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Intertie Usage Report 1997
WN VE ae Municipality of Anchorage Municipal Light & & Power Rick Mystrom, Mayor 1200 East First Avenue E C E | V E Anch Alaska 99501-1689 April 16, 1997 ee eer Telephone: (907) 279-7671, Telegbpjers: (907) 263-5804, 27 APR 21 1997 Alaska Industrial Development Mr. Stan Sieczkowski and Export Authority AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of March 1997. Sincerely, ug Hall Chief Power Dispat DH/pjc Attachment CG: T. Stahr, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA Putting E Energy into Anchorage for Over 60 years c:\1-patty\IOC\so-oprtr\usage\cov-| 16-Apr-97 MONTH JULY AUGUST SEPTEMBER OCTOBER MBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD MONTH JULY AUGUST SEPTEMBER OCTOBER MBER MBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD ALASKA INTERTIE USAGE REPORT FY 97 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHS MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA 0 1075 3581 877 587 1535 10980 11838 2622 33095 MLP DELIVERIES CEA DELIVERIES BL DELIVERIES 0 1075 3581 877 587 1535 10980 11838 2622 33095 ° co oo 31281 35392 34975 14212 12622 29635 25499 11474 33632 0 0 0 228722 30478 34580 34189 13448 11528 28431 24269 10538 32677 220138 ° oo 0 oO oO OOO oO ° 803 ° 812 0 786 0 764 0 1094 0 1204 0 1230 0 936 0 955 0 8584 oe 0 0 eo oO oO GVEA DELIVERIES FMUS DELIVERIES 33 0 oo ° oc oo Oo coo oO oO CO GVEA RECEIPTS 30478 35655 37770 14325 12115 29966 35249 22376 35299 0 0 0 253233 $691,326.09 29 eco’ OOH oO Oo 53 coo eo Oo eco eo oO oO OO eco oo FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS 29 oo 8 OOM Oo 0 53 $144.69 B20 000 OD OOO C8 Oo $10.92 803 812 786 764 1094 1204 1230 936 955 0 0 0 8584 $23,434.32 B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT coo coo o LINE TOTAL 31314 36467 38556 15094 13209 31170 36498 23312 36254 0 0 0 261874 $714,916.02 16-Apr-97 MONTH JULY AUGUST SEPTEMBER OCTOBER EMBER urLEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL MONTH JULY AUGUST SEPTEMBER OCTOBER EMBER EMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ALASKA INTERITE USAGE REPORT FY 97 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS AEGT TO GVEA AEGT TO FMUS GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT 0 ecocoaaoeoa fd 0 ocooeoc oC oe 0 oooeocao oOo 0 coo eo CoO Co 0 ecooaeooae aos 0 coococoOcC oe MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES FMUS DELIVERIES 0 eceooe oe OOOO Ct 0 eooeo oO OOOO Ot 0 esecooec oe OOOO Ot 0 ecooea oe OOOO Ot cecooeo OOO OOO OO 0 ecooacoc fd 0 eocoooao oc 0 cocoa oC fo 0 cocoa oc se 0 eoooaooaeeo ef ecooeocoO CC Oe GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL 0 ecooacn oo ee OC oO es $0.00 0 ecocococo oe eC OOO $0.00 0 ecocoaea eo oe OOOO $0.00 0 ecocoeao oOo eO OOO Oe $0.00 0 eocooo oO OO OOO $0.00 ecooao ec OOOO OCC Oe $0.00 i ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY => ALASKA iE = ENERGY AUTHORITY 480 WEST TUDOR ANCHORAGE, ALASKA 99503 907 / 269-3000 FAX 907 / 269-3044 Reply Address: c/o R&M Consultants, Inc. 9101 Vanguard Drive Anchorage, Alaska 99507 907/522-1707 FAX 907/522-3403 April 30, 1997 Project No. 96-004 Ser No.: RM-011 Mr. Stan Sieczkowski Alaska Energy Authority 480 West Tudor Road Anchorage, AK 99503 RE: Terror Lake Hydroelectric Project Tunnel Repair Projec _ Invoice for Period Ending March 22, 1997 Dear Mr.Sieczkowski: The Invoice for period February 23, 1997 thru March 22, 1997 submitted by Harza Northwest, Inc., is enclosed. The invoice appears to be reasonable and appropriate for the services performed by Harza during the invoice period. We recommend payment of the invoiced amount with any adjustments determined through AEA detailed accounting review. Please give me a call if there are questions on the above. ohn K. we Owner’s Representative Enclosure (1) AEAB0430.97L = 1 om & want January 13, 1999 and Exeor Mr. Sian Sieczkowski, Secretary Anchorage/Fairbanks Intertie Operating Committee AIDEA 480 W Tudor Rd Anchorage AK 99503-6690 Dear Stan: Effective January 1, 1999, the GVEA representatives for the Anchorage/Fairbanks Intertie Operating Committee are Brad Evans, and Steve Haagenson, Alternate. Marvin Riddle has asked to be taken off the committee since his position change at GVEA to Vice President of Member Services and Business Development. If you have any questions, please contact me. Sincerely, CAL f Kn Robert J. Hansen Executive Vice President & C.0.O. ce: Marvin Riddle Steve Haagenson Brad Evans Ny ae Municipality of Anchorage Municipal Light & Power Filck Mysirom; Mayor 1200 East First Avenue F E | V F ANchorage, Alaska 99501-1685 ie (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 MAY 2 2 1997 Alaska Industrial Development May 20, 1997 and Export Authority Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: As of May 20, 1997, all tower cell phones for snow load monitoring equipment are functioning normally except tower #231. Respectfully, geek (acdt97) OAES utting Energy into Anchorage for Over 60 years c:\l-patty\IOC\so-oprtr\memos\phones.doc CITY of WRANGELL, ALASKA INCORPORATED JUNE 15, 1903 BOX 531, 99929 (907) 874-2381 FAX: (907) 874-3952 remanent DECEIVE APR 07 1999 p April 5, 1999 Alaska Industrial Developmen and Export Authority TO: Del Conrad Stan Sicczkowski, AEA FROM: Jeff Jabusch, Finance Director RE: Wrangell Meter Readings (Tyee) Enclosed is the Wrangell meter reading for March 1999. The total KWH for the month is 2,546,620. Please feel free to contact me if you have any questions. Sincerely, Jeff Jabusch, Finance Director STATE OF ALASKA TYEE HYDROELECTRIC PROJECT REVENUE METER READINGS FOR CITY OF WRANGELL DATEREAD: _3- 31 - 99 TIME READ: 8,40 PERSON READING METER: Clay Hammer ¢ wim Nelson PREVIOUS PRESENT | READING READING __| DIFFERENCE | MULTIPLE KWH’S LINE TO APG 996L34 | StL acd | 56% 630 0 569, 630 WRANGELL SUBSTATION | 554.9, 19 TSAL.18 | 1976.99 1,000 1,976, 190 TOTAL KWH'S THROUGH: 3 - 30 -99 MEP Municipal Light & Power POWER MANAGEMENT 1200 East First €venue Anchorage Alaska 99501-1685 phone 907.263.5450 fax 907.263.5441 1 Pp @eti gt yY Oo F a N € H O R A G@ E Rick Mystrom = Mayor D EGEIVET) SEP 16 199 Alaska Industrial Development and Export Authority September 14, 1998 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of August 1998. Sincerely, Doug Hall Chie ispatcher DH/pjc Attachment cc: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA J. Cooley, CEA J. Hall, MEA C.Petty, AEA ¢:\1-patty\IOC\so-oprtr\usage\cov-ltr.doc 11-Sep-98 ALASKA INTERTIE USAGE REPORT FY 99 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT AIDEA TO CEA AIDEA TO MLP AIDEA TO AEGT JULY 684 0 9912 0 0 oO 0 °O 0 0 0 0 AUGUST 602 0 6405 0 45 oO 143 O 0 0 0 0 SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 1286 0 16317 0 45 0 143 0 0 0 0 ° ENERGY $ YTD MONTH MLP DELIVERIES CEA DELIVERIES BL DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS LINE TOTAL JULY 684 9912 0 0 0 10596 0 0 0 0 10596 AUGUST 602 6450 oO 143 0 7007 0 0 143 45 7195 SEPTEMBER ° ° 0 0 ° 0 ° 0 ° ° ° OCTOBER 0 0 0 0 ° 0 0 0 0 0 ° NOVEMBER 0 0 0 0 0 0 0 0 0 0 0 DECEMBER 0 0 ° O 0 0 0 O 0 oO 0 JANUARY 0 0 0 0 0 0 0 O 0 oO 0 FEBRUARY 0 0 0 0 0 0 0 O 0 0 0 MARCH 0 oO 0 0 0 0 0 0 0 0 0 APRIL 0 0 0 0 0 0 0 0 0 0 0 MAY 0 0 0 0 0 0 0 0 0 0 0 JUNE 0 0 0 O 0 0 0 0 0 0 0 YR TOTAL 1286 16362 0 143 0 17603 0 0 143 45 17791 ENERGY $ YTD $90,655.45 $0.00 $0.00 $736.45 $231.75 $91,623.65 11-Sep-98 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ALASKA INTERITE USAGE REPORT FY 99 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS AEGT TO GVEA AEGT TO FMUS GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL 0 ecooeo oo eC OOOO et 0 Specie oo ce a oo 2 ico 0 ecocococ oo eo OC Ot 0 eoooeo oOo oO OOOO 0 eooeo oOo oO OOOO 0 ooo oeoc ooo OC COCO oO $0.00 0 oooeo oo oO OOOO eo $0.00 0 St a $0.00 0 oooooeo oo OO Co $0.00 0 cooooec oC OCC $0.00 cooeo oO OOOO CoO oO $0.00 United States Forest Alaska Region Tongass National Forest Department of Service Stikine Area Agriculture P.O. Box 309 Petersburg, AK 99833 File Code: 2720 Date: September 22, 1997 Vrnoangre ro Alaska Energy Authority D [c CGE I VW Ee Stan Sieczkowski BWiIbUY & ) | 430 W. Tudor Road i Se ocT 93 1997 LY Anchorage, AK 99503-6690 ~ Alaska Industrial Development and Export Authority Enclosed is a copy of the USDA Forest Service’s proposed schedule and annual rental fees for permitted commercial and private communications site uses on National Forest System lands. The Forest Service proposes to adopt for the Southern and Eastern States and Alaska (Regions 8, 9, and 10, respectively) the same fee policy and schedule currently in effect for communications facilities in the Western States (Regions 1 to 6). The final policy and fee schedule for Regions 1 to 6 were published in the Federal Register on October 27, 1995 (60 FR 55089), and became effective for existing uses in those Regions on January 1, 1996. The Bureau of Land Management (BLM) published the same fee schedule and similar policy in a final rule for all lands administered by the BLM on November 13), 1995 (60 FR 57057) - Dear Mr. Sieczkowski: The proposed communications site fee schedule and policy will simplify the permitting and administration process for you and the Forest Service. In addition, authorization documents will be similar to those used in the private sector and a fee schedule that is consistent agency-wide and with the Bureau of Land Management will be in place. We encourage you to examine the proposed fee schedule and policy carefully and provide us with your comments. The Forest Service expects to publish a final policy and schedule for Regions 8, 9, and 10 in November, 1997, incorporating comments received as a result of this Federal Register notice. If you have any questions concerning the proposed fee policy and schedule, please contact Mark Scheibel, Lands Staff, at (202) 205-1264. Sincerely, PATRICIA A. Sel Acting Forest Supervisor Enclosure Caring for the Land and Serving People Printed on Recycled P; FS-6200-28b (12/93) ~ & [3410-11] DEPARTMENT OF AGRICULTURE Forest Service Fee Schedule for Communications Facilities Authorized To Use and Occupy National Forest System Lands in Regions 8, 9, and 10 RIN 0596-AB60 AGENCY: Forest Service, USDA. ACTION: Notice of proposed policy; request for public comment. SUMMARY: The Forest Service proposes to adopt for the Southern and Eastern States and Alaska (Regions 8, 9, and 10, respectively) the same fee schedule and policies currently in effect for the Western States in Regions 1 to 6 for communications facilities authorized to use and occupy National Forest System lands. The Forest Service and the Bureau of Land Management in the Department of the Interior jointly developed identical fee schedules, the same definitions for use categories, and similar administrative procedures for administering and determining fees for communications uses, which are in effect in Regions 1 to 6 for the Forest Service and nationally for the Bureau of Land Management. The Forest Service fee schedule for Regions 1 to 6 was published as a final policy in the Federal Register October 27, 1995 (60 FR 55089) and the Bureau of Land Management schedule was published as a final rule November 13, 1995 (60 FR 57057). The proposed implementation of this fee schedule for Regions 8, 9, and 10 would complete the Forest Service efforts to establish annual fees for all communications uses on National Forest System lands that are consistent throughout all States, are based on sound business management principles, and reflect fair market va , aS required by Title V of tk ederal Land Policy and Management Act of 1976, the Independent Offices Appropriations Act of 1952, and the Office of Management and Budget Circular A-25. Public comment is invited. DATES: Comments must be received in writing by [Insert date 60 days after date of publication in the FEDERAL REGISTER] . ADDRESSES: Send written comments to the Director, Lands Staff (2720), Forest Service, USDA, P.O. Box 96090, Washington, DC 20090-6090. The public may inspect comments received on this proposed policy in the Office of the Director, Lands Staff, 4th Floor-South, Auditors Building, 201 14th Street S.W., Washington, DC. Those who submit comments should be aware that all comments, including names and addresses when provided, are placed in the record and are available for public inspection. To facilitate entrance into the building, those wishing to inspect comments are encouraged to call ahead at (202) 205-1367. FOR FURTHER INFORMATION CONTACT: Mark Scheibel, Lands Staff, (202) 205-1264. SUPPLEMENTARY INFORMATION: Background Use of National Forest System lands for transmission of electronic signals, commonly called communications uses, is authorized by Title Vv of the Federal Land Policy and Management Act of 1976 (43 U.S.C. 1761-1771). This use involves buildings, towers, or other physical improvements built, installed, or established to support communications equipment. From 37 to 1992, through various no es in the Federal Register, the Forest Service began publishing final and revised fee schedules on a regional basis for selected categories of communications uses on sites serving rural areas. The notices explained the need for further analysis to complete the fee schedules for the remaining use categories. In the interim, on-site appraisals would determine commercial mobile radio and cellular telephone fees for sites serving urban areas (Los Angeles, Albuquerque, and Boise, for example) and for television and FM radio broadcast. To forestall the effect of significant fee increases on authorization holders, especially in rural areas, Congress adopted administrative provisions in the Appropriations Acts for Interior and Related Agencies for fiscal years 1990 through 1994 preventing the Forest Service from raising fees over the amount in effect on January 1, 1989. In the fiscal year 1992 Appropriations Act, Congress extended the prohibition to include those authorizations issued by the Department of the Interior, Bureau of Land Management (BLM). In addition, the conference report for the Appropriations Act directed the Secretaries of Agriculture and Interior to establish a broad-based Radio and Television Broadcast Use Fee Advisory Committee (Advisory Committee). The Advisory Committee’s charge was to review the schedules, with particular emphasis on their impact on rural communities in the Western United States. The Forest Service and BLM entered into a joint agency agreement in April 1991 to develop parallel procedures and standards for establishing fair market rental values for communications uses on lands they administer. The objective of the effort was to develop joint market-ba fee schedules. At that time, .e Forest Service decided to proceed with a fee schedule for only the Western States (Regions 1 to 6) and to develop fee schedules for the Southern and Eastern States and Alaska at a later date. The Advisory Committee submitted its report to the Secretaries on December 11, 1992. The report made several recommendations: (1) use of fee schedules instead of individual site appraisals to improve cost efficiency and administration, (2) acceptance of industry-recognized market ranking systems, (3) a phase-in period for rent increases greater than $1,000, (4) collection of 25 percent of the gross sublease income received from tenants by facility owners, (5) issuance of a "footprint" lease in which only facility owners would hold authorizations, and (6) annual fee increases based on the Consumer Price Index (Urban Consumer, U.S. City Average). On July 13, 1993, the Forest Service published a Federal Register notice (58 FR 37840) requesting public comments on a proposed fee schedule for the four categories of commercial uses previously excluded from the regional schedules. The uses included television broadcast, FM radio broadcast, commercial mobile radio, and cellular telephone uses. The adoption of a final revised fee schedule would complete the regional schedules in place in Forest Service Regions 1 through 6 in the Western United States. Additionally, the agency stated its intention that its fee schedule be fully consistent with that of BLM and acknowledged that BLM planned to issue a separate Federal Register notice proposing the use of fee schedules for all communications uses applicable to lands under its jurisdiction. The 2st Service and BLM jointly re wed and considered the comments received by the Forest Service on its July 1993 proposed policy (58 FR 37840, July 13, 1993), incorporating and adopting the comments as appropriate in the development of the BLM proposed rule. On July 12, 1994, BLM published a proposed rule in the Federal Register (S9 FR 35596), requesting comments on amendments to its right-of-way regulations. The proposed rule contained procedures for setting fair market rent for communications uses on public land and established schedules and procedures for eleven categories of communications service. The Forest Service and BLM developed the final fee schedule and similar policies and procedures for administering communications authorizations using information gained from public responses to the proposed Forest Service policy (58 FR 37840, July 13, 1993) and the proposed BLM rule (59 FR 35596, July 12, 1994). The agencies also used the Advisory Committee report; the General Accounting Office report; discussions with hundreds of industry representatives and private lessors, commercial communications site managers, State and local government representatives, and appraisers; and nearly 2,000 confirmed private lease transactions. The final Forest Service fee schedule, policy, and procedures for communications fees for Regions 1 through 6 were issued as amendments to Forest Service Handbook (FSH) 2709.11, Special Uses Handbook, chapter 30, Fee Determinations, and chapter 40, Special Uses Administration (60 FR 55089, October 27, 1995). Proposed Fee Schedule for Regions 8, 9, and 10 The proposed fee schedule and policy for communications uses in Regions 8, 9 and 10 are identical to the final policy and fee schedule implemente for Forest Service Regions 1 t igh 6 (60 FR 55089, October 27, 1995) Regions 8, 9, and 10 used existing data gathered for developing the fee schedule in Regions 1 through 6 and additional data gathered in areas of concentrated uses in Regions 8, 9, and 10 to determine if this fee schedule implemented in Regions 1 through 6 is valid for the Southern and Eastern States and Alaska. Analysis of the market survey concluded that the fee schedule for Regions 1 through 6 is appropriate for use in Regions 8, 9, and 10. Method for Determining Fees The proposed method to determine fees in Regions 8, 9, and 10 is the method currently used in Regions 1 through 6 and set out in Forest Service Handbook (FSH) 2709.11, Special Uses Handbook, chapter 40, Special Uses Administration, section 48, Communications. The fee policy and schedule, including implementation, phase-in, and updating procedures, are included in FSH 2709.11, chapter 30, Fee Determinations, section 36.2, Communications Site Fee Schedule. The text of the proposed policy and the fee schedule in FSH 2709.11 are set forth at the end of this notice. Fee Schedule 1. Categories of Use The proposed fee schedule for Regions 8, 9 and 10 contains nine categories of communications uses that are identical to the categories in the current fee schedule for Regions 1 to 6. These categories of uses include: (1) television broadcast, (2) AM/FM radio broadcast, (3) cable television, (4) broadcast translators, low power television and low power FM radio, (5) commercial mobile radio service and facility | ager, (6) cellular telephone, private mobile radio service, (8) microwave, and (9) other communications uses. Two use categories, passive reflector and local exchange network, will remain as regional fee schedules. 2. Community Served The current fee policy in Regions 1 through 6 contains criteria for determining the community served. The proposed fee schedule for Regions 8, 9, and 10 contains identical criteria as follows: a. The fee schedule is based on a ranking of Ranally Metro Areas (RMAs) as identified in the current edition of the "Rand McNally Commercial Atlas and Marketing Guide." An RMA represents Rand McNally’s definition of metropolitan areas in the United States. There are 452 RMAs, of which 417 have a population of 50,000 or more; 35 have a population near 50,000 and are included as RMAs because they include a central city of an official Metropolitan Statistical Area. b. The fee is based on the location of the communications site and whether or not it serves an RMA, serves a community not listed as an RMA, or is in a remote, sparsely populated area that does not serve any individual community. c. If the communications site serves an RMA, the fee is determined by the category of use and the population range on the schedule that includes the RMA population. da. If the communications site serves a community not listed as an RMA, the fee is determined by the category of use and the population range on the schedule that includes the population for the largest community served by the site, as indicated in the current edition of the "Rand McNally Road Atlas." e. the communications site does r serve a community, the fee is based on the minimum scheduled fee for the type of facility and use. The fee schedule used for Regions 1 to 6 and proposed for Regions 8, 9, and 10 is shown in section 36.21, exhibit 01. 3. Fee Indexing The fees for Regions 1 to 6, which the Forest Service proposes to apply to Regions 8, 9, and 10, are subject to an annual index to ensure the fee is kept current with fair market value. The Forest Service found that use of an index is common practice in the private lease market. Accordingly, the Bureau of Labor Statistics’ Consumer Price Index for All Urban Consumers (CPI-U) is used as an annual index for communications site fees in the current schedule for Regions 1 to 6. Annual rents for communications site uses on private leases are linked to changes in the CPI-U instead of increases in land value. Because of inflation and time factors, use of the CPI-U could cause higher than normal increases in land rents in the private market. To offset potentially high increases in CPI-U and minimize any potential inflation of fees, the agency has to limit the CPI-U increases in the current schedule to no more than 5 percent per year. 4. Lease Authorization Regions 8, 9, and 10 would utilize the same communications site lease, Form FS-2700-4a, already used by the Forest Service in Regions 1 through 6 and nationally by the Bureau of Land Management. This authorization allows the holder to lease space in the holder’s facility to other communications users. The fee is determined by the highest value use in the facility (base fee), plus 25 percent of the schedule : for the type of use and commu y served for all tenant uses. Additional provisions of the lease are as follows: a. The lease authorizes tenant occupancy, if desired by the holder and consistent with site plans or agency direction, without prior written consent of the Forest Service. (1) In a facility with tenants, the holder’s base fee is determined by the use that generates the highest fee on the schedule (highest valued use) of any of the uses in the facility, excluding those uses that would qualify for a fee exemption and/or waiver. If the schedule fee for another use in the facility is higher than the holder’s, the holder’s use is subordinated for purposes of calculating total fees for the facility. By October 15 each year, the holder is required to provide the authorized officer with a certified statement listing the name and type of use for each occupant in the holder’s facility on September 30 of that year. (2) Uses defined as "customer" (including private (other) and internal (PMRS) categories), rental of space in a communications facility, and uses that would qualify for a fee exemption and/or waiver are not used to calculate total fees for the facility. (3) An additional fee for tenant occupancy applies to all other use categories in every population strata not identified in the preceding paragraph (2). The additional fee is calculated on 25 percent of the scheduled fee. (4) The total fee for the facility is the base fee (the highest value use), plus the additional fee based on 25 percent of the schedule fee for all tenant uses in the facility. (These requirements are in sec. 36.21.) b. 4 fee for a facility with no te ts is the schedule fee for the holder’s category of use. c. A tenant in a facility may hold a separate authorization at the full schedule fee based on the tenant’s category of use. A tenant is defined in the policy as a communications user who rents space in a communications facility and operates communications equipment for the purpose of re-selling communications services to others for profit (sec. 48.1, para. 5). d. The lease is transferable with prior approval of the authorized officer. 5. Phase-in of Fee Schedule The Forest Service recognizes that the proposed implementation of the fee schedule could significantly raise fees for some permittees in Regions 8, 9, and 10. The agency thus proposes for Regions 8, 9, and 10 to phase in the fee schedule according to the same procedure already in place for Regions 1 to 6 as follows: Fee increases of $1,000 or more would be phased in over a 5-year period, with a maximum increase of $1,000 in year one of implementation of the schedule. The balance would be phased in during years two through five. The full fee, as indicated in the fee schedule, plus adjustments based on annual CPI-U indexing and changes in tenant uses, would be reached in the fifth year. The phase-in policy does not apply for new uses (new construction). As stated in the proposed policy for Regions 1 to 6, the reason for phasing in the fee schedule is to minimize the possible significant economic burden on users (58 FR 37840, July 13, 1993). The agency also recognizes that a phase-in policy results in reduced receipts to the Treasury the initial years of the fee s dule implementation. However, the agency believes that the magnitude of some fee increases under the proposed fee schedule, due in part to the length of time the fee schedule has been under development and debate, and its decision to change the method of determining fair market value to obtain more accurate fees, could impose an economic burden on some permittees with an associated risk of adverse impact on their business. A phase-in policy minimizes this risk to the permittee. The following is an example of a phase-in fee schedule: Year 1 (1998): $ 700 + $1,000 = $1,700 Year 2 (1999): ($1,700 + $250) x 1.02 = $1,989 Year 3 (2000): ($1,989 + $250) x 1.02 = $2,284 Year 4 (2001): ($2,284 + $250) x 1.02 = $2,584 Year 5 (2002): ($2,584 + $250) x 1.02 = $2,891 Year 6 (2003): ($2,891 + $ 0) x 1.02 = $2,949 This example of a phase-in fee schedule assumes a 2 percent increase each year in the CPI-U. 6. Reevaluation of Fee Schedule The policy in effect for Regions 1 to 6, which the Forest Service proposes to adopt in Regions 8, 9, and 10, provides for review and updating of the communications fee schedule no later than 10 years from the date of implementation, and at least every 10 years thereafter, to ensure the fees reflect fair market value (60 FR 55097). Each holder’s annual fee established as a result of this schedule would be reviewed. 7. Other Provisions of the Policy The policy for Regions 1 to 6, which the Forest Service proposes to adopt for Regions 8, 9, and 10, allows exceptions to the fee schedule . ‘ertain situations. The fee p cy for Regions 1 through 6 provides that the authorized officer may deviate from the schedule and use other methods, including appraisals and competitive bids, to determine fair market value fees for communications uses when one or more of the following criteria applies (FSH 2709.11, sec. 36.21a): a. The fee or use is not covered by the fee schedule. b. The fee has been or will be established through competitive bid or appraisal and will be updated in accordance with the terms and conditions of the authorization. c. The Regional Forester concurs with the authorized officer that the communications site serves a population of 1 million or more and the expected fee for the communications use is more than $10,000 above the established fee schedule. d. The expected fee exceeds the schedule rate fee by five times or more. Fee waivers and exemptions are allowed but must follow the policy addressing all land uses, as set forth in FSH 2709.11, chapter 30 and Forest Service Manual (FSM) chapter 2710, section FSM 2715. The authority to set criteria for and grant exemptions from fees is either reserved to Federal agencies or set by law. The authorized officer determines fee waivers on a case-by-case basis and may grant a fee waiver when it is equitable and in the public interest. Summary The Forest Service is proposing to implement the same fee schedule and policies in the Southern and Eastern States and Alaska (Regions 8, 9, and 10, respectively) as are currently in use in the Western United States (Regions 1 through 6). The agency believes the proposed fee schedule 1 :s the statutory and regulator equirements to obtain fair market value fees from authorized commercial and private communications uses on National Forest System lands, and that its adoption would be in the public interest. If this fee schedule is adopted for Regions 8, 9, and 10, it would place most communications uses on National Forest System lands in these Regions under a fee schedule. Exceptions to use of the fee schedule would be allowed in certain situations. It is the agency’s intention that its fee schedule for Regions 8, 9 and 10 be fully consistent with the schedule currently implemented in Regions 1 through 6 (60 FR 55089, October 27, 1995) and with the corresponding fee schedule for lands under the jurisdiction of the Bureau of Land Management (60 FR 57057, November 13, 1995) . Controlling Paperwork Burdens on the Public This policy does not contain any record keeping or reporting requirements or other information collection requirements as defined in 5 CFR part 1320 which are not already required by law or not already approved for use. The information collection being requested as a result of this action has been approved by OMB (Number 0596-0082, expiration date June 30, 1999). Accordingly, further review is not required under provisions of the Paperwork Reduction Act of 1995 (44 U.S.C. 3501 et seq.), and implementing regulations at 5 CFR part 1320 do not apply. Environme L Impact This proposed policy would establish a fee schedule to guide the administrative process of calculating annual fees to be charged holders of authorizations for communications uses on National Forest System lands in Forest Service Regions 8, 9, and 10 (Southern and Eastern States and Alaska, respectively). The existing regional fee schedules for communications uses in Regions 8, 9, and 10 would be replaced by the fee schedule already in effect for the Western States in Regions 1 to 6. Upon adoption of a final fee schedule, individual authorization holders would be notified of the changes in their annual fees. Section 31.1b of Forest Service Handbook 1909.15 (57 FR 43180, September 18, 1992) excludes from documentation in an environmental assessment or impact statement, "rules, regulations, or policies to establish Service-wide administrative procedures, program processes, or instructions." The agency’s preliminary assessment is that this policy falls within this category of actions and that no extraordinary circumstances exist which would require preparation of an environmental assessment or environmental impact statement. A final determination will be made upon adoption of the final policy. Regulatory Impact This proposed policy has been reviewed under USDA procedures and Executive Order 12866 on Regulatory Planning and Review. It has been determined that this is not a significant policy. This policy will not have an annual effect of $100 million or more on the economy nor adversely affect productivity, competition, jobs, the environment, public health or safety, nor State or local governments. This policy will not interfere with an action taken or planned by another agency nor raise legal or policy issues. Fini 7, this action will not alter the budgetary impact of entitlements, grants, user fees, or loan programs or the rights and obligations of recipients of such programs. Accordingly, this proposed policy is not subject to OMB review under Executive Order 12866. Moreover, this proposed policy has been considered in light of the Regulatory Flexibility Act (5 U.S.C. 601 et seq.), and it has been determined that this action will not have a significant economic impact on a substantial number of small entities as defined by that act. The phase-in of annual fees proposed in this notice will allow small entities to adjust to the new fees over a period of time, and thus minimize the risk of adverse impact on some businesses because of the magnitude of the increases in some fees. No Takings Implications This policy has been analyzed in accordance with the principles and criteria contained in Executive Order 12630, and it has been determined that the policy does not pose the risk of a taking of Constitutionally protected private property. Civil Justice Reform Act This proposed policy has been reviewed under Executive Order 12778, Civil Justice Reform. If this proposed policy were adopted, (1) all State and local laws and regulations that are in conflict with this proposed policy or which would impede its full implementation would be preempted; (2) no retroactive effect would be given to this proposed policy; and (3) it would not require administrative proceedings before parties may file suit in court challenging its provisions. Unfunded 1! ates Reform Pursuant to Title II of the Unfunded Mandates Reform Act of 1995, which the President signed into law on March 22, 1995, the Department has assessed the effects of this policy on State, local, and tribal governments and the private sector. This policy does not compel the expenditure of $100 million or more by any State, local, or tribal governments or anyone in the private sector. Therefore, a statement under section 202 of the Act is not required. /s/robert c. joslin 7/8/97 Acting Chief (dated) @ Tongass National Forest Stikine Area P.O. Box 309 Petersburg, AK United States Department of Agriculture Forest Service Alaska Region 99833 File Code: 2720 Date: September 22, 1997 vf fe Alaska Energy Authority D fe GE I We Stan Sieczkowski te Wis Le Us 430 W. Tudor Road OCT 93 1997 Anchorage, AK 99503-6690 OUT 93 i997 Dear Mr. Sieczkowski: Alaska Industrial Developmen: énd Export Authority Enclosed is a copy of the USDA Forest Service’s proposed schedule and annual rental fees for permitted commercial and private communications site uses on National Forest System lands. The Forest Service proposes to adopt for the Southern and Eastern States and Alaska (Regions 8, 9, and 10, respectively) the same fee policy and schedule currently in effect for communications facilities in the Western States (Regions 1 to 6). The final policy and fee schedule for Regions 1 to 6 were published in the Federal Register on October 27, 1995 (60 FR 55089), and became effective for existing uses in those Regions on January 1, 1996. The Bureau of Land Management (BLM) published the same fee schedule and similar policy in a final rule for all lands administered by the BLM on November 13, 1995 (60 FR 57057). The proposed communications site fee schedule and policy will simplify the permitting and administration process for you and the Forest Service. In addition, authorization documents will be similar to those used in the private sector and a fee schedule that is consistent agency-wide and with the Bureau of Land Management will be in place. We encourage you to examine the proposed fee schedule and policy carefully and provide us with your comments. The Forest Service expects to publish a final policy and schedule for Regions 8, 9, and 10 in November, 1997, incorporating comments received as a result of this Federal Register notice. If you have any questions concerning the proposed fee policy and schedule, please contact Mark Scheibel, Lands Staff, at (202) 205-1264. Sincerely, Acting Forest Supervisor Enclosure Caring for the Land and Serving People Printed on Recycled P; FS-6200-28b (12/93) ~ & (3410-11) DEPARTMENT OF AGRICULTURE Forest Service Fee Schedule for Communications Facilities Authorized To Use and Occupy National Forest System Lands in Regions 8, 9, and 10 RIN 0596-AB60 AGENCY: Forest Service, USDA. ACTION: Notice of proposed policy; request for public comment. SUMMARY: The Forest Service proposes to adopt for the Southern and Eastern States and Alaska (Regions 8, 9, and 10, respectively) the same fee schedule and policies currently in effect for the Western States in Regions 1 to 6 for communications facilities authorized to use and occupy National Forest System lands. The Forest Service and the Bureau of Land Management in the Department of the Interior jointly developed identical fee schedules, the same definitions for use categories, and similar administrative procedures for administering and determining fees for communications uses, which are in effect in Regions 1 to 6 for the Forest Service and nationally for the Bureau of Land Management. The Forest Service fee schedule for Regions 1 to 6 was published as a final policy in the Federal Register October 27, 1995 (60 FR 55089), and the Bureau of Land Management schedule was published as a final rule November 13, 1995 (60 FR 57057). The proposed implementation of this fee schedule for Regions 8, 9, and 10 would complete the Forest Service efforts to establish annual fees for all communications uses on National Forest System lands that are consistent throughout all States. are based on sound business management principles, and reflect fair market vali as required by Title V of the deral Land Policy and Management Act of 1976, the Independent Offices Appropriations Act of 1952, and the Office of Management and Budget Circular A-25. Public comment is invited. DATES: Comments must be received in writing by [Insert date 60 days after date of publication in the FEDERAL REGISTER] . ADDRESSES: Send written comments to the Director, ve Staff (2720), Forest Service, USDA, P.O. Box 96090, Washington, DC 20090-6090. The public may inspect comments received on this proposed policy in the Office of the Director, Lands Staff, 4th Floor-South, Auditors Building, 201 14th Street S.W., Washington, DC. Those who submit comments should be aware that all comments, including names and addresses when provided, are placed in the record and are available for public inspection. To facilitate entrance into the building, those wishing to inspect comments are encouraged to call ahead at (202) 205-1367. FOR FURTHER INFORMATION CONTACT: Mark Scheibel, Lands Staff, (202) 205-1264. SUPPLEMENTARY INFORMATION: Background Use of National Forest System lands for transmission of electronic signals, commonly called communications uses, is authorized by Title v of the Federal Land Policy and Management Act of 1976 (43 U.S.C. 1761-1771). This use involves buildings, towers, or other physical improvements built, installed, or established to support communications equipment. From : ’ to 1992, through various not.i.cs in the Federal Register, the Forest Service began publishing final and revised fee schedules on a regional basis for selected categories of communications uses on sites serving rural areas. The notices explained the need for further analysis to complete the fee schedules for the remaining use categories. In the interim, on-site appraisals would determine commercial mobile radio and cellular telephone fees for sites serving urban areas (Los Angeles, Albuquerque, and Boise, for example) and for television and FM radio broadcast. To forestall the effect of significant fee increases on authorization holders, especially in rural areas, Congress adopted administrative provisions in the Appropriations Acts for Interior and Related Agencies for fiscal years 1990 through 1994 preventing the Forest Service from raising fees over the amount in effect on January 1, 1989. In the fiscal year 1992 Appropriations Act, Congress extended the prohibition to include those authorizations issued by the Department of the Interior, Bureau of Land Management (BLM). In addition, the conference report for the Appropriations Act directed the Secretaries of Agriculture and Interior to establish a broad-based Radio and Television Broadcast Use Fee Advisory Committee (Advisory Committee). The Advisory Committee's charge was to review the schedules, with particular emphasis on their impact on rural communities in the Western United States. The Forest Service and BLM entered into a joint agency agreement in April 1991 to develop parallel procedures and standards for establishing fair market rental values for communications uses on lands they administer. The objective of the effort was to develop joint market-bas fee schedules. At that time, __+ Forest Service decided to proceed with a fee schedule for only the Western States (Regions 1 to 6) and to develop fee schedules for the Southern and Eastern States and Alaska at a later date. The Advisory Committee submitted its report to the Secretaries on December 11, 1992. The report made several recommendations: (1) use of fee schedules instead of individual site appraisals to improve cost efficiency and administration, (2) acceptance of industry-recognized market ranking systems, (3) a phase-in period for rent increases greater than $1,000, (4) collection of 25 percent of the gross sublease income received from tenants by facility owners, (5) issuance of a "footprint" lease in which only facility owners would hold authorizations, and (6) annual fee increases based on the Consumer Price Index (Urban Consumer, U.S. City Average) . On July 13, 1993, the Forest Service published .a Federal Register notice (58 FR 37840) requesting public comments on a proposed fee schedule for the four categories of commercial uses previously excluded from the regional schedules. The uses included television broadcast, FM radio broadcast, commercial mobile radio, and cellular telephone uses. The adoption of a final revised fee schedule would complete the regional schedules in place in Forest Service Regions 1 through 6 in the Western United States. Additionally, the agency stated its intention that its fee schedule be fully consistent with that of BLM and acknowledged that BLM planned to issue a separate Federal Register notice proposing the use of fee schedules for all communications uses applicable to lands under its jurisdiction. The F 3st Service and BLM jointly revscwed and considered the comments received by the Forest Service on its July 1993 proposed policy (58 FR 37840, July 13, 1993), incorporating and adopting the comments as appropriate in the development of the BLM proposed rule. On July 12, 1994, BLM published a proposed rule in the Federal Register (S9 FR 35596), requesting comments on amendments to its right-of-way regulations. The proposed rule contained procedures for setting fair market rent for communications uses on public land and established schedules and procedures for eleven categories of communications service. The Forest Service and BLM developed the final fee schedule and similar policies and procedures for administering communications authorizations using information gained from public responses to the proposed Forest Service policy (58 FR 37840, July 13, 1993) and the proposed BLM rule (59 FR 35596, July 12, 1994). The agencies also used the Advisory Committee report; the General Accounting Office report; discussions with hundreds of industry representatives and private lessors, commercial communications site managers, State and local government representatives, and appraisers; and nearly 2,000 confirmed private lease transactions. The final Forest Service fee schedule, policy, and procedures for communications fees for Regions 1 through 6 were issued as amendments to Forest Service Handbook (FSH) 2709.11, Special Uses Handbook, chapter 30, Fee Determinations, and chapter 40, Special Uses Administration (60 FR 55089, October 27, 1995). Proposed Fee Schedule for Regions 8, 9, and 10 The proposed fee schedule and policy for communications uses in Regions 8, 9 and 10 are identical to the final policy and fee schedule implementec xr Forest Service Regions 1 th gh 6 (60 FR 55089, October 27, 1995) Regions 8, 9, and 10 used existing data gathered for developing the fee schedule in Regions 1 through 6 and additional data gathered in areas of concentrated uses in Regions 8, 9, and 10 to determine if this fee schedule implemented in Regions 1 through 6 is valid for the Southern and Eastern States and Alaska. Analysis of the market survey concluded that the fee schedule for Regions 1 through 6 is appropriate for use in Regions 8, 9, and 10. Method for Determining Fees The proposed method to determine fees in Regions 8, 9, and 10 is the method currently used in Regions 1 through 6 and set out in Forest Service Handbook (FSH) 2709.11, Special Uses Handbook, chapter 40, Special Uses Administration, section 48, Communications. The fee policy and schedule, including implementation, phase-in, and updating procedures, are included in FSH 2709.11, chapter 30, Fee Determinations, section 36.2, Communications Site Fee Schedule. The text of the proposed policy and the fee schedule in FSH 2709.11 are set forth at the end of this notice. Fee Schedule 1. Categories of Use The proposed fee schedule for Regions 8, 9 and 10 contains nine categories of communications uses that are identical to the categories in the current fee schedule for Regions 1 to 6. These categories of uses include: (1) television broadcast, (2) AM/FM radio broadcast, (3) cable television, (4) broadcast translators, low power television and low power FM radio, (5) commercial mobile radio service and facility m ger, (6) cellular telephone, (., private mobile radio service, (8) microwave, and (9) other communications uses. Two use categories, passive reflector and local exchange network, will remain as regional fee schedules. 2. Community Served The current fee policy in Regions 1 through 6 contains criteria for determining the community served. The proposed fee schedule for Regions 8, 9, and 10 contains identical criteria as follows: a. The fee schedule is based on a ranking of Ranally Metro Areas (RMAs) as identified in the current edition of the "Rand McNally Commercial Atlas and Marketing Guide." An RMA represents Rand McNally’s definition of metropolitan areas in the United States. There are 452 RMAs, of which 417 have a population of 50,000 or more; 35 have a population near 50,000 and are included as RMAs because they include a central city of an official Metropolitan Statistical Area. b. The fee is based on the location of the communications site and whether or not it serves an RMA, serves a community not listed as an RMA, or is in a remote, sparsely populated area that does not serve any individual community. c. If the communications site serves an RMA, the fee is determined by the category of use and the population range on the schedule that includes the RMA population. d. If the communications site serves a community not listed as an RMA, the fee is determined by the category of use and the population range on the schedule that includes the population for the largest community served by the site, as indicated in the current edition of the "Rand McNally Road Atlas." e. I he communications site does nc. serve a community, the fee is based on the minimum scheduled fee for the type of facility and use. The fee schedule used for Regions 1 to 6 and proposed for Regions 8, 9, and 10 is shown in section 36.21, exhibit 01. 3. Fee Indexing The fees for Regions 1 to 6, which the Forest Service proposes to apply to Regions 8, 9, and 10, are subject to an annual index to ensure the fee is kept current with fair market value. The Forest Service found that use of an index is common practice in the private lease market. Accordingly, the Bureau of Labor Statistics’ Consumer Price Index for All Urban Consumers (CPI-U) is used as an annual index for communications site fees in the current schedule for Regions 1 to 6. Annual rents for communications site uses on private leases are linked to changes in the CPI-U instead of increases in land value. Because of inflation and time factors, use of the CPI-U could cause higher than normal increases in land rents in the private market. To offset potentially high increases in CPI-U and minimize any potential inflation of fees, the agency has to limit the CPI-U increases in the current schedule to no more than 5 percent per year. 4. Lease Authorization Regions 8, 9, and 10 would utilize the same communications site lease, Form FS-2700-4a, already used by the Forest Service in Regions 1 — 6 and nationally by the Bureau of Land Management. This authorization allows the holder to lease space in the holder’s facility to other communications users. The fee is determined by the highest value use in the facility (base fee), plus 25 percent of the schedule f£ for the type of use and commurnicy served for all tenant uses. Additional provisions of the lease are as follows: a. The lease authorizes tenant occupancy, if desired by the holder and consistent with site plans or agency direction, without prior written consent of the Forest Service. (1) In a facility with tenants, the holder’s base fee is determined by the use that generates the highest fee on the schedule (highest valued use) of any of the uses in the facility, excluding those uses that would qualify for a fee exemption and/or waiver. If the schedule fee for another use in the facility is higher than the holder's, the holder's use is subordinated for purposes of calculating total fees for the facility. By October 15 each year, the holder is required to provide the authorized officer with a certified statement listing the name and type of use for each occupant in the holder’s facility on September 30 of that year. (2) Uses defined as "customer" (including private (other) and internal (PMRS) categories), rental of space in a communications facility, and uses that would qualify for a fee exemption and/or waiver are not used to calculate total fees for the facility. (3) An additional fee for tenant occupancy applies to all other use categories in every population strata not identified in the preceding paragraph (2). The additional fee is calculated on 25 percent of the scheduled fee. (4) The total fee for the facility is the base fee (the highest value use), plus the additional fee based on 25 percent of the schedule fee for all tenant uses in the facility. (These requirements are in sec.) 36.21.) bs TI fee for a facility with no tenu...s is the schedule fee for the holder’s category of use. c. A tenant in a facility may hold a separate authorization at the full schedule fee based on the tenant’s category of use. A tenant is defined in the policy as a communications user who rents space in a communications facility and operates communications equipment for the purpose of re-selling communications services to others for profit (sec. 48.1, para. 5). d. The lease is transferable with prior approval of the authorized officer. 5. Phase-in of Fee Schedule The Forest Service recognizes that the proposed implementation of the fee schedule could significantly raise fees for some permittees in Regions 8, 9, and 10. The agency thus proposes for Regions 8, 9, and 10 to phase in the fee schedule according to the same procedure already in place for Regions 1 to 6 as follows: Fee increases of $1,000 or more would be phased in over a 5-year period, with a maximum increase of $1,000 in year one of implementation of the schedule. The balance would be phased in during years two through five. The full fee, as indicated in the fee schedule, plus adjustments based on annual CPI-U indexing and changes in tenant uses, would be reached in the fifth year. The phase-in policy does not apply for new uses (new construction) . As stated in the proposed policy for Regions 1 to 6, the reason for phasing in the fee schedule is to minimize the possible significant economic burden on users (58 FR 37840, July 13, 1993). The agency also recognizes that a phase-in policy results in reduced receipts to the Treasury ii ie initial years of the fee sc..cuule implementation. However, the agency believes that the magnitude of some fee increases under the proposed fee schedule, due in part to the length of time the fee schedule has been under development and debate, and its decision to change the method of determining fair market value to obtain more accurate fees, could impose an economic burden on some permittees with an associated risk of adverse impact on their business. A phase-in policy minimizes this risk to the permittee. The following is an example of a phase-in fee schedule: Year 1 (1998): $ 700 + $1,000 = $1,700 Year 2 (1999): ($1,700 + $250) x 1.02 = $1,989 Year 3 (2000): ($1,989 + $250) x 1.02 = $2,284 Year 4 (2001): ($2,284 + $250) x 1.02 = $2,584 Year 5 (2002): ($2,584 + $250) x 1.02 = $2,891 Year 6 (2003): ($2,891 + $ 0) x 1.02 = $2,949 This example of a phase-in fee schedule assumes a 2 percent increase each year in the CPI-U. 6. Reevaluation of Fee Schedule The policy in effect for Regions 1 to 6, which the Forest Service proposes to adopt in Regions 8, 9, and 10, provides for review and updating of the communications fee schedule no later than 10 years from the date of implementation, and at least every 10 years thereafter, to ensure the fees reflect fair market value (60 FR 55097). Each holder’s annual fee established as a result of this schedule would be reviewed. 7. Other Provisions of the Policy The policy for Regions 1 to 6, which the Forest Service proposes to adopt for Regions 8, 9, and 10, allows exceptions to the fee schedule i: ‘rtain situations. The fee po y for Regions 1 through 6 provides that the authorized officer may deviate from the schedule and use other methods, including appraisals and competitive bids, to determine fair market value fees for communications uses when one or more of the following criteria applies (FSH 2709.11, sec. 36.21a): a. The fee or use is not covered by the fee schedule. b. The fee has been or will be established through competitive bid or appraisal and will be updated in accordance with the terms and conditions of the authorization. c. The Regional Forester concurs with the authorized officer that the communications site serves a population of 1 million or more and the expected fee for the communications use is more than $10,000 above the established fee schedule. d. The expected fee exceeds the schedule rate fee by five times or more. Fee waivers and exemptions are allowed but must follow the policy addressing all land uses, as set forth in FSH 2709.11, chapter 30 and Forest Service Manual (FSM) chapter 2710, section FSM 2715. The authority to set criteria for and grant exemptions from fees is either reserved to Federal agencies or set by law. The authorized officer determines fee waivers on a case-by-case basis and may grant a fee waiver when it is equitable and in the public interest. Summary The Forest Service is proposing to implement the same fee schedule and policies in the Southern and Eastern States and Alaska (Regions 8, 9, and 10, respectively) as are currently in use in the Western United States (Regions 1 through 6). The agency believes the proposed fee schedule m 3 the statutory and regulatory .-quirements to obtain fair market value fees from authorized commercial and private communications uses on National Forest System lands, and that its adoption would be in the public interest. If this fee schedule is adopted for Regions 8, 9, and 10, it would place most communications uses on National Forest System lands in these Regions under a fee schedule. Exceptions to use of the fee schedule would be allowed in certain situations. It is the agency’s intention that its fee schedule for Regions 8, 9 and 10 be fully consistent with the schedule currently implemented in Regions 1 through 6 (60 FR 55089, October 27, 1995) and with the corresponding fee schedule for lands under the jurisdiction of the Bureau of Land Management (60 FR 57057, November 13, 1995). Controlling Paperwork Burdens on the Public This policy does not contain any record keeping or reporting requirements or other information collection requirements as defined in 5 CFR part 1320 which are not already required by law or not already approved for use. The information collection being requested as a result of this action has been approved by OMB (Number 0596-0082, expiration date June 30, 1999). Accordingly, further review is not required under provisions of the Paperwork Reduction Act of 1995 (44 U.S.C. 3501 et seq.), and implementing regulations at 5 CFR part 1320 do not apply. Environmeni Impact This proposed policy would establish a fee schedule to guide the administrative process of calculating annual fees to be charged holders of authorizations for communications uses on National Forest System lands in Forest Service Regions 8, 9, and 10 (Southern and Eastern States and Alaska, respectively). The existing regional fee schedules for communications uses in Regions 8, 9, and 10 would be replaced by the fee schedule already in effect for the Western States in Regions 1 to 6. Upon adoption of a final fee schedule, individual authorization holders would be notified of the changes in their annual fees. Section 31.1b of Forest Service Handbook 1909.15 (57 FR 43180, September 18, 1992) excludes from documentation in an environmental assessment or impact statement, "rules, regulations, or policies to establish Service-wide administrative procedures, program processes, or instructions." The agency’s preliminary assessment is that this policy falls within this category of actions and that no extraordinary circumstances exist which would require preparation of an environmental assessment or environmental impact statement. A final determination will be made upon adoption of the final policy. Regulatory Impact This proposed policy has been reviewed under USDA procedures and Executive Order 12866 on Regulatory Planning and Review. It has been determined that this is not a significant policy. This policy will not have an annual effect of $100 million or more on the economy nor adversely affect productivity, competition, jobs, the environment, public health or safety, nor State or local governments. This policy will not interfere with an action taken or planned by another agency nor raise r legal or policy issues. Finassy, this action will not alter the budgetary impact of entitlements, grants, user fees, or loan programs or the rights and obligations of recipients of such programs. Accordingly, this proposed policy is not subject to OMB review under Executive Order 12866. Moreover, this proposed policy has been considered in light of the Regulatory Flexibility Act (5 U.S.C. 601 et seq.), and it has been determined that this action will not have a significant economic impact on a substantial number of small entities as defined by that act. The phase-in of annual fees proposed in this notice will allow small entities to adjust to the new fees over a period of time, and thus minimize the risk of adverse impact on some businesses because of the magnitude of the increases in some fees. No Takings Implications This policy has been analyzed in accordance with the principles and criteria contained in Executive Order 12630, and it has been determined that the policy does not pose the risk of a taking of Constitutionally protected private property. Civil Justice Reform Act This proposed policy has been reviewed under Executive Order 12778, Civil Justice Reform. If this proposed policy were adopted, (1) all State and local laws and regulations that are in conflict with this proposed policy or which would impede its full implementation would be preempted; (2) no retroactive effect would be given to this proposed policy; and (3) it would not require administrative proceedings before parties may file suit in court challenging its provisions. Unfunded Ma tes Reform Pursuant to Title II of the Unfunded Mandates Reform Act of 1995, which the President signed into law on March 22, 1995, the Department has assessed the effects of this policy on State, local, and tribal governments and the private sector. This policy does not compel the expenditure of $100 million or more by any State, local, or tribal governments or anyone in the private sector. Therefore, a statement under section 202 of the Act is not required. /s/robert c. joslin 7/8/97 Acting Chief . (dated) Ny ae Municipality of Anchorage Municipal Light & Power Rick Mystrom, Mayor 1200 East First Avenue Anchorage, Alaska 99501-1685 May 5, 1997 Telephone: (907) he for] Velqy MAY 0 9 1997 rane = Alaska Industrial Development rt Authori 480 West Tudor Road and Export Authority Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of April 1997. // Doug Hall Chief Power B her DH/pjc Attachment CG: T. Stahr, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA Putting Energy into Anchorage for Over 60 years ¢:\1-patty\IOC\so-oprtr\usage\cov-Itr.doc 05-May-97 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY YR TOTAL ENERGY $ YTD MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY YR TOTAL ENERGY $ YTD ALASKA INTERTIE USAGE REPORT FY 97 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA oO 1075 3581 877 587 1535 10980 11838 2622 5770 38865 MLP DELIVERIES CEA DELIVERIES BL DELIVERIES 0 1075 3581 877 587 1535 10980 11838 2622 5770 38865 ©0800 FD oO oO eo Oo 31281 35392 34975 14212 12622 29635 25499 11474 33632 42965 ° 0 271687 30478 34580 34189 13448 11528 28431 24269 10538 32677 41875 262013 ee e8e8200808 8 82 © oO Co oO 803 812 786 764 1094 1204 1230 936 955 e080 80 Oo OO oO Oo 1090 0 9674 ° ©2002 oO oO oO oO oO 4 coo eo eo oo GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS 33 b Soc 08 © eo BO OU oo e080 oO oO oO oO oO OO oO 30478 35655 37770 14325 12115 29966 35249 22376 35299 47645 0 0 300878 $821,396.94 29 oO 0 5B ° ° 19 ° ° 23 76 0 ©2000 80 8B oO oO oe 00 0 OO Oo oO ©2080 fo oO oO OO Oo FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS $0.0 6208000000000 00 $207. 29 eco FB OO uo 23 oO 0 76 48 B® 020020000 8G OO Oo $10.92 803 812 786 764 1094 1204 1230 936 955 1090 o ° 9674 $26,410.02 B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT ©2800 000000 LINE TOTAL 31314 36467 38556 15094 13209 31170 36498 23312 36254 48758 ° 0 310632 $848,025.36 05-May-97 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ALASKA INTERITE USAGE REPORT FY 97 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS AEGT TO GVEA AEGT TO FMUS GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT 0 cscooaoae Ooo ts 0 eococoaoeoc oe os 0 eococooaecoOao os 0 a 0 escooeocaoeoao aod 0 coooeooOeC os MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES FMUS DELIVERIES 0 ecco eo OOOO OC 0 cooeo oO OO OOO Ct 0 sooo OoO OOO OO OC 0 ecooo eo oO eOC OOOO ts ecooeo oO OO OO OOO 0 ecocooacoaeao sd 0 ecocooaec oa os 0 i 0 ocooo eo OO CO 0 i cooeo oO OOOO ts GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL 0 ecoooea oe OOO os $0.00 0 ecocoaoeo oe OOOO ts $0.00 0 ecooo Oo OOOO OC OS $0.00 0 eococoeo oO OO COCO $0.00 0 seocoo eo OOOO OC OS $0.00 coo eo oO eC OC OC COC St $0.00 Gv GOLDEN VALLEY ELECTRIC ASSOCIATION INC. Box 71249, Fairbanks, Alaska 99707-1249, Phone 907-452-1151 ECEIVE I OCT ~ 7 1996 alaska Industrial D October 4, 1996 and Export Neate John Cooley Chairman, Intertie Operating Committee Chugach Electric Association PO Box 196300 Anchorage, AK 99519-6300 Subject: Stevens Substation Reliability | am writing to inform the IOC of MEA’s continued disregard for interconnected system reliability matters. The Stevens Sub was supposed to have reliable communications installed so the substation would not impact the reliability of the Alaska Intertie. On October 3, 1996 we had a relay operation on the Douglas/Teeland line. When GVEA Dispatch called MEA to request that they zero the load at Stevens due to a lack of generation in Fairbanks, the following comment was received: "I'll have to try and find someone and see if | can get them up there and peel the load off.” Once again, when we needed them to be able to operate the substation, they could not. The communications system and RTU at Stevens have the worst reliability record | have ever seen. | think the best way to describe the lack of reliability is to mention their communications/RTU record over the last six months. The Stevens Substation RTU/communication system failed a total of 152 times, and was out of service 47.5 days. | don’t believe that is acceptable performance. Also, we have been promised several times that an underfrequency relay would be installed, but it still hasn’t been put in the substation. This disregard for interconnected system reliability can not continue . The attached letter clearly states what MEA was required to do in order to operate a tap off the Intertie. Since they completely disregard all agreements they make, | am officially GOLDEN VALLEY ELECTRIC ASSOCIATION INC. Stevens Substation Reliability October 4, 1996 Page 2 requesting the IOC and the State of Alaska take action to require MEA disconnect the substation until they correct the operational problems that have been ongoing since the substation was energized. hin. bsb- wanin Riddle anager of System Operations cc: Stan Sieczkowski. AIDEA Brad Evans GVEA ON State of Alaska Walter J b:cxa:. Governor | sfeyvrt iH ml Alaska Energy Authority i ei \rk KX. J / A Public Corporation TTT Z July 28, 1992 iy Comet iit aie || / cy: Mr. James Hall Ma i i) e Matanuska Electric Association, hn P.O. Box 2929 Palmer, Alaska 99: Subject: ie Talkeetna Substation/Anchorage-Fairbanks Intertie Tap Dear Mr. Please reference your recent conversation with Mr. Marchegiani of my staff and the May 13, 1992 IOC meeting. The Alaska Energy Authority approves of the Talkeetna Tap of the Anchorage-Fairbanks Intertie contingent upon MEA fulfilling the requirements of the motion approved by the IOC at their May 13, 1992 meeting. The motion read as follows: "IOC approve the proposed Talkeetna tap by MEA, subject to the installation of PT's with hotline/hotline check, capable of future synchronizing and; MEA address the following issues to the satisfaction of IOC and AEA: - Operating procedures - Review of Final Design - Construction Practices and schedules - SCADA control SCADA microwave communications Control area load following/tieline bias metering control point MITCR ramifications Contract compliance" Please keep Afzal Khan or Eric Marchegiani appraised of your progress with the project. We look forward to working with you on this project. Sincerely, Ronald A. Garzini Interim Executive Difector EAM:RAG:;jd cc: Afzal Khan, Alaska Energy Authority Eric Marchegiani, Alaska Energy Authority Stanley E. Sieczkowski, Alaska Energy Authority Tom.Lovas, IOC Chairman «JOG; OC;Distribution. (see. attached | i list) O PO, Box 110809 Juneau, Alaska 99811-0809 (907) 465-3575 &% PO. Box 190869 704 EastTudor Road Anchorage, Alaska 99519-0869 (907) 561-7877 92Q3\D3291(1) Mr. David Burlingame Mr. Tim McConnell Chugach Electric Association Anchorage Municipal Light & Power 560 r Minnesota Drive 1200 E. First Averue P.O. Box 196300 Anchorage, Alaska 99501 Anchorage, Alaska 99519-6300 on 263-5453 907) 276-4789 i {073 562-0027 (FAX) Paty EIS co ee) Mr:Robert Orr, Mr. Sam Matthews .. Golden’ Valley Electric Association Alaska Electric Generation & Transmission P.O. Box 1249 Cooperative Fairbanks, Alaska 99707 P.O. Box 169 eu peel oe “0556 (FAX) (09 478-8551 907) 235-3313 (FAX) Mr. Jim Hall Matanuska Electric Association P.O. Box 2929 Palmer, Alaska 99645 507 745-9266 907) 745-9328 (FAX) 92Q3\JD3287(1) lectric ASSOCIATION, INC. CHUGACH ELECTRIC Y Cw ach BX ASSOCIATION, INC. a DECEIVE |) MAY - 8 1997 May 5, 1997 Alaska Industrial Development ; : and Export Authority Stan Sieczkowski Alaska Energy Authority 480 West Tudor Anchorage, Alaska 99503 Subject: Modification of Teeland Substation, AEA Portion Dear Stan: As indicated in the attached memo from Mike Massin, Director of Engineering, Chugach has installed a 75 MVA transformer in its portion of the Teeland Substation which can be used under emergency conditions to transfer power between the Alaska Intertie and the MEA/Chugach system. Chugach plans to install circuit breakers, bus work and relay and control equipment to allow this transformer to operate continuously. Chugach requests permission from AEA to connect this transformer to Structure #79A of the Alaska Intertie as shown on the attached one-line diagram. In addition, Chugach requestspermission from the IOC to operate this transformer in parallel with the existing 100 MVA, 230/138 kV AEA transformer. Both transformers are within the Chugach control area so there should be no power scheduling implications. Appropriate metering will be installed as shown on the one-line diagram. System losses should be reduced slightly due to the parallel path. System studies have shown that parallel operation of this transformer will increase system reliability and stability. Sincerely, S. Cooley, PE Manager, System Plannt Attachment: Director, Engineering Division memo of 4/15/97 cc: Larry Colp, FMUS w/att. Jim Hall, AEG&T/MEA w/att. Sam Matthews, AEG&T/HEA w/att. Tim McConnell, ML&P w/att. Marvin Riddle, GVEA watt. JSC:TS JSC10268.WPD 5601 Minnesota Drive * P.O. Box 196300 * Anchorage, Alaska 99519-6300 Phone 907-563-7494 * FAX 907-562-0027 RECEIVED CHUGACH ELECTRIC ASSOCIATION, INC. APR 17 1997 Anchorage, Alaska SYSTEM April 15, 1997 PLANNING TO: John Cooley, Manager, System Planning if THROUGH: Mike Massin, Director, Engineering Division WW]. FROM: Dora Gp. Manager, Transmission & Special Projects SUBJECT: — Teeland Substation Improvements 75 MVA Transformer 138/115kV, W.0.#E9620119 A 75MVA transformer is presently installed at the Teeland Substation and can be used under emergency conditions to transfer power between the Anchorage/Fairbanks Intertie and the MEA/Chugach system. It is intended to install circuit breakers, bus work and relay and control equipment to allow this transformer to operate continuously. System studies have been performed and they indicate that operation of this transformer would increase system reliability and stability. The enclosed One Line Operators Diagram (Drawing #TLSS-EL-0001/E9620119) shows the intended connection. The installation is expected to be operational by late summer of this year. At that time the following items should be agreed to by the IOC and the owner(s) of the Anchorage/Fairbanks Intertie: l, Operation of the 75 MVA Transformer in parallel with the AEA transformer (1OOMVA, 230/138kV) 2 Physical connection to the Anchorage/Fairbanks Intertie on Structure # 79A Revenue accuracy metering equipment will be provided on the 115 and 138kV side. Synch check relays will prevent energization under assynchronous conditions. Power flow is expected primarily to the north, but can be reversed. If the 1OOMVA transformer - and with it the SVC system - is not operational, transfer will be limited to TSMVA. DGL/ahw (C/ANNALISA\WPDOCS 9620119 TLIOC.WPD. Enclosure: Drawing #TLSS-EL-0001/E9620119 ic Jim Wilson, w/ Mike Wood, w/ Brian Hickey, w/ Dave Grooms, w/ W.0.#E9620119, Sec., RF LISKV TO MEA ANDERSON Lusky To MEA HERNING SKY TRANSFER x SITE BAY 230KV TO CEA PT. MACKENZIE a3] =x) sar | See Pees | EGER Toate] | \s 230. 000/115. 000-34, 500¥ 34,500~120/240v | '50/200/250MVA 30/40/SOMVA TERT. [ios w 138 000/113 000- 34.300 v 'SSUED FOR CONS ™#UC’ OW 2/30/85 ASBUALT ACCOXMT NO 77198 4 wOWD SOTS Tere ADDED MEW TT. ROO 277796 x STATION SERVICE 13, 800-120/240¥ TSKVA 3 J _ 230. 000-138, 000-13. 800¥ EE] THYRISTOR CONTROL, 5601 Minnesota Drive P.O. Box 196300 Anchorage, Alaska 99519-6300 STRATE z 138KV TO APA OOUGLAS 73 TEELAND SUBSTATION ONE LINE OPERATORS DIAGRAM — PRT VOUS REFERENCE (db [waoaro/ iim /eivet V0) G04 3 8/7/96 TLSS-EL-0001/E9620119 CERTIFIED MAIL RETURN RECEIPT REQUESTED DECISION David Nicklie General Delivery Cantwell, Alaska 99729 State of Alaska Department of Natural Resources Division of Land Realty Services Section 3601 C Street, Suite 960 Anchorage, Alaska 99503-5936 Abtna, Inc. P.O. Box 649 Glennallen, Alaska 99588 State of Alaska Department of Transportation Northern Region, Right of Way Section Attn: John A. Miller Chief Right of Way Agent 2301 Peger Road, MS-2553 Fairbanks, Alaska 99709-5399 United States Department of the Interior rt tate ehh & BUREAU OF LAND MANAGEMENT Alaska State Office ~ 222 W. 7th Avenue, #13 Anchorage, Alaska 99513-7599 a EUV Alaska Industrial Development . and Export Authority F-14372 (2561) F-034722 (2620) F-034738 (2620) il F-14844-A (2651) a {|p { F-030599 (2821) F-13845 (2821) ~ AA-44361 (2800) AA-53912 (2850) PPP Win 539 (962) JP/BC NOVEMBER 1 3 1996 F-14372 Native Allotment Application F-034722 Community Grant State Selection Application F-034738 State General Grant Selection Application F-14844-A Village Selection Application F-030599 Material Site Right-of-Way Grant F-13845 Federal Aid Right-of-Way Dike Project Denali Highway Alaska Energy Authority : AA-44361 480 W. Tudor Road : Right-of-Way Facility Anchorage, Alaska 99503 : Grant, Intertie and Substation _ Golden Valley Electric Association : AA-53912 P.O. Box 71249 ; Power Transmission Line Fairbanks, Alaska 99707 : Right-of-Way Grant Native Allotment Application Approved State Selections Rejected in Part Village Selection Rejected in Part Native Allotment Not Subject to Denali Highway Native Allotment Subject to Material Site Right-of-Way F-030599 Federal Aid Highway Right-of-Way F-13845 Null and Void in Part Native Allotment Subject to Power Transmission Line/Intertie R/W AA-44361 Native Allotment Subject to Electrical Distribution Line Right-of-Way AA-53912 On October 4, 1971, the Bureau of Indian Affairs (BIA) filed Native allotment application F-14372 and evidence of use and occupancy on behalf of David Nicklie. The application, which was filed under the provisions of the Act of May 17, 1906,' was before the Department on February 2, 1971. The application indicates use and occupancy since May of 1950, for lands located within Secs. 2 and 3, T. 18 S., R. 7 W., Fairbanks Meridian. The lands have since been surveyed and are currently described as Lots 1 and 2, U.S. Survey No. 11154, Alaska, containing 154.96 acres. Allotment Application Not Legislatively Approved The Native allotment application was not legislatively approved and must be adjudicated because the lands were validly selected by the State of Alaska on August 9, 1965. Section 905(a)(4) of the Alaska National Interest Lands Conservation Act of December 2, 1980 (ANILCA), 43 U.S.C. 1634 (1988) provides that: Where an allotment application describes land . . . which on or before December 18, 1971, was validly selected by . . . the State of Alaska pursuant to the Alaska Statehood Act and was not withdrawn pursuant to Sec. 11(a)(1)(A) of the Alaska Native Claims Settlement Act .. . [it] shall be adjudicated pursuant to the requirements of the Act of May 17, 1906, as amended, the Alaska Native Claims Settlement Act, and other applicable law. 'The Act of 1906 as amended, 43 U.S.C. 270-1 to 270-3 (1970), was repealed with a savings provision by Sec. 18(a) of the Alaska Native Claims Settlement Act of December 18, 1971 (ANCSA), 43 U.S.C. 1617(a) (1988). 3 Also, on January 20, 1994, a legally sufficient protest was filed by Dianna Johnson under the criteria set forth in Sec. 905(a)(5) of ANILCA. Section 905(a)(5) states in pertinent part: ... the Native allotment application shall be adjudicated pursuant to the requirements of the Act of May 17, 1906, as amended, if on or before the one hundred and eightieth day following the effective date of this Act-- (C) A person or entity files a protest with the Secretary stating that the applicant is not entitled to the land described in the allotment application and that said land is the situs of improvements claimed by the person or entity. Native Allotment Application Approved In his application, David Nicklie stated that he resided on the lands claimed as his allotment from May through November each year from 1950. A field examination of the claim was conducted by a Bureau of Land Management (BLM) realty specialist on June 21, 1973, at which time the examiner interviewed the applicant, noted physical signs of occupancy (specifically a trailer, which, according to other residents of the area, was predated by a tent frame), and identified potential conflicts. In his report of the examination, the realty specialist concluded that Mr. Nicklie had met the minimum use and occupancy requirements for qualification for a Native allotment application. However, on March 21, 1983, an amendment to the description of Mr. Nicklie’s amended allotment claim was received by BLM. Due to the amendment and several conflicts between Mr. Nicklie’s allotment application and other land interests (another allotment application, patents, and rights-of-way), a supplemental field examination was requested in 1990. On September 5, 1991, the BLM realty specialist completed a supplemental field examination of the claim and addressed several existing conflicts. He noted a partial conflict between Mr. Nicklie’s allotment claim and the allotment claim of Stuart Baker. Mr. Baker’s allotment has since been rejected thereby eliminating any conflict. Evidence of the applicant’s use of the land was documented as being the same improvements found in the earlier exam 17 years prior. The improvements located were the trailer, a camper and a 30’ x 50’ well-tended vegetable garden. In addition, the applicant had begun to use the land for storage of several automobiles and trucks which were also present. In his report, the examiner concluded that for the uses claimed by Mr. Nicklie, those being for residence and storage, the applicant had met the requirements of the Act of 1906. Absent any refuting evidence as to the validity of Mr. Nicklie’s allotment claim, further supporting evidence of his use would not have been required in order to approve his allotment claim. However, information refuting Mr. Nicklie’s use was submitted to BLM by Dianna Johnson in her affidavit and letter dated March 8, 1996. Ms. Johnson’s knowledge of the applicant’s use of the allotment land came from her years spent recreating nearby on a headquarters site claim applied for by her then husband in 1965. The headquarters site application was later rejected by the BLM on August 20, 1970. David Nicklie does not claim as a part of his Native allotment the land within the rejected headquarters site. This decision addresses only that knowledge which Ms. Johnson has regarding Mr. Nicklie’s use of his allotment claim and does not address other land claim issues Ms. Johnson may have with respect to the previously rejected headquarters site or access thereto. The following information is from Dianna Johnson’s affidavit: In 1965, Dianna Johnson and her husband met the family of David Nicklie upon their arrival in the Cantwell area. At that time, Ms. Johnson observed that the Nicklie family resided approximately 1.5 miles from the present location of the Nicklie allotment. From 1965 through 1968 Ms. Johnson did not see any evidence of use on the allotment claim, including that which might be associated with a permanent or temporary residence. It was in 1970 that Dianna Johnson recalls Mr. Nicklie moving a trailer onto the allotment claim. This appears to be the extent of Ms. Johnson’s personal knowledge of David Nicklie’s use of his allotment claim prior to his filing the application for an allotment. In addition to her personal observations, Ms. Johnson brought attention to the applicants age at the time he claimed to have begun using and occupying the land, and the credibility of certain witness statements offered in support of Mr. Nicklie’s allotment claim. These factors were considered in the adjudication of the allotment claim. On his application, David Nicklie claimed to have commenced use and occupancy of the allotment land in May of 1950. Since Mr. Nicklie was born in 1941, he would only have been about 9 years old at that time. This might be considered a young age for a boy to be using the land substantially and independent of others. However, in order to qualify for a Native allotment in this location Mr. Nicklie could have started using the land at any time prior to the filing of the state selection applications in 1965, because from 1950 until 1965, it was vacant and unappropriated public lands. On August 9, 1965, when the State filed its applications, Mr. Nicklie was 24 years old and could have been independently using the land for several years. Aside from the two BLM field examinations that were favorable to the claim, there is other evidence supporting Mr. Nicklie’s use of his allotment. The casefile contains notarized affidavits from 11 long-time residents of the Cantwell area and a letter from Ahtna Regional Corporation. While Mr. Nicklie did not state on his application that he used his allotment land for purposes other than a seasonal residence and storage, his affidavit and that of the many residents of Cantwell recount that he also used different portions of the land for subsistence activities such as fishing in the Jack River, hunting moose, caribou, porcupine, spruce hens, ptarmigan, trapping ground squirrels, snaring rabbits, and berry and wild celery picking. All of the aforementioned activities are associated with a traditional and customary Native lifestyle which leave little trace of physical evidence. The affidavits from the residents in the Cantwell community all verify that they witnessed, or had knowledge of, David Nicklie performing these activities either in support of his family subsistence needs or for himself since the early 1950’s. Considering the personal knowledge of Ms. Johnson, the knowledge of 11 other residents of the Cantwell area, and the physical evidence found by the field examiners, it appears that Mr. Nicklie has provided substantial information to support his use of the allotment land claimed. Based upon adjudication of the application, this office has determined that at the time the claim was initiated, the lands were vacant, unappropriated and unreserved and the applicant has satisfied the use and occupancy requirements of the Act of May 17, 1906, as amended. Therefore, allotment application F-14372 is hereby approved for the lands described above. State Selection Applications Rejected in Part On August 9, 1965, the State of Alaska filed community and general purposes grant selection applications F-034722 and F-034738, respectively, pursuant to Sec. 6(b) of the Alaska Statehood Act of July 7, 1958 (72 Stat. 339), as amended, for lands in T. 18 S., R. 7 W., Fairbanks Meridian, including lands encompassed by Native allotment application F-14372. Section 6(b) of the Alaska Statehood Act of July 7, 1958, provides that the State may only select vacant, unappropriated, and unreserved public lands in Alaska. The lands described above were appropriated by the occupancy of the Native applicant at the time of State selection. Therefore, State selections F-034722 and F-034738 are rejected as to the lands described above and all the minerals therein (except as addressed below with respect to granted material site right-of-way F-030599). Village Selection Application Rejected in Part On May 3, 1974, Ahtna Incorporated (successor-in-interest to Yedatene Na Corporation) filed village selection F-14844-A, as amended, under the provisions of Sec. 12 of ANCSA for lands in T. 18 S., R. 7 W., Fairbanks Meridian, including lands in Native allotment application F-14372. The subject lands were segregated by the Native allotment application at the time of village selection. Application F-14844-A is therefore rejected as to the land described above. Adjudication of Rights-of-Way The State of Alaska has interests in three rights-of-way associated with Native allotment F-14372. Those rights of way are the Denali Highway, granted material site F-034722, and federal aid dike project F-13845 on the Jack River. Each right- of-way will be separately addressed. Denali Highway Native allotment application F-14372 is currently described as Lots 1 and 2 of U.S. Survey No. 11154. The allotment was conformed to this survey by notice dated July 31, 1995. The State of Alaska received copies of this notice and survey maps attached thereto. The survey clearly depicts the allotment claim as lying either north of the northerly right-of-way boundary of the Denali Highway or south of the southerly right-of-way boundary of the Denali Highway. Therefore, as there exists no conflict between the highway right-of-way and the surveyed allotment, the certificate of allotment when issued will not be made subject to the Denali Highway. Material Site On December 19, 1962, the State of Alaska applied for material site right-of-way F-030599. The right-of-way was granted to the State on February 18, 1963. The granting of the right-of-way predates the filing of David Nicklie’s allotment application in 1971, however, it does not predate the commencement of Mr. Nicklie’s use of the land. In 1975, mineral examinations of the Nicklie allotment and that of the conflicting allotment claim of Stuart Baker (since rejected) were performed to determine if the allotments were mineral in character. Since material site right-of-way F-030599 was wholly encompassed within the descriptions of the two allotment claims, the site was analyzed and included in the mineral reports of both allotment claims. The mineral determinations on the Baker and Nicklie allotments concluded that they were non-mineral in character except for those portions of the allotment claims located within the State’s material site right-of-way. The land within the right-of-way F-030599 was determined to be, at that time and in years prior, valuable for sand, gravel, and riprap. If Mr. Nicklie’s allotment claim had been timely adjudicated in 1975 after receipt of the mineral determination, his claim would have been rejected as to the lands located within the material site. It was not until 1980, when ANILCA was enacted, that sand and gravel were no longer considered minerals for the purposes of mineral determinations on Native allotment claims. 7 Recent decisions issued by the Interior Board of Land Appeals (IBLA) address the allotment claim of Mary Sanford. Similar to Mr. Nicklie’s claim, Mary Sanford’s allotment was also determined to be valuable for sand and gravel in the mid- 1970’s (1973) for a portion of the claim conflicting with a material site right-of-way granted to the State of Alaska in the 1960’s (1966). In Ahtna, Inc. 100 IBLA at 17-18, the IBLA examined whether lands embracing deposits of gravel are properly deemed mineral in character and concluded the following: . .. [W]e must conclude that prior to passage of section 905(a)(3) of ANILCA in 1980, 43 U.S.C. 1634(a)(3) (1982), lands valuable for gravel were mineral lands not available for disposition under the Alaska Native Allotment Act and the regulations promulgated thereto . . .[Emphasis added.] . .. Thus, prior to the passage of ANILCA in 1980, Sanford would not have been able to obtain an allotment for the land embracing the gravel deposit. . . . Sanford’s Native allotment application was subject to rejection for the lands embraced in the gravel deposit . . If adjudication had proceeded in its proper sequence, Sanford’s application would have been rejected as to the gravel lands . . . [Emphasis added.] The IBLA further addressed the issue in State of Alaska, Department of Transportation and Public Facilities 131 IBLA at 127-128: Accordingly, we find that the allotment applicant’s preference right to an allotment cannot as a matter of law relate back to the initiation of use and occupancy with respect to the mineral land located within the State’s mineral material site right-of-way. ... While section 905(a)(3) of ANILCA defined "nonmineral" lands to include lands valuable for gravel, this provision did not retroactively invalidate the material site right-of-way. Consequently, there is no basis for finding that the State material site issued in 1966 was preempted and is null and void. [Emphasis added.] Therefore, on the basis of the IBLA’s reasoning as outlined above, the certificate of allotment when issued shall be made subject to the State’s granted material site right-of-way F-030599. Jack River Dike Project The third right-of-way interest held by the State is for the dike constructed on the northern bank of the Jack River, BLM serial no. F-13845. On April 27, 1971, the State of Alaska, Department of Highways applied for a right-of-way to begin construction of dike project no. F-052-2(1). Authorization for the right-of-way was granted on April 18, 1974. A portion of the allotment described as Lot 1 of USS 11154 is affected by the dike right-of-way in that it appears to be located within the original description of the right-of-way. From a review of the allotment survey, noting its size and shape and proximity to the Jack River, a conflict may not exist between the allotment and the actual dike as constructed on the northern bank of the Jack River. However, any portion of the right-of-way grant which conflicts with the allotment claim must adjudicated. Part 1 of the "Terms and Conditions of Grant" attached to and made a part of right-of-way grant F-13845 states that the grant was issued subject to all valid rights existing on the date of the grant. The allotment claim was a valid existing right at the time the right-of-way was granted. Therefore, right-of-way grant F- 13845 is hereby determined null and void in part to the extent that it conflicts with a portion of Native allotment F-14372 within Lot 1 of USS 11154. Willow to Healy Intertie On March 38, 1982, the Alaska Power Authority, now the Alaska Energy Authority, filed a right-of-way application for a power transmission line from Willow to Healy, Alaska, BLM serial no. AA-44361. A substation for that power line is also included in the right-of-way. Both the power line and the substation are located on the allotment claim of David Nicklie. The right-of-way grant was issued excluding the lands within the unapproved allotment claim on June 17, 1983. The grant was later amended on July 22, 1983, to include the allotment lands after the BIA filed a letter of non-objection to the issuance of the right-of-way grant. Therefore, the certificate of allotment when issued will be made subject to the terms and conditions of amended right-of-way grant AA-44361. Electrical Distribution Line On June 18, 1984, Golden Valley Electric Association filed right-of-way application AA-53912 for an electrical distribution line which in part crosses the Native allotment claim of David Nicklie. On November 27, 1984, the BIA issued a letter of non-objection to BLM for inclusion of the allotment lands in the right-of-way when granted. The BLM subsequently issued the granted right-of-way, including the lands within the allotment claim on April 26, 1988. Therefore, the certificate of allotment when issued will be made subject to the terms and conditions of right- of-way grant AA-53912. Allotment Not Subject to Mineral Reservation All applications approved pursuant to the Act of May 17, 1906, are subject to the provisions of the Act of March 8, 1922, as amended, 43 U.S.C. 270-11 (1982) (repealed, with a savings clause, effective 1986) and 270-12 (1982) (amended, with 9 a savings clause, effective 1986). It has been determined that the above-described lands are without value for minerals (except as addressed above with respect to granted material site right-of-way F-30599); therefore, none shall be reserved to the United States. Reservations in Certificate of Allotment The Certificate of Allotment will reserve the following to the United States: A right-of-way thereon for ditches or canals constructed by the authority of the United States. Act of August 30, 1890, 43 U.S.C. 945 (1988). This allotment shall be subject to: 1. Material site right-of-way F-030599, granted to the State of Alaska on February 18, 1963, pursuant to the authority of the Federal Aid Highway Act of August 27, 1958, as amended, (72 Stat. 885, 23 U.S.C. 317); 2. Power transmission right-of-way AA-44361, granted to the Alaska Power Authority on March 3, 1982, as amended on June 17, 1983, and modified on May 10, 1984, pursuant to the authority of the Act of October 21, 1976 (90 Stat. 2748, 43 U.S.C. 1761-1771); and 3. Electrical distribution line right-of-way AA-53912, granted to Golden Valley Electric Association on April 26, 1988, pursuant to the authority of the Act of October 21, 1976 (90 Stat. 2743, 43 U.S.C. 1761-1771). Any questions the applicant may have regarding future use relative to the Native allotment or any assistance the applicant may need with the description should be directed to the Alaska Realty Consortium at the following address: Alaska Realty Consortium 401 East Fireweed Lane, Suite 102 Anchorage, Alaska 99503-2111 The telephone number is (907) 276-2772. The State of Alaska has 60 days from receipt of this decision in which to initiate a private contest against the Native allotment application pursuant to Departmental regulation 43 Code of Federal Regulations (CFR) 4.450 (copy enclosed). Failure of the State of Alaska to initiate a private contest within the time indicated above will result in the Native allotment application being approved and the other parties being rejected as to the lands in Native allotment application F-14372. This action will become final without further notice. The State of Alaska has a 30 day appeal period which commences upon expiration of the 10 60 days allowed for initiation of a private contest. (State of Alaska, 48 IBLA 229). All parties not having the right to initiate a private contest who wish to appeal this decision must follow the provisions of the appeal procedures. This decision may be appealed to the Interior Board of Land Appeals, Office of the Secretary, in accordance with the regulations contained in 43 CFR, Part 4, and Form 1842-1 (copies enclosed). If an appeal is taken, the notice of appeal must be filed with the Bureau of Land Management, Alaska State Office, 222 West Seventh Avenue, #13, Anchorage, Alaska 99513-7599, within 30 days from receipt of this decision, except for the State of Alaska who has the appeal period set forth above. Failure to file the notice of appeal with the Bureau within the time allowed is a jurisdictional defect and will result in dismissal of the appeal. In order to avoid dismissal of the appeal, there must be strict compliance with the regulations. The appellant has the burden of showing that the decision appealed from is in error. Copies of the notice of appeal must also be submitted to each party named in the heading of this decision and to the Office of the Regional Solicitor, Alaska Region, U.S. Department of the Interior, 4230 University Drive, Suite 300, Anchorage, Alaska 99508-4626 at the same time the original documents are filed with this office. The following parties must also be served with a copy of the notice of appeal: Alaska Realty Consortium 401 East Fireweed Lane, Suite 102 Anchorage, Alaska 99503-2111 Dianna Johnson c/o Gerald Sharp, Attorney Preston, Thorgrimson, Shidler, Gates and Ellis 420 L Street, Suite 400 Anchorage, Alaska 99501 The Departmental regulations in 43 CFR 4.21 (58 FR 4939, copy enclosed) provide that parties entitled to file an appeal may file a request for a stay of the effectiveness of this decision during the time that the appeal is being reviewed by the Board. The request for a stay must accompany the notice of appeal submitted to the Bureau of Land Management (BLM) and a copy of both documents must be served on the Interior Board of Land Appeals, Office of Hearings and Appeals, 4015 Wilson Boulevard, Arlington, Virginia 22203, at the same time they are submitted to the BLM. A copy of the request for a stay must also accompany each copy of the notice of appeal submitted to the parties listed in the heading of this decision or listed as parties to be served in the preceding paragraph. A request for a stay is required to show sufficient justification based on the standards listed below. 11 Standards for Obtaining a Stay If you request a stay, you have the burden of proof to demonstrate that a stay should be granted. Except as otherwise provided by law or other pertinent regulation, the regulations in 43 CFR 4.21(b) provide that a petition for a stay of a decision pending appeal shall show sufficient justification based on the following standards: (1) The relative harm to the parties if the stay is granted or denied, (2) The likelihood of the appellant’s success on the merits, (3) The likelihood of immediate and irreparable harm if the stay is not granted, and (4) | Whether the public interest favors granting the stay. ww RMA Jenice R. Prutz Land Law Examiner Native Allotment Team Branch of 962 Adjudication Enclosures: Form 1842-1 Appeal Regulations Federal Register Publication (58 FR 4939, dtd 1/19/93) Master Title/Survey Plats Copy furnished to: Alaska Realty Consortium (CM-RRR) 401 East Fireweed Lane, Suite 102 Anchorage, Alaska 99503-2111 (w/enclosures) Bureau of Indian Affairs Alaska Title Services Center (ATSC) 1675 C Street Anchorage, Alaska 99501-5198 (original signature) State of Alaska Department of Fish and Game Habitat and Restoration Division Attn: Robin Willis 333 Raspberry Road Anchorage, Alaska 99518-1599 (w/cy of survey plat) Dianna Johnson (CM-RRR) c/o Gerald Sharp, Attorney Preston, Thorgrimson, Shidler, Gates and Ellis 420 L Street, Suite 400 Anchorage, Alaska 99501 (w/enclosures) DM, Glennallen (050) 12 Ferm 1842-1 . (Fewrsary 1985) UNITED STATES DEPARTMENT OF THE INTERIOR BUREAU OF LAND MANAGEMENT INFORMATION ON TAKING APPEALS TO THE BOARD OF LAND APPEALS DO NOT APPEAL UNLESS 1. This decision 1s adverse to vou, AND 2. You belseve it is incorrect IF YOU APPEAL, THE FOLLOWING PROCEDURES MUST BE FOLLOWED 1. NOTICE OF APPEAL . 2. WHERE TO FILE NOTICE OF APPEAL SOLICITOR ALSO COPY TO 3. STATEMENT OF REASONS SOLICITOR ALSO COPY TO 4. AOVERSE PARTIES 5. PROOF OF SERVICE Within 30 days file a Notsce of Appeal in the office which issued this deci ion (see 43 CFR Secs. 4.411 and 4.413). You may state your reasons for appealing, if yo desire. ALASKA STATE OFFICE 222 W. 7th AVENUE #18 ANCHORAGE. AK. 99512 Within 30 davs after filing the Notice of Appeal. file a complete statement of the reasons why you are appealing. This must be filed with the United States Departmes of the Intenor. Office of the Secretary, Board of Land Appeasis, 4015 Wilson Bivd.. Aslington, Virginia 22203 (see 43 CFR Sec. 4.412 and 4.413). If you fully stated you reasons for appealing when filing the Notice of Appeal, no additional statement b necessary. Within 15 days after each document is filed, each adverse party named in the decisio. and the Regional Solicitor or Field Solicitor having jurisdiction over the State in whic! the appeal arose must be served with a copy of: (a) the Notsce of Appeal, (b) the State ment of Reasons, and (c) any other documents filed (see 43 CFR Sec. 4.413). Servic: will be made upon the Associate Solicitor, Division of Energy and Resources, Wesh ington, D.C. 20240, instead of the Field or Regional Solicitor when appeals are take: from decisions of the Director (WO—100). Within 15 days after any document is served on an adverse party, file proof of the Service with the United States Department of the Interior, Office of the Secretary Board of Land Appeals, 4015 Wilson Bivd., Arlington, Virginie 22203. This may con sist of a certified or registered mail ‘Return Receipt Card’’ signed by the adverse part: (see 43 CFR Sec. 4.401(¢X2)). Unless these procedures are jollowed your appeal will be subrect to dismissal (see 43 CFR Sec. 5.402). Be certam thar al communications are identified by serial number of the case berng appealed. NOTE: A document 13 mor filed until 1 1s actually recerved m the proper office (see 43 CER Sec. 4.401 a)) SUBPART 1821.2--OF FICE HOURS; TIME AND PLACE FOR FILING 1821.2=1 Office bours of State Offices. (a) State ces and the Washington Office of the Bureau of 4 Management are open to the public for the filing documents and inspection of records during the 8 specified in this paragreph on Monday through of each week, with the exception of those days the office may be closed because of a national or Presidential or other administrative order. hours during which the State Offices snd the ington Office are open to the public for the filing Ccuments and inspection of records are from 10 a.a. p.m, standard time or daylight saving time, is im effect at the city in which each office FF, gts hit See. 1821.2-2(d) Any document required or permitted to be filed under the regulations of this chapter, which is received in the Stste Office or the Washington Office, either in the mail or by personal delivery when the office is not open to the public shall be deemed to be filed as of the day and hour the office next opens to the public. (e) Any document required by law, regulation, or decision to be filed within stated period, the last day of which falls on a day the State Office or the Washing ton Office is officially closed, shall be deemed to be timely filed if it is received in the appropriate office on the next day the office is open to the public. ® U.S. Government Printing Oftiee:1960-773-016/06030 AB Federal Register / Vol. 58. No. 11 / Tuesday, January 19. 1993 / Rules and Regulations 4839 oe EE TER Re A A A NR a SS SSE SE ST §440.250 Limes en eomparaniiity of wir (b) Ambulatory services for the moadically needy (§ 440.220(e)(2)) may be limited to: (1) Individuals under age 18: and (2) Groups of individuais entitied to institutional services. [FR Doc. 93-880 Filed 1-15-03; 845 am) DLO CODE srasot DEPARTMENT OF THE INTERIOR Cffice of the Secretary 43 CFR Part 4 RIN 1082-AA10 Department and Hearings and Appeais agency: Offices of the Secretary, Intericr. acnion: Final rule. merece ap the effect of ons govern an administrative decision pending appeal before the Interior Department's Office of Hearings and Appeals. The provisions of the ions currently provide that the filing of a notice of ° a skab Guciaee eusiaioenl, wsloes tise fr Director of the Office of Hearings and Appeais or an Appeals Board exercises discretion to provide that the decision appealed from will be in full force and efiect i . Under the amended ean aS erent ll become effective at the expiration of time for filing a notice of s where ho petition for a stay is or 45 days Send aee atc ete appeal where a timely petition fora is filed, uniess the Director or an nit Appeals Board has determined Otherwise in accordance with specified standards. EFFECTIVE DATE: Feliruary 18, 1993. FOR FURTHER INFORMATION CONTACT: Nadine Markbam-ltteilag, Branch of Administrative Law and General Legal Services, Division of General Law. Office of the Solicitor, room 6531. Main lnterior Building, 1849 C Street. NW.. Washington. DC 20240, (202) 208-5216. SUPPLEMENTARY INFORMATION 1. Background and Discussion On Friday. September 25, 1992, the of the Interior published for comment in the Federal Register a Tule to amand its tions at 43 CFR 4.21. which govern the effect of an administrative decision pending appeal before the ‘s Office of Hearings and This rule was proposed in order that there would be an analysis of individual to uicaein tn ianenien| iate rather cvs the curvent rules. wheseby 0 oony regard to whsther a stay of decision is oris sale viene aaa eer substantive right of appeal that who desires a stay an appellant w Bie petition for e stay justifies a is necessary according to specified standards lt should be noted that. as stated in the text of the rule, whenever there is a ee a Royalty Management at30 CFR 243.2 (57 FR 44991, Sept. 30, 1992), the special rule will govern. The of the Interiar Tecsived comments on the Tule from nine sources..Two ofthe . sources were components ofthe © ~- De The Divisian of Energy Mineral Resources of the Bureau of Land (BLM) and the Director of the Ares Office of the Bureau of Indian Affairs (BIA). A summary of the comments and the ... Department's responses to the comments follows. end These concerns and requests for changes to the proposed text of the rule will be addressed in greater detail later in the i : The ninth commenter objected to the Proposed revision and recommended that the proposed rulemaking be withdrawn. The commenter indicated that the revision would allow a decision to be in full force and effect even though the decision would not yet be “final” in that it could be reversed on appeal by one of the Department's Appeais Boards. The commenter argued that to allow « decision to become efisctive while an appeal is still pending and until a final it has been made would unfairly those bei While it is true that, under the revised procedures, an sppellant will need to address the merits of the decision in its ~espect to justifying the uitimate cisposiuen of an sppeal. Propesed Hevision of Other Regulations That Govern Specific Types of Appeais Before the Office of Heanngs and Appeals Two commenters referenced current petitions for rulemaking that wovid amend other provisions governing the Depanment's appeals process. One commenter expressed the view that amending the specific ions governing coal mining appeals would be preferable to amending the Department's general administrative apbeal provisions. . This rciemaking does not preclude ihe consideration of revisions to other portions of the Department's sppesis 7egulations such as those referred to by ‘Se commenters. The Department telieves, however, that amending the Seneral stay provisions is an appropriate way to deal with its concerns about stays of decision pending sppeais. The peutions for other rulemaking referenced by the commenters are cutside the scope of this rulemaking but are being fuily considered by the appropriate Departmental offices. Effect of the ule on the Bureau of iadien Affeirs’ Leasing Programs The commenter from the BIA raised s cancarn about the ejiect of the preposed revision on the BIA's leasing programs. The commenter explained thatthe BLA has a policy commitment to lease ail lands net currently under lease in order to ensure a continued flow of income to its wards pursuant to its trustee responsibilities. If the BLA cancels 8 tease held by an inaividual and the - cancellation were to go imto full force « iad effect pencing areal: the BIA's tulfillment of its commitment ‘o issue 8 naw lease to a diferent lessee would ‘ixely occur before all e | avenues were exhausted. Were the original decision of the BIA ultimately to be overturned by the Interior Boerd of ‘adian Appeais, the BLA would be exposed to further lease cancellation proviems. The potential difficulties that concern cae BLA commenter may be easily sve:ded, however, if the BIA refrains Som issuing new leases while en iar which a stav is not pending before the Board of oan Appeals. Toe BIA's commitment to issue leases is a policy that is capable oi suspension in anv particular pending 2ppeal. Further, anv of Gaveiition governing specific administrative appeais before the Department may be amended to impose different procedures trom those outlined in § 4.21 and to be + on the part excepted, in whole or in part. from the provisions in § 4.21. Retreactive Effect Two commenters suggested that the ew regulation should be epplied to existing appeals before the Offics of Fiearnngs and Appeals. Given that the rule wiil require the Office of Hearings and Appesis to begin ruling on petitions for a stay oi Gecision. the Depastment belisves it would be unwise to overwhelm the Office et chs outset by encouraging an inundation of petitions for cases that are currently pending before the Office of Hearings and Appeals. Further, it wouid be unfsir Sone ies Se existing appellants. The Depart=snt. after giving much consideration to the matter, has concluded that the new rule shall net be given retroactive effect. Authomty of the Secretary of the Interior To Take jurisdiction of an Appeal Cnue commenter belisved that the language granting the Director cr an #.ppesis Board the sutharity to order that a decision be pencing eppeal implied that the Secretary would lacx the same and could be constrced to restrict the Secretary's" power under 43 CFR 4.5 to assume jurisdiction of any sppeais matter at any stags. The commenter suggested that the — Secretary may order a decisicn to be in eifect immediately. The Department with the commanter’s concern that the language of the rule implies any lack of authority . Of the Secretary. Just as the current lan of § 4.21, which refers only to the Director or an Appeels Board SS ee on the part of the Secretsry, neither does the wording of the amended rule. The provisions of 43-CFR 4.5(a) are quite clear that the Secretary may take jurisdiction of any cese before any pagllayen'ar emuivweesal Wek a ecm noe ep, poem ed review any decision of an employee or employees, or direct reconsideration of 8 decision. The believes that to reference the in the text nae Director cr an Appeals Board might Ee same time limits imposed upon the Office of Hearings and Appeals in reaching a determination on a stay issue. The Department prefers to svoid any implication of such a limit upon the een nL ere ey 4 3940 Federal Register / Vol. 58. No. 11 / Tuesday, January 19, 1993 / Rules and Regulations Ss ®®.::??:':r:!==ii"““""!""""_ rE The “75-day Grace Period” Three commenters believed thst the Depertrent should eliminate provinces in the proposed rule that couid prevent a Cecision Som eifecuve icr ee ean expires, in the event that 3 petition e sey is filed. The commenters that the ruie be revised to indicate that e Cepartmental decision tS senpl per snicy wet bar mh pencency ofan beginning ae eetan one determined otherwise. Two comman:ers parvpraphs (N31 (0X2) eed GS) ia 2 order to accomplish this - iy ee ser len nr eerie concerns and declines to Sareea enemas yeep» ttpormedid once I Que of the primary purposes the al ito ply th Depron process. The Department ion Gok fall donde tone effective before the time for filing en appeal has expired, and before the ee the opportunity to give cunsiteostion to 0 pathilem Sera stay, the appeals process could become mere combersome and complex than - warranted. Further, the revision ts ths sale is intended to eliminate “automstic” in the appeals process, and to allow instead ior analysis of the merits of individual a meted is appropiate. The Department believes thst in order to afford equitable treatment to all parties it is better, for purposes of this ruta, to postpone the effective date cia. escision for the minimal time of up to 75 days from the date of the initia) decision in order to afford the opportunity to determine whether a sisy of decision pending eppeal is Ga commenter noted en inconsistency between ena peaadnn tak peepee” pre mre pe pay rer sm in full force and effect and the text of the rale. The inconsistency bas been corrected in the summary text of this notice. Federal Register / Vol. 58. No. 11 / Tuesday, january 19. 1993 / Rules and Regulations 494° a EE A SE er RARE SSDS SET TT SEES NN ————e=—_—S g__—X—_—_C_Ce——oooeeeee ree_—c® ee a —v—vr— a penod for an appellant to file a nee at car tites aeons and Appeals to act on the petition fora stay, before a decision goes into full forse and effect. The cumunanter urged that the provisions in §4.21{a) be aiterec to pisces a Departmental decisicn in full force and effect immediataly to achieve consistency with the provisions of 43 CFR parts 3150 and 3160. Given the wide vansty of Departmental decisions which may be appealed. it may be i te in some circumstances to e decision Tan — a reasonable time in which to files petition for a stay, and in which the Director or an Appeals Board may grent ee ene excepted from de a stay is a desired end. the differences SS ee Sonera wi to decisions into immediate full force and effect based on the types of decisions being made. Division of Section 4.21(a) into Paragraphs (a) and (b) Asothsr commenter was concerned that the text of the rule at proposed § 4.21(a), which would require the . Director or an Appeals Boars to act upon a petition fer a stay within 45 Cays, does not appear to appiy to. situations “other pertinent reguianons,” among the amended provisions of part 3160. The commenter argued that the combined effect of the two rules leaves a “hiatus.” which establishes no time limit within which an Appeals Board must act ona stay - a Ta eapeeeentaneaan ke gee 3160. The commenter requested § 4-2ile) ioctude direction indi how appeilate officials should say which are governed other cedtieabmasstet Sar ~ parts 3150 and 3160 ae pate eae poe br raters to decisions governed ee al appeals example, parts 3150 and 3160. the procedural Provisions in proposed § 4.21) would Ast necessarily have spplied to all Petitions for stays. Therefore, while the Separtment bas retained the provision ‘Eat allows time to file a stay petition before « decision goes effect in § 4.21(a), the procedural changes crested by this rcie have been Seeninr aes ee paragrapa ) so as to apply, except where otherwise provided by jew or other pernnent regulation. to ail petitions for stays to the Director or an es See eens eee is redesignated as paragraph (c), and ewasting paragrann (c) will now decome paragrapa (d). Requirement that the Petition for a Stey of Decision be Submitted With the Notice of Appeal One commenter suggested that the final ruis make clear that stay requests will not be entertained unless they are filed at the time of the notice of appeal. The Department believes that the commenter has inadvertently a Srl eepresd sibs appears in the text at peragraph (a2). The Department believes that the text of the rule makes clear that the petition fore stay is to be cena Tin tesegeent guaran appeal. The Frepeedinpune ty ar egpeed BY the commenter, which would substitute the words “alang with” for “together. rae een e aaeee Two commenters that the listed criteria for whether a stay is appropriate be altered to achieve greater consistency with judicial review guidelines. They that, rather ~ than marely addressing the listed Ctiteria, the applicent for a stay must be ey that the threatened injury to mks _, Spplicant outweighs to the adverse parties against whom the stay is sought, that the likelihood the will succeed on the merits is “substantial”, that there is “substantial” likelihood of immediate harm if a stay is not and that the public interest “will be furthered by” (as opposed to “favors”) the issuance ofa stay. _ The Department declines to an _ bsighten listed in paragraph (b}(1). The © Department believes, as a matter of policy, that a lesser standard is warranted for parties wishing to obtain an administrative review of a decision 8s opposed to judicial review in federal court. - burden of proof the four criteria into full force and The Burden of Proof Necessary To Obtain a Stay of Dec:sion Penaing Arpeal Two commenters suggested that the snouid cleariy state that the to obtain a stay rests with the ap’ peilant. They indicated thei belief that the proposed rale implies that the appeilant must do no more tha “show” the sesnens dec selial, They proposed that the ruis clearly state that the appellant bears the burden of proving that its appeal satisfies each o! the four criteria isted. One comments: in particular appellant's © for a stey must meet each of tt Criteria listed. The commenter also siete to considered to the four listed elements. The commenter further objected ihat t! Tule would allow for the or an Appeais Board to assign greater weight to any of the criteria ov the others in ruling on a petition for a ee provide guidance es to gg eel with the grea rust ofthe comment nd inserted at paregra; (bX 2), and has modified the language spay beh matt ison to cemenseees ia tae esi aareiaiay that a stay is necessary under eech of a with tt comment tin recipe Sn cua a stay, c an Appeais Board is to consider whe ‘all four criteria iisted in §4.2206K1) have been net. The Department believes, however, that the language the rule restricts the appellate official to the four criteria ee modify the text es sugges by the commenter. Further, the aise tar anae necessary to or official in his or her ability to the relative weights of the criteria. Parties Entitled To File a Petition fc Stay of Decision Pending Appeal One commenter that th final regulation provide that only party who has filed a notice ef app: of even if ft co ae ren appeulinizown ee . sp42 Federal Register / Vol. 58, No. 11 / Tuesday, January 19, 1993 / Rules and Regulations —SSSEEEh IEIEIHhH)]“ "!™=™®_™__ commenter and bas added language to the rule to paragraph (a)(2) to provide that oniy a party wao otherwise may file an sppeal with the Office of Hearings and A may file a petition for s suy Service of the Petition for a Stov of Decision Pending Appeal on Affected Parties Three commenters that the rule require that 8 party who files a ed petition for a must serve 6 copy Fuca petition on partes affected by the that such affected parties should bave the right to file a respanse to the ——e ee service on. a copy per time for a eee to 3 possible, siden is prelenbie response to 8 is pre: to a longer period. Further it is the Department's position that the procedures added in §4.22(b)(3) will allow sufficient time for the appellate official to fully consider the merits of a petition for a and thereto. In order that the appellate official will have time to decide a issus within the 45 day limit, it Poa i to provide far replies to responses in the rule. The Department declines to adopt the i to a response in deciding on a petition for a stay. Such a change necessary because the rule doses not provide for paruss to reply toa The Department has declined to adopt pa perdtas aeatabe ire 4.21 i i bearing on a petition for 0 otey. Tho e officials in the Offices of Hearings and Appeals may hold hbearmgs. if they deem it necessary, in accordance with the euthorities and Comment on the Text of Proposed Section 4.21(b) One commenter amendment to the §4.21(b) in light of the fact that this reguiations governing es ee of the commenter and bas the Interior has determined that this rule will not cause a taking of private Property. , Poperwork Reduction Act This rule doss not contain information collection i Management and Budget under 44 U.S.C 3501 et seq. - -iThe , into eae redesignsting Environmental Effects The bas determined that this rule is i exciuded from the National Environmental Protection Act (NEPA) process because it is of an technical and procedural nature, and thereiore neither an environmental assessment nor an environmental impect statement is required. (40 CFR 1508; 518DM23A). Executive Order 12778, Civil Justice Reform The Department of the interior has cartified to the Office of Management onesie eppliesbie sumiatis eeridid meets in sections 2{a) and 2(b}(2) of Executive Order No. 12278. Drafting Information The suthor of this rule is Nedine Markham-ittaileg, Attornsy-Advisor, Branch of Administrative Lew and General Legal Services, Division of Dapmumanr ai Gea bess seer anit NW.. Washington, DC 20240. List of Subjects in €3 CFE Part 4 Administrative prectice and. procedures, Civil rights, Claims, Equal access to justices, Government contracts, Grazing lands, Indians, Lawyers, Mines. Penalties, Public lands, Surface mining. ‘This final rule is issued under the of 43 US.C 1201. ecu CPR 421 is tovioad to read a to Tithe entharity citation for part 4 cantizuss to read as follows: a Autharity: B.S. 2478. as amended, 43 - US 2201, unless otherwise noted: 2. Section 4.21 is amended by become ic) amd ernae redesignated paregraph (cl. ” §421 General provisions. lecizi ti imsttichanas peeidio ras ae (2) A decision will not be effective during the time in which a person adversely affected file a notice of eppeai: when the interest ae nee pom peor ay Appeais may e decision, or any part of a decision. shall be in full force and effective hee eee time daring which « parean odverssly Federal Resister / Vol. 58. No. ————— aifeced may [ile a notice of appeai uniwss a petitica for a stzy pending aopeal is flied togeiaar wih a umeiy nouce of appeai: a petiticn icra stay mav be filed only by a party.who may properly ma:ntain an appeal: (3) A cecasion. or that poruon of & Gecsion, for which a stay is not granted will become effective immediately afer tne Director or an Appeals Board deries cr parualiy denies the petition for a stay, or fails to act on the petition within the time specified in paragraph (b){4) of this section. (b) Stancards and procedures for obtaining a stay. Except as otherwise — by law or other pertinent 1) A petition for a suy of a decision pending sppeel shall show sufficient justification based on the following standards: (i) The relative harm to the parties if the stay is granted or denied. (ii) The likslibood of the appellant's - success on the merits, (iii) The likelihood of immediate and irreparable harm if the stay is not granted. and >] Witt te public interest favor a The a) te the stay bears the cn of poe to demonstrate that a stay should be ted; (3) The spel serve ~ its notice of ap; petition fors stay on each party named in the decision from which the appeal is taken, and on the Director or the Appeais Board to which the appeal is taken. at the same time such documents sre served on the appropriate officer of the Department: any party, inciudirg the officer wno made the decision being appesied. may file a to the stay petition within 10 days after services: failure to file a res: shall not result in a default on the question of whether e stay — be granted: service shall made by delivering copies personally or by sending them by registered or certified mail. raturn receipt requested: (4) The Director or an Appeals Board shall grant or deny a petition for a stay ponding appeal. either in whole or in past. on the basis of the factors listed in Deragraph (b)(1) of this section. within 35 caiendar days of the expiration of the time for filing a notice of appeal: ic) Exhaustion of administrative remecies. No decision which at the time Of its readiticn is subject to appeal to the Director or an A; Board shall Se considered final so as to be agency 2Ction subject to judicial review under 5 U.S.C 704, uniess « petition for a stay of decision has been timely filed and the decision being sppeaied bas been made effective in the manner provided in of * specify operation channel. See 57 FR 21388, parsgrspns :a)(3) or (o)(4) of this section or2 cecsicn has ceen made eiiecuve . ' pending apcesi pursuant to paracraph {3}(1) of this section or pursuant to other Pperinent reguiaucn. (d) eee Datea: Decemper 13. 1992. John E. Schrete. Assistant Secretary. Policy. Management and Budget. IFR Doc. 93-1102 Filed 1-15-93: 8:45 ami ELUNO COOE O1b-an-e Sc: ={=#=== FEDERAL COMMUNICATIONS COMMISSION 47 CFR Part 73 [MM Docket Ne. 90-81; RM-7514] Radio Broadcasting Services; Crestview and Westbay, FL AGENCY: Federal Communications 20, 1992. Channel 284Ci can be Crestview in compliance with the Commission's minimum distance separation requirements, with a site restriction 35.9 kilometers (22.3 miles) south of the community..The- ue coordinates for Channel 284C1 at Crestview are North Latitude 30-26-21 and West Longitude 86-33-43. With this acuon. the proceeding is. terminated. EFFECTIVE DATE: February 25. 1993. FOR FURTHER INFORMATION CONTACT: Lawrence A. Walke, Mass Media Bureau. (202) 634-6530. SUPPLEMENTARY INFORMATION: This is 8 synopsis of the Commission's Memorandum Opinion and Order. MM Docket No. 90-91. adopted December 18,1992. and released january 12. 1993. The full text of this Commission decision is available for inspection and copying during norma! business hours in the FCC Dockets Branch (room 230). 1919 M Street, NW., W . DC. The complet text of this decision may also be purchased from the Commission's copy contractors. Downtown Copy Center, (202) 452— 1422. 1990 M Street_NW., Washington. DC 20036. Tuesday. January 19. 1993 / Ruies and Reguiations 3945 List of Subjects in 47 CFR Part 73 Radio Broadcasting. PART 73—{AMENDED] 1. The authonty citauon for part 73 conunuss to read as foliows: Autharity: 47 U.S.C 154. 303. §72.202 [AMENDED] 2. Section 73.202{b), the Table of FM Allotments under Fionda. is amended by removing Channe/ 284C2 and adding Channel 284Ci at Crestview. Federal Cammunicanons Commission. Deugias W. Webbink. Chief, Policy and Rules Division. Mass Medic Bureau. IFR Doc. 93-1097 Filed 1-15-83: 8:45 em! BLL CODE Erie 47 CFR Part 73 [MM Dockst Ne. $2-220; RM-S075] Radio Broedcasting Services; Moose Lake, MN AGENCY: Federal Communications Seeeintial acnon: Final rule. sumMARY: This document allots Channel 296C3 to Moose Lake. Minnesota. as peat rey pens: epgen 92=45—30. With this action. this proceeding is terminated. window a Sereuhel 200Gs ot Minors Lalo wil open on February 26. 1993. and close on March 29. 1993. POR FURTHER INFORMATION CONTACT: Xathleen Scheverie, Mass Media Bureau. (202) 634-6530. SUPPLEMENTARY INFORMATION: This is a summary of the Commission's Reporn and Order. MM Docket No. $2=220, adopted December 11, 1992, and released January 12. 1993. The full text of this Commission decision is available for inspection anc copying during nermal business hours in the FCC . Docksts Branch (room 230),1819M __ Street, NW. W: DC The complete text of this decision may aiso be purchased from the Commission's copy contractors. Downtown Copy Center. 1990 M Street, NW.. Suite 640, Washington. DC 20036. (202) 452—1422. List of Subjects in 47 CFR Part 73 Radio brosdcasting. = AC tel 113900 Denali Street # Anchorage, AK 99503 e (907) 563-8000 0 44260 Sterling Highway e Soldotna, AK 99669 e (907) 262-3500 > The Alaskan Company g Highway a, (907) Subscriber Agreement Date of Birth Social Wz No. Drivers License No. ey of AE (2 “Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below-you agree that you have read and agreed to all terms and conditions on the front and reverse of this Agreement. You agree to pay all charges if the company or person Authorized Signer Name: / 0 sfatey < wee Zhi Authorization No. Service = Plan — qn A/D ae Unlock Code Toll Restrict AY PUL L2 Rate Plan esas Payment R Received SUBSCRIPTION AGREEMENT General Terms and Conditions . This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACtel”) for the provision of cellular radiotelephone or paging services (“Service"). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber’s authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber's unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN"). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtel may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. e) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber's request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges. The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills, and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACtel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7. Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period. THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR OTHERWISE. IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations. THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any right, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACtel, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attomeys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14, Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15. Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber's last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17. General. a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties. b) If any provision of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. ¢) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. - “a ACitel 11 3900 Denali Street ¢ Anchorage, AK 99503 e (907) 563-8000 044260 Sterling Highway Soldotna, AK 99669 e (907) 262-3500 SS The Alaskan Company oe . zs : Subscriber Agreement 1U+\ ri Apt/Suite No. Home Phone f Purchase ae a Tax Exempt Social Security No. Drivers License No. Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a / | month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below you agree that you have read and agreed | to all terms and conditions on the front and reverse of this Agreement. You agree to pay all chap if the ar or person named as the Subscriber denies responsibility. Authorized Signer Name: Shi VS1tLz ce Z bose: SE Hot 5 cf = 4, YD Print Name Sign Name Monthly Access Activation / Programming Fee Deposit Se $ MK $ ae $ 4 Authorization No. Tax Features Voice/Page Mail Office Use Only Voice/Page Mail No. ae Date See i {(¢ it Le A fs i Unlock Code y Ag | J 2, ii Lt Rate Plan Verification Payment K Received es MT 0007 R 6/96 SUBSCRIPTION AGREEMENT General Terms and Conditions < me This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACte!”) for the provision of cellular radiotelephone or paging services (“Service”). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber’s authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber’s unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN"). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtei may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. ¢) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber’s request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges. The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills, and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACitel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7, Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period. THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR OTHERWISE. IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations. THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any right, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACtel, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attorneys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14. Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15. Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber’s last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17. General. a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties. b) If any provision of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. e) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. ZV ACitel 11 3900 Denali Street « Anchorage, AK 99503 « (907) 563-8000 11 44260 Sterling Highway ¢ Soldotna, AK 99669 ¢ (907) 262-3500 SS The Alaskan Company er e _— Subscriber Agreement Subscriber Name (Billing Responsible Party) Billing Address Apt/Suite No. State Physical Address Apt/Suite No. City State Work Phone Home Phone Cellular User Name Purchase Order Tax Exempt Date of Birth Social Security No. Drivers License No. Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below you agree that you have read and agreed to all terms and conditions on the front and reverse of this Agreement. You agree to pay all charges if Ahe company or person named as the Subscriber denies responsibility. x i ; LG L Authorized Signer Name: Se Liha a C Print Name aa Si oe ApS Lane / apes Fee suetc Office Use Only Voice/Page Mail No. | Activation Date hate Frode Toll Restrict Hee {[& P, d { Equipment A/ D i Unlock Code Toll Restrict Rate Plan Verification Payment Received ro SUBSCRIPTION AGREEMENT General Terms and Conditions im This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACtel”) for the provision of cellular radiotelephone or paging services (“Service"). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber's authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber’s unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN"). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtel may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. ¢) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber’s request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges. The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills, and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACtel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7. Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period. THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR O WISE. IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations. THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any right, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACte!, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attomeys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14. Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15. Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber’s last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17. General. a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties. b) If any provision of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. ¢) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. M/ AC tel 113900 Denali Street e Anchorage, AK 99503 « (907) 563-8000 0 44260 Sterling Hi Soldotna, AK 99669 (907) 262-3500 The Alaskan Company a ms oo Subscriber Agreement 3 ( Billing Address Apt/Suite No. Subscriber Name (Billing Responsible Party) City State Physical Address Apt/Suite No. City State Work Phone Home Phone Cellular User Name Purchase Order Tax Exempt Date of Birth Social Security No. Drivers License No. Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a —~_ month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below you agree that you have read-and 7 to all terms and conditions on the front and reverse of this Agreement. You agree to pay all charges named as the Subscriber denies responsibility. f i Authorized Signer Name: Print Name Monthly Access $ mK ¢ Authorization No. Voice/Page Mail $ Office Use Only 0 Toe / Pager, ey Voice/Page Mail No. Equipment Al D Unlock rs Toll Restrict Cellular No. / ae No. ore os an | Mail No. | Activation Date HT) L Unlock Code Toll Resript tut LAA Bibya LA. WA \i/4 i Cellular No. / Pager > : Voice/Page Mail No. | Activation Date | -(/ Aes y t fle i) - ——— ; LG 1x} ao { ly Service Plan Equipment A/D i Unlock Code Toll Restrict t Store No./Agent Sales ae Lead Source =— Rate Plan Verification a Received SUBSCRIPTION AGREEMENT General Terms and Conditions . This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACtel”) for the provision of cellular radiotelephone or paging services (“Service"). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber’s authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber’s unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN”). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtel may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. e) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber’s request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges. The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills,and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACtel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7. Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period. THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due.. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR OTHERWISE. “IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations, THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any tight, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACtel, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attorneys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14. Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15. Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber’s last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17, General. a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties. b) If any provision of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. ¢) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. EE 5 a ated eee SPIES zy ACtel 1 3900 Denalii Street ¢ Anchorage, AK 99503 ® (907) 563-8000 0 44260 Sterling Highway e Soldotna, AK 99669 © (907) 262-3500 The Alaskan Company ig Highway a, * (907) Subscriber Agreement fe tik Subscriber Name (Billing Responsible Party) Apt/Suite No. Billing Address City State Zip Physical Address Apt/Suite No. City State Zip Home Phone Work Phone Cellular User Name Purchase Order Tax Exempt Date of Birth Social Security No. Drivers License No. Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a |<. month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below you agree that you have read-and agreed to all terms ahy or person y Authorized Signer Name: ( Coon py Jo 4/ Fe Print Name Bi Sign Name Date and conditions on the front and reverse of this Agreement. You agree to pay all oe) if the cor named as the Subscriber denies responsibility. Monthly. Access Activation / Programming Fee $ an are Authorization No. Office Use Only Cellular No. / Pager No. FSN/ Gj Se se Voice/Page Mail No. | Activation Date 10.4. Unlock Code Toll Restrict Cellular No. / Pager No. So Voice/Page Mail No. Fe Va \) [275 i Service Plan A Unlock Code Toll ies Calter} No,/ Pager No. 3S ps Voice/Page Mail No. Service Plan i i Unlock Code Toll tae Sales Associate — Source AS i | ) Rate Plan Verification see =, Received 4 Gig) MT 0007 R 6/96 SUBSCRIPTION AGREEMENT General Terms and Conditions . o This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACtel”) for the provision of cellular radiotelephone or paging services (“Service"). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber’s authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber’s unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN"). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. _b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtel may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. ¢) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber’s request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges. The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills, and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACtel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7. Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period. THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR OTHERWISE. IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations. THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any tight, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACtel, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attorneys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14, Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15. Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 3 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber's last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17. General. a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties. b) If any provision of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. e) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. 7S es A TTR TE Ee CSS 3 a. 1 TIE gy ERB Se s = : ACitel 113900 Denali Street « Anchorage, AK 99503 # (907) 563-8000 SSS. 2 11 44260 Sterling Highway * Soldotna, AK 99669 © (907) 262-3500 The Alaskan Company ing Highway a, ° (907) Subscriber Agreement Subscriber Name (Billing Responsible Party) Billing Address Apt/Suite No. City State Physical Address Apt/Suite No. City State Work Phone Home Phone Cellular User Name Purchase Order Tax Exempt Date of Birth Social Security No. Drivers License No. Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a ~\< month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below you agree that you have read-and agreed to all terms and conditions on the front and reverse of this Agreement. You agree to pay all chargés if the co: named as the Subscriber denies responsibility. : pa ee / a ~ L/ / Authorized Signer Name: a el io. 4 Ge Print Name Z Sign Ne Date Monthly. Access Activation / Programming Fee Deposit $ CoA $ — $ na Authorization No. Tax Features Voice/Page Mail %|\ $ $ Office Use Only Cellular No. / Pager No. | ESN/,CC., Voice/Page Mail No. | Activation Date 4 aes | DISET IE z AA Service Plan Equipment A/D Unlock Code Toll Restrict ‘ ; ea /Page Mail No. \ eee a YAIGE TT II Equipment (A/D Activation Date 4-4 Toll Restrict Cellular No. / Pager No, Voice LY pe : 4 Service Plan - Unlock Code ; Lf > if Cellular No. / Pager No. ‘ i Activation Dat ii fi ¢ ; & ALY Unlock Code Toll Restrict Cc. {i,! t ESN /Ci Voice/Page Mail No. PATE i Equipment A/D Ls Ae te Service Plan f VL Cs s Oi dt { ff UA 1iU/@ Rate Plan Verification : Payment Received ; tH : "4 MT 0007 R 6/96 SUBSCRIPTION AGREEMENT General Terms and Conditions Sy, This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACtel”) for the provision of cellular radiotelephone or paging services (“Service"). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber’s authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber’s unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN"). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtel may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. e) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber’s request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges. The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills, and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACtel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7. Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period. THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel. OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR OTHERWISE. IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations. THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any tight, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACtel, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attomeys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14. Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15, Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber’s last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17. General, a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties. b) If any provision-of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. ¢) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. ye ee ee —< a? 22e~ ee tie. 2.4 ACtel 113900 Denali Street # Anchorage, AK 99503 ¢ (907) 563-8000 >= 1 44260 Sterling Highway © Soldotna, AK 99669 * (907) 262-3500 The Alaskan Company igi sae Subscriber Agreement Subscriber Name (Billing Responsible Party) Billing Address Apt/Suite No. State Physical Address Apt/Suite No. City State Zip Work Phone Home Phone Cellular User Name Purchase Order Tax Exempt Date of Birth Social Security No. Drivers License No. Your Agreement with MACtel, Inc. is for the provision of cellular radiotelephone or paging services and any additional features or services ordered by you. The price established for service is set forth in the current MACtel, Inc. Rate Schedule for the service plan you have selected. Your service plan requires a month agreement. You hereby authorize MACtel, Inc. to investigate your credit history and report your performance to credit reporting agencies. To obtain service, you must satisfy MACtel, Inc.’s credit criteria or make a security deposit that is acceptable to MACtel, Inc. By signing below you agree that you have read and agreed to all terms and conditions on the front and reverse of this Agreement. You oe to Pa all charges if the company or person named as the Subscriber denies responsibility. —-. lOf4/P Ge Authorized Signer Name: Print Name /Date Monthly Access Activation / Programming Fee Deposit $ tt $ $ A Voice/Page Mail $ ESN /CC pore Voice/Page Mail No. | Activation Date eI LY Te U 14 IE" 5 ' - ip 44, Service Plan \ i Unlock Code Toll Restrict wo Cyt ELAS > {Z4 j Cellular No. / Pager No. | ESN /'CC Features Voice/Page Mail No. | Activation Date Service Plan Equipment A/D Price Unlock Code Toll Restrict Cellular No. / Pager No. | ESN / CC Features Voice/Page Mail No. | Activation Date Service Plan Equipment A/D Price Unlock Code Toll Restrict Sales Associate Lead Source i —+ Rate Plan Verification Payment Received MT 0007 R 6/96 SUBSCRIPTION AGREEMENT General Terms and Conditions This is an agreement between the customer named on the reverse side (“Subscriber”) and MACtel, Inc., (“MACtel”) for the provision of cellular radiotelephone or paging services (“Service"). This agreement shall not be binding unless and until accepted and executed by an authorized employee of MACtel. 1. Availability. Service is available to Subscriber’s receiving equipment (“Unit”) is subject to transmission limitations caused by atmospheric or topographical conditions. Service may be temporarily refused, limited, interrupted or curtailed due to governmental regulations or orders, system capacity limitations or equipment modifications, upgrades, relocations, repairs and other activities necessary or appropriate for the proper Service. 2. Use of Service. Orders for activating, changing or terminating Service will be accepted by MACtel only from Subscriber or Subscriber’s authorized agent. Subscriber is responsible for ensuring that the Unit is technically and operationally compatible with the cellular system and in conformance with applicable Federal Communications Commission (“FCC”) rules and regulations. Subscriber shall not use its Unit for any unlawful or abusive purpose or in such a way as to create damage or risk to MACtel’s business, reputation, employees, facilities, third parties or to the public generally. 3. Telephone Access Numbers. Subscriber has no ownership rights to, or interests in, a specific telephone access number assigned to Subscriber’s unit. MACtel reserves the right to change telephone number assignments from time to time upon notice to Subscriber. Subscriber may not use or assign its telephone number to any other unit or Electronic Serial Number (“ESN"). Subscriber shall not program any other telephone number into its Unit. 4. Payment of Charges. a) Subscriber is responsible for payment of charges for all Service furnished, including without limitation all calls originated or received by Subscriber’s Unit, even if the Unit is lost or stolen, until four working hours after Subscriber notifies MACtel of the loss or theft. _b) Usage and tolls will be billed at the end of each billing period. Monthly access charges will be billed monthly in advance of Service. In addition, MACtel may bill Subscriber in advance each month in an amount equal to one month’s estimated charges for usage and tolls, together with applicable taxes. c) Payment of invoiced charges is due fourteen days after MACtel mails an invoice to Subscriber. d) When payment for Service is made by check, a charge of $25.00 will be made by MACtel for each check returned to MACtel unpaid for any reason. ¢) The access charge for a fractional part of a month will be a proportionate part of the monthly access charge based on the actual number of days Service is provided. A credit allowance will be made, at Subscriber’s request, as a pro rata adjustment to monthly access charge, for any continuous interruption of service in excess of 24 hours. f) A Rate Schedule has been provided to Subscriber, and is subject to change without notice. g) A service charge of 1.5% per month will be added to past due accounts.. Subscriber may pay the total unpaid balance at any time. 5. Deposits. MACtel may at its option require Subscriber to make a deposit to be held by MACtel as a guarantee of the payment of charges, The fact that a deposit has or has not been made does not relieve Subscriber from complying with the provisions of Paragraph regarding the prompt payment of bills, and does not affect MACtel’s right to discontinue Service for nonpayment of any sums due MACtel. 6. Disconnection of Service for Cause. If payment of any amount due MACtel by Subscriber is not made on time or if Subscriber is in any other way in default under this agreement, MACtel may, in its sole discretion and without liability to Subscriber, temporarily or permanently disconnect Service to Subscriber. In addition, MACtel may exercise or pursue any other remedy in law or equity. MACtel may charge a fee for reactivation of Service. 7. Termination of Agreement by Subscriber or MACtel. Subscriber or MACtel may at any time, with or without cause, terminate this agreement and Service by notifying the other party in writing. If termination is by Subscriber without cause, such termination shall not relieve Subscriber from his or her responsibility to pay for the minimum term of the agreement plus any applicable notice period, THIS AGREEMENT PROVIDES FOR A MINIMUM SUBSCRIPTION TERM. TERMINATION BY THE SUBSCRIBER WITHOUT CAUSE WILL RESULT IN A CANCELLATION FEE OF $25.00 PER MONTH OR PART OF A MONTH REMAINING IN THE MINIMUM SUBSCRIPTION TERM. For pager servicer, termination by the Subscriber without cause requires one month notice; FAILURE TO GIVE THE REQUIRED NOTICE WILL RESULT IN A ONE MONTH’S ACCESS FEE CHARGE TO SUBSCRIBER. If termination by MACtel is not due to the failure of Subscriber to comply with the terms of this agreement, MACtel will give Subscriber not less than 30 days notice of termination. Termination of the agreement shall not relieve Subscriber of its obligation to pay all outstanding charges when due. MACtel will not pay, or invoice subscriber for, any amount due on Termination of the agreement if that amount is less than $1.00. 8. Limitation of Liability. THE TOTAL LIABILITY OF MACtel ARISING OUT OF OR IN ANY WAY CONNECTED, DIRECTLY OR INDIRECTLY, WITH THIS AGREEMENT SHALL BE LIMITED TO PAYMENT BY MACtel OF DAMAGES EQUAL TO THE AMOUNT OF ONE MONTH’S ACCESS CHARGE. THIS LIMITATION OF LIABILITY SHALL APPLY REGARDLESS OF THE FORM OF THE ACTION, WHETHER FOR BREACH OF CONTRACT, WARRANTY, NEGLIGENCE, STRICT LIABILITY IN TORT, OR OTHERWISE. IN NO EVENT SHALL MACtel BE LIABLE FOR ANY SPECIAL OR CONSEQUENTIAL DAMAGES. 9. Rate Schedule change by Subscriber. Subscriber may elect a Service Plan other than that shown on the face of this Subscriber Agreement at any time, provided the Service Plan is shown on a current Rate Schedule. A change to a higher level of Service will become effective immediately, for the month in which notice is given. A change to a lower level of Service will take effect in the month following the month in which notice is given. 10. Warranty Limitations. THERE ARE NO EXPRESS OR IMPLIED WARRANTIES, INCLUDING WITHOUT LIMITATION THE IMPLIED WARRANTY OF MERCHANTABILITY AND FITNESS FOR A PARTICULAR PURPOSE, RESPECTING THIS AGREEMENT AND THE SERVICE PROVIDED. NO WARRANTY IS MADE AS TO THE COVERAGE AVAILABILITY OR GRADE OF SERVICE PROVIDED BY MACtel. 11. Waiver. The failure of MACtel to insist in any one or more instances, upon the performance of any of the terms, covenants, or conditions herein, or to exercise any right, shall not be a waiver or relinquishment of the further performance of any such term, covenant or conditions or the future exercise of such right, and the obligation of Subscriber with respect to such future performance shall continue in full force and effect. 12. Indemnification. Unless caused by the negligence or other fault of MACtel, Subscriber shall defend, indemnify and hold harmless MACtel, its owners, officers, employees and agents, from and against any and all claims, demands, suits, judgments, causes of action, losses, expenses, liability and damages (i) for libel, slander or infringement of copyright from the material transmitted via the telephone access number, and (ii) for any claim arising in any way, directly or indirectly, in connection with this agreement or the use or inability to use the telephone access number. This indemnification obligation shall survive the termination of this agreement. 13. MACtel’s Expenses. Subscriber shall pay to MACtel all costs and expenses, including without limitation reasonable attorneys’ fees, and the fees of any collection agencies and court costs, incurred by MACtel in exercising any of its rights or remedies under this agreement or enforcing any of the terms, conditions or provisions hereof. 14. Excusable Delay and Failure to Perform. MACtel shall not be liable for any delay or failure to perform due to any cause beyond its control. 15. Captioned Headings. The captioned headings have been included in this agreement merely for convenience of reference. They are not to be considered part of, or to be used in interpreting, this agreement. 16. Notices. Notices to Subscriber shall be deemed given if deposited in the U. S. Mail addressed to the Subscriber's last know address as shown on the reverse side hereof. Notices to MACtel shall be deemed given when received by MACtel at the address shown on the reverse side hereof. 17. General. a) No modification hereof shall be binding upon either party unless the modification is in writing and signed by a duly authorized representative of both parties, b) If any provision of this agreement is contrary to, prohibited by, or deemed invalid under applicable law, such provision shall be deemed omitted to the extent so contrary, prohibited or invalid, but the remainder of this agreement shall not be affected or impaired and shall be given effect so far as possible. c) This document and the rights and duties of the parties shall be governed and interpreted according to the laws of the State of Alaska. d) No assignment or transfer, in whole or in part, of this agreement shall be binding upon MACtel without its express written consent. ¢) This agreement shall be binding upon and shall inure to the benefit of the parties hereto and their respective successors, administrators, legal representatives, heirs, and assigns, where permitted by this agreement. SUBSCRIBER ACKNOWLEDGES THAT HE OR SHE HAS READ AND UNDERSTANDS THESE TERMS AND CONDITIONS AND AGREES TO BE BOUND BY THEM, AND THAT THIS DOCUMENT WITH ATTACHMENTS IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN THE PARTIES AND SUPERSEDES ALL PROPOSALS, ORAL OR WRITTEN, AND ALL OTHER COMMUNICATIONS BETWEEN THE PARTIES RELATING TO THE SUBJECT MATTER HEREOF. LG ~\ CITY OF 5 adh. 7‘ — FAIRBANKS ats ENGINEERING DEPARTMENT (907) 459-6740 E ¢ fF V E | JAN 23 1938 leans: thie sal Alaska Industrial Developmen! and Export Authority Linda Day Alaska Energy Authority 480 West Tudor Road Anchorage, Alaska 99503-6690 Subject: Change of Ownership Please be advised the Fairbanks Municipal Utilities System is no longer responsible for the Anchorage / Fairbanks Intertie Energy usage. Please send future statements to Golden Valley Electric Association, Post Office Box 71249, Fairbanks, Alaska 99707-1249. Thank you. 1 } Sincerely, Ata Ws \ CITY OF FAIRBANKS . ; a Engineering Department : | Yo we hawe fw \ lw a fafeo/s 6A fre. Mme Doc ? RUFUS B. BUNCH, PE City Engineer C:\AMIPRO\WDOCS\1-19-98.SAM/RBB/pm ce: Golden Valley Electric Association, Post Office Box 71249, Fairbanks, Alaska 99707-1249 the GOLDEN HEART CITY .... "extremely Alaska" 800 Cushman Street Fairbanks, Alaska 99701-4615 TNTERTIE 6 SS ae oe ee wood RP JOINT USE AGREEMENT THIS AGREEMENT is between the Alaska Power Authority (hereinafter called the "Power Authority") and Matanuska Electric Association (hereinafter called "MEA"), witnesseth, that, WHEREAS in 1981 the legislature directed the Power Authority to construct the Anchorage=Fairbanks Transmission Intertie (Sec. 14, Ch. 118, SLA 1981, as amended by Sec. 19, Ch. 133, SLA 1982); and WHEREAS the purpose of the intertie project is to connect the electrical power transmission facilities of | Southcentral Alaska with Interior Alaska; and WHEREAS to carry Out this purpose it is necessary to transmit electrical power between Teeland Substation and Willow Substation; and WHEREAS MEA owns and operates an electrical trans- migsion system in Southcentral Alaska; and WHERBAS MEA designed, owns, and operates a 115 kv erenestenton line from Willow Substation to Teeland Substa- tion; an WHEREAS all but 5.5 miles of that line are capable of transmitting 138 kV as required for the intertie operation; and WHEREAS MEA is willing to provide the right-of-way for the design and construction of 5.5 miles of a 138 kV electrical transmission line (hereinafter called the "Project"); and WHEREAS the Power Authority is willing to design and construct the Project in return for ownership of the Project and permission to use tha MEA right-of-way to build, operate and maintain the Project; and WHEREAS the Power Authority is willing to allow MEA to transmit power to MEA loads at no cost tc MEA; and WHEREAS the Power Authority will transfer owner- ship of the Project and relinquish the permit to MEA when the Power Authority determines that it no longer requires the electrical transmission line, NOW THEREFORE, it is agreed as follows: ARTICLE I Saction 1. MEA warrants that it has obtained all rights-ofeway, easements, and/or permits reasonably required for the construction, operation, and maintenance of the Project and hereby grants a license and permit to tha Power Authority to utilize said rights in real property to construct, Operate, and maintain the Project at no cost to the Power Authority. Said license and permit shall terminate upon the transfer described in Section 9 hereof but in all events no latar than October 1, 2018, FEB 17 *e 198 11:18AM MEA BIG LAKE Pag Section 2. The Power Authority shall comply with the terms of all MEA rights-of-way, easements and permits affecting the Project, copies of which are attached hereto and made a part of this Agreemant. (Attachment A). Section 3. The Power Authority shall accomplish all engineering and construction services necessary for the complete engineering design and the construction of the Project. The Power Authority shall design and construct the Project so as to permit the installation of three-phase underbuild distribution which is to be reasonably compatible with MBA's existing system. Saction 4. MEA shall not be responsible for operation and maintenance of the Project unless this Agree- ment is terminated or title to the Project is transferred to MEA. Section 5. The Power Authority shall indemnify and hold MEA harmless from any claims or actions of any kind arising from the design, construction, operation, and main- tenance of the Project and/or the failure to comply with the terms of all MBSA rights-of-way, easements, and permits by the Power Authority or its agents, contractors, or assigns. However, in no event shall the Power Authority indemnify MEA for MEA's own negligence, or for the negligence of MBA's agents, contractors or agsigns. Furthermore, the Power Authority shall have no obligation to indemnify for claims brought after October 1, 2018, or after the transfer of title described in Section 9 below. Section 6. MEA may design, construct, operate, and maintain reasonable underbuilt electrical distribution lines utilizing the structural components of the transmis- sion line. All such underbuild construction shall be @esigned and constructed in accordance with REA and NESC vequirements and shall receive Power Authority design approval prior to construction. The design, construction, operation, and maintenance costs for the underbuilt will be borne by MEA. Thara shall be no underbuild along the Sunset Boulevard to the Hollywood Road segment beginning at the east end of the lake located in the Northwest One-Quarter (NW1/4) o£ Section 31. Section 7, MEA shall indemify and hold the Power Authority harmless from any claims or actions of any kind arising from MEA's design, construction or operation and maintenance of its underbuilt distribution lines. Section 8. It is understood that the new trans- mission line will be a portion of the existing MEA trans- mission system required to serve the MEA load north of the Teeland Substation. Accordingly, it is agreed that MEA shall have the primary right at all times to utilize the new transmigsion line capacity to transmit power to such MEA loads at no cost to MEA. Such rights will have precedence over all other uses. The Power Authority will make all reasonable efforts to ensure that the line is available for use at all times but offers no guarantee of availability or reliability of the new transmission line. The Power Authority will not be liable for direct or consequential damages resulting from line failure. All energy losses resulting from utiliaation herein specified shall be supplied and paid for by MEA. For the purposes of determining said losses, engineering estimation shall be used and shall assume only MEA loading of the line. Utilization ef the iine by MEA at Page 2 of 4 FEB 17 798 11:1@AM MEA BIG LAKE P.8 any given instance shall not exceed forty (40) megawatts, which is that amount of transmission eet eecy lost to MEA by incorporation of this new transmission line into the existing MEA transmission system. Section 9. When the Power Authority determines that it no longer requires the electrical transmission line as a component part of the Anchorage-Fairbanks Intertie Project, the Power Authority will transfer title to the transmission line to MEA at no cost as part of the compensa- tion for the performance of this contract by MEA and Power Authority usage of the MEA right«of-way. Section 10. In the event this Agreement expires or is terminated, the Power Authority shall have the right to utilize the Project for intertie operations within the limitations of Section 8, above, and MEA shall assess charges based only upon maintenance costs of the Project as constructed by the Power Authority. ARTICLE II Section 1. As used herein, the term: A. “Project” means the physical facilities necessary to transmit three-phase electrical anergy not to excead 138 kV from a take-off structure located at Teeland Substation, a distance of approximately 5.5 miles to Hollywood Road as depicted on Attachment B hereto, including, without limitation, wooden poles, conductors, insulators, anchors, guy wires, take-off structures, and ralated equipment, B. "Construction" means all labor, equipment, Supplies, and services necessary to place the Project in commercial operation, including, but not limited to, clearing the right-of-way to permit installation and maintenance of the Project, in accordance with the Project's design. Section 2. It is specifically agreed between the parties executing this Agreement that it is not intended by any of tha provisions of any part of the contract to create in the public or any member thereof a third-party beneficiary hereunder, or to authorize anyone not a party to this Agrae- ment to maintain a suit for personal injuries or property damage pursuant to the terms or provisions of this Agreement. Section 3, This Agreement represents the entire agreement between the parties concerning the Project. The parties agree that all other agreements written or oral concerning the Project are merged with this Agreement. Section 4, This Agreement may only be modified in writing which must be signed by the appropriate officars of each party to this Agreement. Section 5. Nothing in this Agreement shall be interpreted to make the Power Authority the agent of MEA or MEA the agent of the Power Authority. ALASKA POWER AUTHORITY DATED: “wlan eayin 10, 1 ae By Title: Page 3 of 4 FEB 17 11:11AM MEA BIG LAKE Pao MATANUSKA ELECTRIC ASSOCIATION, INC. DATED: hide 4 e ibe STATE OF ALASKA ) 2 BB. THIRD JUDICIAL DISTRICT ) The foregoing Agreement Was acknowledged before me this Ic? day of January, 1984, by Larry D. Crawford, the Executive Director of the Alaska Power Authority, an Alaskan corporation, on behalf of the corporation. STATE OF ALASKA ) THIRD JUDICIAL DISTRICT } The foregoing Agreement wai wiedged before me this svt aay of*vanuary, 1984, by sGiedoag nf Millan » the of Matanuska Electric AsS0ciatifon, an Alaskan corporation, on behalf of the corporation, 1 Plassey , My commission expires: Page 4 of 4 C:\WINDOWS\TEMP\MEA121 jpg (local) Page | of 2 cousins sete file:;C:\WINDOWS\TEMP\MEA121.jpg 2/18/98 FEB 17 ’98 11:@6AM MEA BIG LAKE wus Matanuska Electric Association, ae cornea Parcel T1A * W/O 9706 ELECTRIC LINE RIGHT OF WAY EASEMENT tie KNOW ALL WEN BY THESE PRESENTS. that we the undersigned (whether one or more) WINFRED G. LUCAS {unmarried) (husband and wife) for a good and valuable consideration, the receipt whereof is hereby acknowledged, do hereby grant unto MATANUSKA ELECTRIC ASSOCIATION, INC., a coop. erating corporation (hereinafter called the “‘Association’”’) whose post office address is Palmer, Alaska, and to its successors or assigns, the right to enter upon the lands of the undersigned, situated in the Palmer Recording District, State of Alaska, and more particularly duct ed as follows: The North One Hundred Feet (100') of the Northeast One-Quarter (NE 1/4) of the thet Northwest One-Quarter (NW 1/4) of Section 32, Township 17 North, Range 2 West, Seward OP ee being within the Palmer Recording District, Third Judicial District; State -of Alaska. (The North 50' of the above-described easement overlaps a 50' section line reservation) Baing in Section 22" noiaip 128i =e aie, __ "struct, rephave, repair, mao he hr sid nd or under all streets, highways ‘abutting said lands, an electric transmission and/or ; tion line or system. To and make gach repairs, changes, alterations, ee ee TemMov: als from, substitutions and additions to its facilities as the Association may from time to time-deem advisable, incudi ing, by way of example and not by way of. limitation, the right to: increase’ Or - erage the meaner of ‘conduits, wires, cables, hand holes, manholes, connection boxes, “and transformer enclosures; to. cut, trim’.and‘ son 1, ‘the ‘by. chemical’ means, machi > ‘otherwise of trees and shru' located within "fA of the seater Une of sald ‘Une or” |: pp that interfere with or Hen. to eedanger’ the nperétiog and maeintensnee Dl HG ne. bu deluding any control of the growth of er vegetation in the right of. way.. which -may-4 dentally and necessarily result from the means of contro] employed); to. keep, the easement-< lea “*“gf.all buildings, atone Oy ym pepe pee or otherwise agree: 5 nd fel or, if’ an any Of sald syotem is Placed underground, facilities, by ae assoqiztion Lt eet OF er facilities ineluding described lands ai FEB 17 ’98 11:@7AM MEA BIG LAKE , BOOKATI PAGO. ELECTRIC LINE RIGHT OF WAY EASEMENT KNOW ALL MEN BY THESE PRESENTS that we the undersigned, JOHN G. (GARY) HAGGITT, WILLIAM H. MCKILLOP, JOHN D. HAGGITT, MARGARET E. HAGGITT, and PHYLLIS TATE, for a good and valuable consideration, the receipt whereof is hereby acknowledged, do hereby grant unto MATANUSKA ELECTRIC ASSOCIATION, INC., a cooperative corporation (hereinafter called the "Association"), whose post office address is P.O. Box 1148, Palmer, Alaska 99645, and to its successors or assigns, the right to enter upon the lands of the undersigned, more particularly described as follows: The North One Hundred Feet (100') of the Northeast One Quarter (NE 1/4) of Section 32, Township 17 North, Range 2 West, Seward Meridian, Palmer Recording District, Third Judicial District, State of Alaska and to construct, reconstruct, rephase, repair, operate, and maintain on or under the above-described lands and/or in, upon, or under all streets, roads, or highways abutting said lands, an electric transmission and/or distribution line or system; to “inspect and make such repairs, changes, alterations, improvements, ‘removals from, substitutions, and additions to its facilities as ‘the Association may from time to time deem advisable, including, ‘by way of example and not by way of limitation, the right to jincerease or decrease the number of conduits, wires, cables, hand :holes, manholes, connection boxes, transformers, and transformer ‘enclosures; to cut, trim, and control the growth by chemical imeans, machinery, or otherwise of trees and shrubbery located ; iwithin fifty (50) feet of the center line of said line or system, ‘or that may interfere with or threaten to endanger the operation j}and maintenance of said line or system (including any control of the growth of other vegetation in the right of way which may incidentally and necessarily result from the means of control employed); to keep the easement clear of all buildings, structures, or other obstructions; and to license, permit or otherwise agree .to the joint use or occupancy of the lines, system, or, if any {of said system is placed underground, of the trench and related i underground facilities, by any other person, association, or : corporation. | The undersigned agree that all poles, wires and other facilities, including any main service entrance equipment | installed in, upon, or under the above-described lands at the } Association's expense shall remain the property of the Associa- tion, removable at the option of the Association. i i The undersigned covenant that they are the owners of | the above-described lands, and that the said lands are free and ‘clear of encumbrances and liens. IN WITNESS WHEREOF, the undersigned have set their hands and seals. DATED this /3 day of Loli bue , 1982. : | ELECTRIC LINE RIGHT OF | WAY EASEMENT - PAGE 1 of 3 | \ FEB 17 798 11:@6AM MEA BIG LAKE P.4 pooKal4 2accatl STATE OF ALASKA ) i 68. THIRD. JUDICIAL DISTRICT ) Ba iF The foregoing instrument was acknowledged before me this., 13 day of aabher » 1982, by John G. Haggitt. a of Alaska My commission expires: bby DV AIES- ie DATED this 27 day ot egtindea 2: 1982. WILLIAM H. he PT a 7 STATE OF ALASKA ) , : ss. THIRD “JUDICIAL DISTRICT ) “> the foreggin strument was acknowledged before me A7% day of , 1982, by William H. McKillop. j or the State of Alaska My ¢ ssion expires: DATED this 29% day of se Oe 1982. Hat Lett < STATE OF ALASKA ) : ss. THIRD JUDICIAL DISTRICT ) yt! The foregoing instrument was acknowledged before me thisQGry day of eeliamisntes 1982, by Phyllis Tate. Notary eee for the & te of Alaska : My commission expires: Ad, 4 ! Page 2 of 3 FEB 17 ’98 11:@9AM MEA BIG LAKE P.S COKE TT aY4a. paren this 6 day of (Ostpdur, 1982. STATE OF CALF RAA/A ) SS. ya ThE foregoing instrument was acknowledged before me this ew day of emanate. 1982, by John D, Haggitt. jBEERONE EBA OFFICIAL SEAL. JAINICE R. COUEY NOTARY PUBLIC - CALIFORNIA COUNTY OF GOMGMA My Commission Expiry June 2, 1984 |UHOOGO 00 DODD NOC MBA DOHA ENGL Sty py ycceTTNULADU DUAL! ; [¥ = es e gots California MARGARET E. HAGGT STATE OF CAL/FORMA ) 33. The foregoing instrument was acknowledged before me this 44 day of _Octeger_, 1982, by Margaret E. Haggitt. NOTARY PUBLIC « CALIFORNIA ; eosin cnt State qf Forna avanoeuaseemnseeverecpouscdhlA44HH001 P0100 100000004 1_@- # fpldor eat reeds aaa r OFFICIAL BEAL 4 & JAIICE R. COUEY RECORDED-EES PALMER REC. DISTRICT Oor 20. 12 an PH 82 AODHESS SSE. Dig! BHO Se ALISO, | Page 3 of 3 C:\WINDOWS\TEMP\MEA118..jpg (local) Page | of 2 MEA Line Crossing Hollywood/Teeland | LookingSc file:C:\WINDOWS\TEMP\MEA118.jpg 2/18/98 FEB 17 798 11:@5AM MEA BIG LAKE Matanuska Electric Association Big Lake Office ian FAX bee meee Number of pages including cover sheet: = Phone: Phone: 892-7398 Fax phone: ce: Fax phone: 892-6349 REMARKS: OO Urgent For your review [] Reply ASAP (1 Please comment Ny ae Municipality of Anchorage Municipal Light & Power Hee een, ea 1200 East First Avenue Anchorage, Alaska 99501-1685 Telephone: (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 February 18, 1998 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of January 1998. Sincerely, Doug ein Chief Power Dispatcher DH/pjc Attachment CG: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA c\-pattylocwo-oeadtting,Energy into Anchorage for Over 60 years 17-Feb-98 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL YR TOTAL ENERGY $ YTD MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD ALASKA INTERTIE USAGE REPORT FY 98 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MLP TO GVEA MLP TO FMUS 2408 2023 4617 6825 1593 1177 116 18759 MLP DELIVERIES CEA DELIVERIES BL DELIVERIES 2408 2023 4617 6825 1593 1177 116 0 0 0 0 0 18759 oo 0 fo oO oO Oo 33636 27416 23670 21748 25425 35767 27525 0 0 0 0 0 195187 32838 26584 22827 20691 24430 34782 26514 188666 coco eo oO oO Oo ° co eo Oo oO CEA TO GVEA CEA TO FMUS CEA TO MEA 798 832 843 1057 995 985 coo oo Oo oO 1011 0 6521 coo oO Oo GVEA DELIVERIES FMUS DELIVERIES 0 0 507 © e0 80002 8 oO Oo 507 0 oo 80 0 80 Oo oO oO oO ce oo Oo oO GVEA RECEIPTS 35246 28607 27444 27516 26023 35959 26630 0 0 0 0 0 207425 $1,055,793.25 0 0 0 0 0 0 0 0 507 0 0 0 ° ° 0 0 0 ° 0 0 oO 0 0 0 0 0 0 ° 507 0 0 0 FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS 0 oO 0 798 ° 0 ° 832 0 507 0 843 0 0 O 1057 O 0 0 995 0 0 0 985 0 0 0 1011 ° 0 0 0 0 QO 0 0 O 0 0 0 0 0 0 o 0 0 0 0 oO 507 0 6521 $0.00 $2,580.63 $0.00 B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT ° coo oc oOo LINE TOTAL 36044 29439 28794 28573 27018 36944 27641 O 0 ° 0 oO 214453 $33,191.89 $1,091,565.77 17-Feb-98 ALASKA INTERITE USAGE REPORT FY 98 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS AEGT TO GVEA AEGT TO FMUS GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT JULY 0 0 0 0 0 0 AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 cooooc eo coocoond cooaoaoco fd ooocoone ecoococ eo coooco eo cooocood coococ eo ocoocod ooocood coooaoao ed cooocooc MONTH MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL JULY 0 0 0 0 0 0 0 0 0 AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL coo eo eo oO eC COC eoooeo COC OCC Oe coo eo oe eC COCO Co coo oO OC OO CCC Co coco eo eC OC OCC Oe coco oC COC OC SscooOoO COO OC OC Oe Seco OC COC OCC COS coo oC COC COCO Se coo oO COCO COCO CS cosoceo oe eC COCO CS $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 AP<T | wireless,inc. iis anil endl oe oe Mr. Stan Sieczkowski _ E ( F | V E j Ketchikan, AK 99901 eee te Anchorage, Alaska 99503 JUL 2 8 1997 seete Dear Stan: Alaska Industrial Development and Export Authority I’m sorry that the weather shot us in the foot and we were unable to make the trip to Navy Peak. I was really looking forward to meeting you and showing off our site. We have finally had time to sit down and put the pencil to the paper and have come up with the following proposal: We can provide power for your site on Etolin for $900 per month. This will give you two FCC checks and certify your equipment for frequency and normal service. After the two, if you have any equipment problems we will supply the tech labor with you supplying travel and helicopter costs. If at a later date you need more equipment, we will take another look then. If you decide to upgrade to a microwave control line, we charge $500 per month for the interface and we will supply the interface equipment. Again Stan, I am sorry we didn’t get to meet. I am looking forward to a long and pleasant business relationship with you. Sincerely, Darrell Thomas General Manager A Subsidiary of Alaska Power & Telephone ~~ * * x a 480 WEST TO: FROM: DATE: SUBJECT: @™ SENERGY AUTHORITY * @ x ALASKA INDUSTRIAL DEVELOPMENT = fj Sih AND EXPORT AUTHORITY =x ALASKA * TUDOR ANCHORAGE, ALASKA 99503 907 / 561-8050 FAX 907 561-8998 MEMORANDUM Dennis, Stan and Valorie Elaine Waw- August 12, 1997 Larsen Bay FY97 Budget Status Attached is the FY97 Larsen Bay budget status report. These are the main points I want to bring to your attention: Based on billed revenues (as opposed to collected) our debt service coverage is 138.25 %, more than adequate to meet the LOC requirement of 115%. (If we back out the $33,313 still due from the City for FY97 revenues, our debt service coverage would be 100%, due to the increase we made to the Rate Stabilization Fund in FY97.) Assuming that the City eventually pays the $33,313 (3 months payments) still due for FY97, we will have a cash surplus from FY97 activities of $9,085. We will then have to decide how to use this surplus: 1. Transfer this surplus to the Rate Stabilization Fund (see attached FY98 Revision #1), or 2. Leave the surplus in the Revenue Fund and reduce the FY98 monthly payment due from City from $11,600 to $10,840 (see attached FY98 Revision #2), or 3. Transfer a portion of the surplus to the Rate Stabilization Fund, leave part in the Revenue Fund, and reduce the monthly payment to something in between $11,600 and $10,840. The Rate Stabilization Fund is required to be no less than $15,000. Amounts in this fund may be expended whenever there are insufficient funds in the LOC Reimbursement account to pay the debt service payments. Amounts in this fund may also be expended for operating expenses when amounts in the Operating/Revenue Funds are insufficient. ALASKA ENERGY AUTHORITY LARSEN BAY BUDGET - FY97 DESCRIPTION REVENUES City of Larsen Bay Kodiak Salmon Packers Interest OPERATING EXPENSES Operations & Maintenance by City Hydro operator services Communications Other operations & maintenance Misc maintenance of hydraulic plant Other O&M Expenses Professional Services (engineering) Renewal & Replacement Land Rents Insurance RSA with Risk Management AEA Expense Personal Services Travel Other administrative costs Legal Expense Other Interest Expenses Trustee Fee Letter of Credit Fee Total Operating Expense REVENUES LESS OPERATING EXPENSE DEBT SERVICE PAYMENTS Principal ( Due 4/1) Interest _NET INCOME LESS DEBT SERVICE | ACCOUNTS RECIEVABLE FOR FY97 (asjof 8/12/97) Uncollected Revenue - KSP (6/30/97 AJR collected 7/28/97) CASH SURPLUS (DEFICIT) MONTHLY PAYMENTS REQUIRED FROM CITY Debt Service Coverage Computation Revenues less Operating Expense Rate Stabilization Fund R&R Fund Debt Coverage Amount Shortfall (excess) Amount Required cc: Dennis McCrohan, Stan Sieczkowski, Valorie Walker ORIGINAL REVISED BUDGET FORECAST 139,200 139,200 139,200 25,500 11,724 22,307 8,000 8,000 8,060 172,700 158,924 169,567 25,000 16,000 17,915 750 750 481 5,650 1,000 8,000 6,257 32,400 24,750 24,653 2,500 1,000 : 8,000 15,000 8,917 500 532 532 13,500 12,884 12,884 100 99 99 24,600 29,515 22,433 10,000 9,500 9,212 2,170 3,170 1,808 3,360 2,000 2,560 2,500 500 : 18,030 15,170 13,580 2,600 2,722 2,722 7,800 9,801 9,801 85,430 81,958 73,189 87,270 76,966 96,378 (30,000) (30,000) (30,000) (57,293) (87,293) (57,292) (87,293) (87,293) __ (87,292) (23) (10,327) e085 (33,313) (23) (10,327) (24,227) 11,600 11,600 11,600 $ 87,270 $ 76,966 $ 96,378 16,203 24,304 24,304 $ 103,473 _$ 101,270 $ 120,682 118.54% 116.01% --138.25% $ 103,473 $ 101,270 $ 120,682 $ 3,087) $ 884) $ 20,295 $ 100,386 _$ 100,386 _$ 100,386 H:all\elaine\larsen\Lars97.xls 8/12/97 2:59 PM ALASKA ENERGY AUTHORITY LARSEN BAY BUDGET -FY98 REVISED REVISED ORIGINAL FORECAST FORECAST DESCRIPTION BUDGET #1 #2 REVENUES City of Larsen Bay 139,200 139,200 130,080 : S (9,085 Kodiak Salmon Packers 20,000 20,000 20,000 Interest 7,600 7,600 7,600 166,800 166,800 166,765 OPERATING EXPENSES Operations & Maintenance by City Hydro operator services 19,000 19,000 19,000 Communications 800 800 800 Misc maintenance of hydraulic plant 7,000 7,000 7,000 26,800 26,800 26,800 Other O&M Expenses Professional Services (engineering) 2,000 2,000 2,000 Renewal & Replacement 10,000 10,000 10,000 Land Rents 550 550 550 Insurance 12,900 12,900 12,900 RSA with Risk Management 100 100 100 25,550 25,550 25,550 AEA Expense Personal Services 12,400 12,400 12,400 Travel 2,000 2,000 2,000 Other administrative costs 2,500 2,500 2,500 Legal Expense 2,000 2,000 2,000 18,900 18,900 18,900 Other Interest Expenses Trustee Fee 2,800 2,800 2,800 Letter of Credit Fee 7,500 7,500 7,500 10,300 10,300 10,300 Total Operating Expense 81,550 81,550 81,550 REVENUES LESS OPERATING EXPENSE 85,250 85,250 85,215 DEBT SERVICE PAYMENTS Principal ( Due 4/1) (30,000) (30,000) (30,000) Interest (55,223) (55,223) (55,223) (85,223) (85,223) (85,223) NET INCOME LESS DEBT SERVICE 27 27 (8) LESS ACCOUNTS RECIEVABLE CITY OF LARSEN BAY KODIAK SALMON PACKERS. CASH SURPLUS DEFICIT 27 27 (8) MONTHLY PAYMENTS REQUIRED FROM CITY 11,600 11,600 10,840 Debt Service Coverage Computation Revenues less Operating Expense 85,250 85,250 85,215 Rate Stabilization Fund 24,303 24,303 24,303 109,553 18,638 518 Debt Service Coverage (required to be 115%) 728.55%, Debt Coverage Amount 109,553 118,638 109,518 Shortfall (excess) (11,547) (20,632) (11,512) Amount Required 98,006 98,006 98,006 ec: Dennis McCrohan Stan Sieczkowski Hall\elaine\larsen\LARS98.xls 8/12/97 4:09 PM LOCHER INTERESTS LTD. 406 WEST FIREWEED LANE, SUITE 101 ANCHORAGE, ALASKA 99503-2649 TELEPHONE (907) 258-2200 FAX (907) 258-5842 April 8, 1999 APR 12 1999 Alaska Industrial Development Alaska Energy Authority and Export Authority 480 West Tudor Road Anchorage, Alaska 99503 ATTN: Stan Sieczkowski, Manager Maintenance & Operations Dear Mr. Sieczkowski: As per your request I researched the easement enquiry you received from Deanne Humphreys of Century 21 Crawford Real Estate relative to land parcel C001, T23N, R4W, S27. The subject parcel appears to lie approximately 1,000 ft west of the Alaska Intertie. There are no public right-of-ways in the immediate area of parcel C001 associated with the transmission line. Without doing a land ownership investigation, it appears that the utility easement shown on her map (accompanying her enquiry) may actually be a property boundary between lands owned by CIRI to the west, and the State of Alaska, to the east. It appears to be a % section boundary, so it may be a valid public access corridor, provided the access occurs on the State side of the 4 section line. However, she would have to contact the Department of Natural Resources concerning access rights to the subject property. Please let me know if you need further research on access to this land parcel. Sincerely, LOCHER INTEREST LTD. fed 6 bp Paul C. Rusanowski, Ph.D. Project Manager APR- 7-99 WED 7:53 AM C2ICRAWFORD REAL ESTATE FAX NO, 9073733628 baat DEANNA HUMPHREYS 951 HERMON ROAD, #5 WASILLA, AK 99654 EER iB bs wa is ee Fy ) 4 a ee = 5 ~ B PHONm: (907)376-2448 Wi Fax: (907)372-3628 Crawford Real Estate § = aan Stor SieezossKe P0G - Soy “Re. ABOYLW Ste ST Codi il ax heany Qos LOA UMN Ling ty “oreo Q® Codi. Sromks, ee on C21CRAWFORD REAL ESTATE 33 AM F5 7-99 WED APR- 7 Circuit 251-2001 251-2006 251-2011 251-2012 251-2015 251-1006 251-1012 251-2003 251-2005 251-2018 251-2321 251-1002 251-1003 251-1004 NEW. NEW MLP BILLI 251-1008 251-1010 251-1011 251-2009 251-1007 AEA BILL! AEA/CEA hea Agency | Size AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP AEA/MLP | AEA/MLP MLP MLP ooooooooocoeoo°c”]e Le] > 24 ING AMOUNTS | AEAICEA 0 AEAICEA | AEAICEA EE ar AEA/APA | 0 ING AMOUNTS DEDICATED SVCS CHANGES TO AEA RE: MLP REQUEST New Route DELETE DELETE DELETE DELETE DELETE DELETE DELETE Dgls<>Divcom (MLP T-1) _ Teeland<>DivCom(MLP T-1) Chultina<>DivCom (MLP T-1) Bradley<>DivCom (MLP T-1) Fbks<>DivCom (MLP T- 1) |Dgls<>DivCom (MLP T-1) 'Teeland<>DivCom (MLP T-1) DivCom<>Alcantra (MLP T-1) DivCom<>MLP (MLP T-1) | CEA<>DivCom (MLP T-1) |CEA<>DivCom (M (MLP T-1) _ MTA<>DivCom (MLP T-1) _ CEA<>DivCom (MLP T-1) F bks<>DivCom (MLP T-1) Circuit changes effective August 1 for billing purposes MLP Circuit #510-3002 billed through CSR # A301 -2190 MLP Circuit # 510-3001 billed through CSR#A301-2191 F:\XLS\CSR\AEACHGS.XLS Prior New Frmr cL Monge | Meage | Sheree | Charges ll 1,193.64 | 1,212.57 | 4,212.57 1,212.57 1,212.57 38] 41.27| 1,564.08 | 1,698.72 23| 24.47; 946.68 | 1,007.16 83) 86.33) 3,416.28 | 3,553.32 105) 105.04 4,321.80) 4,323.48 260.46) 260.46] 10,720.53 | 10,711.44 37.95, 41.27| 1,562.02 1,698.72 22.54 24.47| 927.75 1,007.16 ina 0) 32.27 __7,588.92 | 0} 4.03 5,663.88 29,503.06 | 30,963.60 4 4] 164.64 164.64 a) 4| 1,193.64 164.64 36.24) 36.65) 1,491.64 | 1,508.52 TL 29)F 1 4 | 4,193.64, 164.64 ~ 260.46) 260.46] 10,720.53 | 10,711.44 | | 44,764.09 | 42,713.88 |” Recurring FY98 Charges Billable ie. “ GE _Variance Amount i Fi UNC (1,193.64) 99.47 |MLP (1,212.57) 101.05 |MLP (1,212.57) 101.05 |MLP (1,212.57) 101.05 MLP (1,212.57), 101.05 /MLP - |MLP 134.64 1,687.50 ;MLP 60.48 1,002.12 |MLP 137.04 3,541.90 IMLP 1.68 4,323.34 |MLP (9.09) 10,712.20 |MLP 136.70} 1,687.33 |MLP 79.41 1,000.54 |MLP 7,558.92 6,929.01 |MLP 5,663.88 5,191.89 |MLP 1,460.54 | 36,579.49 } | | : 164.64 |AEA/CEA (1,029.00) 250.39 |AEA/CEA 16.88 1,507.11 |AEA/CEA ~_ (1,029.00) 250.39 |AEA/CEA ~ (9.09)| 10,712.20 |AEA/APA ~_ (2,050.21)| 12,884.73 | — | | | New Ckt | Number | ae 510-3001 re | | a [No change No change No change No change No change msyp Lr) P Department of Administration FY98 DIS COMMUNICATIONS SERVICE REQUEST (CSR) csr NuMBER: LY 2/PD SECTION A - To be completed by requesting Agency. RADIO PAGER FCC LICENSE ENG OTHER XX i Dept: MLP Div: RADIO SVCS Anchorage X___—- Soldotna___—s«“Fasirbanks_=—=——s Juneau___—— Glennallen__——s Otther__ Section: Requestor: TED HETHCOTE Requestor Phone #: 263-5351 Fax #:263-5836 | TASK - Circle One: RP/SR/PO No: Bill of Collection _ X_ Yes No RADIO: New Install Remove Repair Program Funding Codes: / RD Code: PAGER: New Program Repair Activate Deactivate FCC LICENSE: Marine Land Aux TV Renew Agency Fiscal Authorization (Signature) CRA fas Math cesrems ocommn. OW meh | ENGINEERING: Consulting Price Quote Requisition OTHER: DEDICATED SERVICES Printed Name C. Bat g 263-527 Date 7//8 WORK REQUESTED/COMMENTS: Routine x __ Priority (O/T Authorized) L Critical (48 hrs) Emergency (4 hrs) By signature on this form you agree to pay for the costs incurred by DIS including the established hourly rates for regular and overtime (see attached) for time, plus materials, travel, per diem and shipping. Any cost estimates given for these services are for budgetary purposes only and are not firm and binding on DIS. ests DIS provide dedicated services from the Tudor Rd DivCom site to the MLP. 9) 10 reimburse DIS for th: rv! at the published Estimated costs for size 24 dedicated circuit activated August 1: DivCom< >MLP -- 4.03 miles @ 117.12 per mile/per month X 11= $5,191.89 plus $500 install fee. TOTAL DUE: $5,691.89 Recurring charges to be paid on annual basis. = Coal SECTION B - To be completed by the Division of Information Services Funding Source (SLD) No: N/A Accounting Codes (CC/LC): 02300331/02000400 Authorized Manhours to complete work: Assigned to: Date: WORK TO BE PERFORMED: Sve Code li.e., E/O) Work Location [Date | Tech/Eng | BugNo | RegHrs | O/THrs | D/THrs | Fire Number [| Remarks- Approval Coding Seen | emer a aM 9 Base | Wells] alae | llega gs Unt heati §90 VTeaT ACI AST 1 eI ee a enn as ey cn eg | a nena a ala a Men | I aE pa ea Poorer ere Peter co Cee tre eer poe as | ac HN lon | msi nano iN Ss ESS TSA eC Sle i) la iii aa agin ct] nc | ST Tc A Sei Mode of Travel/TA No: Materials/Supplies: Materials/Supplies: BILLING INFORMATION: RADIO - PAGERS - FCC LICENSE - ENG/CONSULTING - OTHER EQUIPMENT PICKED UP BY BASIS, AMOUNT DUE BASIS AMOUNT DUE BASIS AMOUNT OUE Reguler Hours 6 FCC Fixed Retes 9 Purchase X 10% * NAME: DATE O/T OFT Hours 4 16.33 mo/Pager Months ¢ Purchase X 20% ¢ TOTAL BILLABLE J A N 7 5 ig Billable Supplies ‘ Eng/Consulting $ Service Fee $ Billable Travel . Activate Fee ‘ Misc/Other ‘ $ 5,691.89 Entered by: CKT NO DIVCOM< >MLP. Miles = 4.03 X 471.99 MonthiyRete X 11 Mos= $5,191.89 | BILLING ADDRESS: Tech ll = $61.86 Tech Supv = $66.41 Elect Maint Supv = 672.19 Supply Tech = $33.79 Procurement Specialist | = $42.84 | MUNICIPAL LIGHT & POWER Purchasing Agent Ill_= $59.82 Com Eng! = $67.44 Com Eng Il = $82.38 Com Eng Ill = $86.97 1200 E.1ST AVE. ANCHORAGE, AK. 99501 Anchorage Shop 269-5781 Juneau Shop 465-3932 Fairbanks Shop 451-2206 Soldotna Shop 262-7584 Glennalien Shop 822-5505 Customer Svcs 269-5749 G:\CSR\CSRMLPA.XLS or G:\Forms\CSRMLPA.XLS DEDICATED SVCS CHANGES TO AEA RE: MLP REQUEST F:\XLS\CSR\AEACHGS.XLS Billable Amount ~ 1,687.50 1,002.12 3,541.90 4,323.34 10,712.20 1,687.33 1,000.54 6,929.01 5,191.89 36,579.49 164.64 250.39 1,507.11 250.39 10,712.20 12,884.73 New Recurring hia Agency | Size New Route ginas oan haces Annual Charges _ et — | | | Charges | Variance 251-2001 |AEA/MLP 0 [DELETE _ : : : 251-2006 |AEA/MLP 0 |DELETE __ _ _ | (1,193.64) 251-2011 |AE/MLP | 0 |DELETE | _ __ _[- 251-2012 |AEWMLP | 0 |DELETE _ 1,212.57 |_ 251-2015 |AEA/MLP | O |DELETE pT 4,212.57 [0 251-1006 |AEA/MLP | 0 |DELETE i — — 1,212.57 | : 251-1012 |AEA/MLP | O |DELETE |. 7 . - 7 251-2003 |AEA/MLP 0 |Dgls<>Divcom (MLP T-1) 38| 41.27] 1,564.08 | 1,698.72 134.64 251-2005 |AEA/MLP -0 |Teeland<>DivCom(MLP T-1) 23) 24.47 946.68 | 1,007.16 60.48 251-2018 |AEA/MLP 0 |Chultina<>DivCom (MLP T-1) 83| 86.33] 3,416.28 | 3,553.32 137.04 251-2321 |AEA/MLP 0 |Bradley<>DivCom (MLP T-1) 105} 105.04] 4,321.80| 4,323.48 1.68 251-1002 |AEA/MLP 0 |Fbks<>DivCom (MLP T-1) _ ~~ 260.46] 260.46] 10,720.53 | 10,711.44 (9.09) 251-1003 |AEAMLP | 0 Dgls<>DivCom (MLP T-1) 37.95] 41.27] 1,562.02 | 1,698.72| 136.70 251-1004 |AEA/MLP 0 | Teeland<>DivCom (MLP T-1) 22.54] 24.47 927.75 | 1,007.16 79.41 NEW |MLP 24 |DivCom<>Alcantra (MLP T-1) 0| 32.27) 7,558.92 7,558.92 NEW |MLP 24 |DivCom<>MLP(MLPT-1) | OO}, 4.03) _| 5,663.88 | 5,663.88 MLP BILLING AMOUNTS — - oe _____| 29,503.06 | 30,963.60 1,460.54 251-1008 |AEACEA | 0 [CI 4 4, 164.64 164.64 | 251-1010 |AEAICEA sO. 29 4| 1,193.64 164.64 | (1) 029. 00); 251-1011 |AEACEA | 0 |MTA<>DivCom(MLPT-1) _ 36.24] 36.65 1,491.64| 1,508.52; ‘16.88 251-2009 |AEA/CEA 0 |CEA<>DivCom (MLP T-1) _ 29} 4] s«1,193.64| 164.64. | (1,029.00) 251-1007 |AEA/APA 0 |Fbks<>DivCom (MLP T-1) _ ~ 260.46/ 260.46] 10,720.53 | 10,711.44 (9.09) AEABILLING AMOUNTS | | ___| 14,764.09 | 12,713.88 | (2,050.21) Circuit changes effective | August 1 for billing purposes, | [ : - | MLP Circuit # 510-3001 billed through CSR #A301-2191 | - MLP Circuit #510-3002 billed through CSR #A301-2190 oo ee es es ee FY98 | CHARGE | NewCkt TO: Number { MLP_ a MLP MLP MLP - - MLP - MLP MLP 510-2003 _ MLP 510-2005 MLP 510-2018 MLP 510-2321 MLP 510-1002 MLP 510-1003 MLP_ 510-1004 _ MLP 510-3001 MLP_ 510-3002 AEA/CEA __|No change AEAICEA __|No change AEA/CEA |No change | AEAICEA No change _ AEA/APA [No change — Department of Administration FY98 DIS COMMUNICATIONS SERVICE REQUEST (CSR) CSR NUMBER: DRY 2 SV RADIO PAGER FCC LICENSE ENG OTHER XX Anchorage X___—S Soldotna Fairbanks Juneau Glennallen_ = Other__ SECTION A - To be completed by requesting Agency. Dept: MLP Div: RADIO SVCS Requestor: TED HETHCOTE Requestor Phone #: 263-5351 Fax #:263-5836 RP/SR/PO No: Bill of Collection __X_Yes No Funding Codes: RD Code: TASK - Circle One: RADIO: New Install Remove Repair Program PAGER: New Program Repair Activate Deactivate FCC LICENSE: Marine Land Aux TV Renew ENGINEERING: — Consulting Price Quote Requisition OTHER: DEDICATED SERVICES Printed Name C BUTCH RienMinm. 263-5220 WORK REQUESTED/COMMENTS: Routine x_ Priority (O/T Authorized) Critical (48 hrs) Emergency (4 hrs)__ By signature on this form you agree to pay for the costs incurred by DIS including the established hourly rates for regular and overtime (see attached) for time, plus materials, travel, per diem and shipping. Any cost estimates given for these services are for budgetary purposes only and are not firm and binding on DIS. MItP Sh5r7é Agency Fiscal Authorization (Signature) MLP requests DIS Estimated costs for size 24 dedicated circuit activated August 1: DivCom< > Alcantra -- 32.27 miles @ 19.52 per mile/ Recurring charges to be paid on annual basis. SECTION B - To be completed by the Division of Information Services Funding Source (SLD) No: N/A Accounting Codes (CC/LC): 02300331/02000400 PR: N/A Agenc Authorized Manhours to complete work: Assigned to: Date: : WORK TO BE PERFORMED: rovide dedicated services from the Tudor Rd DivCom slte to the Alcantra site. MLP agrees to reimburse DIS for the: er month X 11= $6,929.01 lus $500 install fee. TOTAL DUE: $7,429.01 Sve Code (i.e., E/O) fe fe PO EOE ERE a Po Mode of Travel/TA No: Materials/Supplies: Materials/Supplies: BILLING INFORMATION: RADIO - PAGERS - FCC LICENSE - ENG/CONSULTING - OTHER T EQUIPMENT PICKED UP BY BASIS AMOUNT DUE BASIS = AMOUNT DUE BASIS AMOUNT DUE Regular Hours ’ FCC Fixed Rates $ Purchase X 10% $ NAME: O/T DIT Hours ‘ 16.33 mo/Pager Months ¢ Purchase X 20% 4 TOTAL BILLABLE J A N 1 5 a Billable Supplies ® Eng/Consulting $ Service Fee $ Bulable Travel ‘ Activate Fee ‘ Misc/Other ’ 7,429.01 Entered by: CKT NO DIVCOM<_>ALCANTRA Miles = 32.27 X_ 629.91 MonthlyRate X11 Mos= $6,929.01 [BILLING ADDRESS: Purchasing Agent Ill = $59.82 Com Eng! = $67.44 Com Eng Il = $82.38 Com Eng Ill = $86.97 Anchorage Shop 269-5781 Juneau Shop 465-3932 Fairbanks Shop 451-2206 Soldotna Shop 262-7584 Glennallen Shop 822-5505 Customer Svcs 269-5749 G:\CSA\CSRMLP.XLS or G:\Forms\CSRMLP.XLS VOICE/DATA CIRCUIT MANUAL FY98 CKTNO | CODE CIRCUIT - AGENCY DESCRIPTION ANNUAL COST [Connect to MLP ni 2447] 923.25 5101002 | MLP_[Fbks<>DivCom [Connect to MLP T-1 effective 8-1-97 | 20s 9,827.16 510 2005 _ | MLP Teeland<>DivCom | - Connect to MLP T-1 effective 8- 1-97, - 24.47, | 923.25 510 2018 __|__MLP ‘Chultina<>DivCom _ It Connect to MLP T-1 effective 8-1-97 iL 86.33) 3,257.23 510 2321 MLP _ Brdly<>DivCom ass {Connect to’ 'MLP T I 1 effective 8-1 1-97 105.04) 3,963.16 S+8-3004+— | MLP DivCom<>Alcantra I MLP T-1 effective 8- 1-97 Ll 32.27/|Paid 98 by CSR te 510- 1003, Lil. a Connect to MLP T-1 effective 8-1 8- 1-97 ° : 41.27 : I 1,557.12 510-1 2003 _ l : MLP J} Dgis<>DivCom_ Bee | Connect to MLP T-1 effective 8-1-97 — 41. 27| 1,557.12 pote-sooz— | MLP DivCom<>MLP IIL MLP T-1 effective 8-1 97 Lt _ 4, 03 Paid 98 by CSR Lael Poe _ eee eee een = at _ } MLP TOTAL a ST IT A i ; ; i | | 22,008.29 Updated 8/11/97 by KD Langill CIRCUITS BY AGENCY F:\XLS\SAVEFY98\CKTSFY98.XLS 37 FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING KT NO ANNUAL JUL COS AUG SEPT O NOV DE! AN A APR MAY JUN TO DATE 251: cost cost cost cost cost cost | cost | cost | cost | cost | cost | cost costs IRCUIT ___leircu! mes | ss a fe KEA-TRLK PH 1 402|/KEA-TRLK PH 2 403] KEA-TRLK PH 3 404/KEA-TRLK PH 4 405. 406. t KEA-TRLK PH 5 KEA FAX LINE KEA-TRLK RO PH 228|TRLK SCADA DIALUP 2401/KEA TRLK DATA 2402|KEA TRLK RTU 2403 TRLK SCADA DATA 1,509.20 AEA PH #1 (CVE) 70.00 2,856.00, 238.00] _ Se _ __ - 476.00 AEA PH #2 (CVE) 70.00] 2,866.00] __238.00 476.00 AEA PH #3 (CVE) 70.00 2,856.00 __ 238.00 AEA PH #4 (CVE) 70.00 2,856.00] 238.00] AEA SCADA (CVE) 70.00| 2,856.00 238 UL jAL= INTERTIE SYSTEM | BRADLEY LAKE SYSTEM TOTALS _ 3,924.33 _ 6,282.97 72,489.32) 79,719.10] _ |TERROR LaKc SYSTEM TOTALS 9,055.2 ~ 754.601 _ jeesceecnt GULCH SYSTEM TOTALS 350.00] 14,280.00 1,190. - @ DAM POOL TOTALS 14,267.97, 175,543.62) 14,760.59, 12,151.90 | T | — - - — — — ew _ + | —- a Prepared by KD Langa F.\FYSBSLO\ AEACKT96.XLS 9/8/97 FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING ANNUAL [JUL TO DATE cost cost cost cost cost cost cost | cost | cost | cost | cost | cost costs CIRCUIT _ MILES _ a es [T | - ™ - annem —. nian + —— ine Larrea at | I a —— AEA PH-OIMRO/HEA 2.00; | . - = _.. 13.72 _1014|AEA PH-SLOTN | 65.00] 2,678.40 CL [ 445.90 __1016|/BROLY-CEA RD PH _ _105.00] 4,321.80 ia 720.30) 1016/DSPTCH LN-D.RIDGE 5,021.52 — | 836.92 1017|CEA-HEA RD PH _ 6,021.62 —— | _| jo | 836.92 1018/AEA PH-BROLY __ 987.84 l= | E i _ 164.64 1019|HMR-SLOVA RD PH oe sf | _ 96.04 / ze HEA-CEA RD PH : 6,021.52 ml _| | | 836.92 S51 |PH TRK HOM-BROLY LK _ __ 987.84 | | 164.64 _1301|BROLY CO TRK #1 |___—- 987.84 _ — 164.64 _1302/BROLY CO TRK #2 - __987.84 = =| 164.66 1303/BROLY DAM PH #1 — _ 27.44 1304 BROLY DAM PH #2 oe 27.44 “1308|BROLY DAM PH #3 [ 27.44 1306 |BROLY DAM PH #4 — _ ft “27.44 1307 | BROLY DAM PH #5 | =| aoe [ 27.44 _1308|/BROLY DAM PH #6 E [| ee im 27.44 _1309|BROLY DID TRK #1 24.00) _ SS SS =5 164.64 1310) BROLY DID TRK #2 24,00] _ _ ae _ = 164.64 1311 |/BROLY CO TRK #2 24.00 | — a oe | pees: | eS _ 164.64 1312/BROLY CO TRK #4 24.00 _— | = _ 164.64 _2301|XER TRIP DROG SLOIN 62.00] 2,661.92 _ _ _ } le 7 426.32 _2303|AEA DATA-DRDG ATU 62.00] 2,651.92 tL - — - 426.32 2304/SLOTNA DATA LOGGER 62.00 2,861.92 _ - 425.32 2305 | XFER TRIP-BROLY/SLOTN 51.00} —- 2,099.16 iv ; . - —s = eee =e | _ 349.86) *=°6|XFER TRIP-BRADLY/ORDG 24.00) 987.84 i _ 82.32| le - : | eee 164.64 _y _/BRDLY LK TRU (CEA) 105.00| 4,321.80] «360.15 960.15) _ ee ee ______720.30 2309 BRDLY MTN SCADA DATA 2.00] _ 82.32} 6.86 6.86; : —— _ | 13.72 2310/D. RIDGE RTU (CEA) 122.00] 6,021.52 418.46 418.46 _ 7 —_ ime [me 836.92 _2311 AEA DATA BROLY/HMR 24.00) 987.84) 82.32 82.32 __ - — 164.64 2312/BROLY DAM SCADA DATA 4.00) | 164.64, 13.72 13.72 _ | _27.44 2313/01m RD METERING HEA 2.00) _ 82.32) 6.86. 6.86 _ i —— 13.72) _2317|BROLY DIAL-UP RTU | 105.00} 4,321.80; 360.15 360.15 a _ —_ | 720.30 2318 |D.RIDGE DIALUP RTU 122.00; 5,021.52| 418.46 418.46) df _ 7 = | 836.92 2319 BROLY DSM CKT (CEA) 105.00] 4,321.80) 360.15 360.15 _ |} | ____ 720.30 2320) BROLY DECNET (GVEA) 106.77] 4,394.65 366.22 366.22| _ : J ; | esos _ 732.44 _2321|BROLY < >DivCom (MLP T-1) 105.04 4,323.45) 360.15|MLP 8-1-97 : | | eee - tt 360.15 2322 BROLY MTR'NG (CEA) 105.00 4,321.80 360.15 = | _ | ______720.30 TOTALS 1,936.81 ‘ Prepared by K 0 Langull FAFY9BSLO\ AEACKT9B.XLS 9/8/97 FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING KT RO ANNUAL |JUL COST AUG SEPT ocT NOV DEC JAN FEB MAR APR MAY JUN TO DATE 251- | cost cost cOosT cost cost cost cost cost cost cosT cosT cost COsTS 2 Foks < >DivCom(MLP T-1) 903__|Dgis< >DivCom (MLP T-1) Teeland < >DivCom (MLP T-1) Fbks< >DivCom Chg 8-1-97 CEA< >DivCom Chg 8-1-97 CEA.OGLS MTA <>DivCom Chg 8-1-97 36.65] 1,608.61 | GVEA.CNTWUSTVNS/OGLS _ 234,00] _ |Dgis<>DivCom (MLP T-1) | 38.00 ze OGLS TLON XFER TRIP - 21.00 Teeland < >DivComiMLP T-1) 23.00 —-946.68) T Z APAIANC-FAI DATA #2 263.00! 10,825.08 a 8 [DOUGLAS ATU (CEA) 41.00] 1,687.56 7 016 |AEA/MEA OGL-CHLT 46.00] 1,893.36 - _ 017 |AEA/CEA LKHO CHLT | 3.01] 3,416.69 : 018 |Chuttina< > DivComiMLP T-1) 83.00] 3,416.28) MLP 8-1-97_ = 006 |APA PH-EKLTN 29.46] 1,212.57] pisc 8-197 | _ - 7 010 |\CEA<>DivCom Chg 8.1.97 4.00| 164.64 : 13.72| _{ 006 |APA DATA-EKLIN 29.00] 1,193.64 oisca197 | | | al 009 |CEA< >DivCom Chg 8:1-97 4.00] ‘164.64 — 13.72[ i | rn _ 011 |MLP-EKLTN 29.46| 1,212.57, DISC 8-1.97 | __ 012 |MLP-EKLTN DATA 29.46] 1,212.67/ —-101.06/DIsc 8-1-97 | _ - _ 015 |AEA DEA#3 MLP EKLTN 29.46, 1,212.57 101.05|DISC 8-1-97 _ Prepared by KO. Langit F\FY9BSLO\ AEACKT98.XLS 9/8/97 x ALASKA INDUSTRIAL DEVELOPMENT SALE.“ Skcecoriumoen"” ALASKA @@ =ENERGY AUTHORITY x * 480 WEST TUDOR ANCHORAGE, ALASKA 99503 907 / 269-3000 FAX 907 269-3044 MEMORANDUM TO: Stan i FROM: Elaine 7L0--— DATE: February 12, 1998 SUBJECT: Changes in Dedicated Circuits Billing from Div Comm Beginning with the August invoice (received in December) from Div Comm, the following circuits were dropped from the billing: Circuit # Description Other Info 1002 Anc-Fai Hotline Intertie O&M Cost 1003 MLP-DGLS PH Intertie O&M Cost 1004 MLP-TLND PH Intertie O&M Cost 2003 MLP-DLGS RTU Intertie O&M Cost 2005 MLP-TLDN Intertie O&M Cost 2018 AEA/MLP-CHLT Intertie O&M Cost 1006 PH-EKLTN AEA Previously billed to MLP 2006 Data-EKLTN AEA Previously billed to MLP 2011 MLP-EKLTN AEA Previously billed to MLP 2012 MLP-EKLTN DATA AEA Previously billed to MLP 2015 MLP-EKLTN AEA Previously billed to MLP 2321 Bradley DECNET-MLP Bradley O&M Cost Also beginning with the August, the following circuits were reduced from 29 to 4 miles: Circuit # Description Other Info 1010 PH-EKLTN AEA bills to CEA 2009 Data-EKLTN AEA bills to CEA 01/29/98 THU 13:05 FAX 907 465 3450 Alaska Data Ctr. Booz ° é . ’ . = oe. Wescind MUNICIPALITY OF ANCHORAGE We MUNICIPAL LIGHT & POWER => MEMORANDUM DATE: July 25, 1997 TO: Stan Sieczkowski/A.I.D.E.A./Director, Facilities Operation FROM: Ted Hethcote/MI&P/Radio Shop Supervisor 72 SUBJECT: DELETION OF A.E.A. LEASED CIRCUITS The following is a list of analog circuits from ML&P Operations Bldg. to the Eklutna Power Generation Facility. ‘The circuits are currently listed on the A-E.A. list of circuits and should be removed as of August 1, 1997. ML&P has made arrangements with Div. Comm. to provide a T-1 path for these circuits which Div. Comm, will bill ML&P directly for beginning August 1, 1997, Also reflected on this list are 2 circuits from C.E.A. These circuits will still be on your list from C.E.A. to Tudor Rd. but will be transferred onto the ML&P T-1 from Tudor Rd. to Eklutna and that portion should be removed from your list. Circuit # Circuit Description @ 1006 APA-PHONE-EKLTN 1012 MLP-DATA-EKLTN ; 2001 MLP-PHONEEKLTIN> “Ot be ovr Soly bill, @ 2006 APA-DATA-EKLTN () 2011 MLP-PHONE-EKLTN @ 2012 MLP-DATA-EKLIN © 2015 AEA DEA#3 MLP-EKLIN _ . 1010 CEA-PHONE-EKLTN — pralec fctlwed Low 29 4 2009 CEA-DATA-EKLTN mies fotluced Gon D4 104 If you have any questions regarding this please contact me at 263-5351. O Propped. from oavt bil) De gaanard 6/1197 Crrov lines Avoppeck Prom +5 2) 97 jane co. Whe! 1OOQ- Taoterke 1Ooo3- Dnsenhe , 1oO4- Trier tbe NAWORDDCALETTER\TEDIOB\STATECKT DOC 200 3- Taper te QOS - Tntyvyh~ Qo 1Z-Indevke 232\- ane FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING CKT ANNUAL [JUL-COST| AUG] SEPT] OCT | NOV] DEC] JAN] FEB] MAR] APR | MAY | JUN] TODATE NO cost cost | cost | cost | cost | cost | cost | cost | cost| cost} cost | cost| costs 251- | cinculT MILES A<>F INTERTIE SYSTEM APA/CNTWL PH _|APAPH-FAL | (260.46) 10,720.53 MLP-CEA PH _|APA RD PH-ANC/PLMR GVEA-CNTWUSTVNS/DGLS DGLS TLDON XFER TRIP APA/ANC-FAI DATA #2 DOUGLAS RTU (CEA) 00) _ f |AEA/MEA DGL-CHLT | .00} 1,893.36) _|AEA/CEA LKHD-CHLT i . 3,416.69 Prepared by K.D. Langill FAFY98SLD\ AEACKT98.XLS FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING CKT ANNUAL |JUL COST) AUG SEPT OocT NOV DEC JAN FEB MAR APR MAY JUN TO DATE ] NO cost cost | cost | cost | cost | cost | cost | cost| cost| cost| cost | cost| costs 251- JciRcuIT MILES : IBRADLEY LAKE SYSTEM 1013|AEA PH-DIMRD/HEA 2.00 82.32 6.86 . _1014|AEAPH-SLOTN 65.00} 2,675.40, 222.95 | oe 1015|BROLY-CEA RD PH 105,00} 4,321.80 360.15 : jo : ee : - 1016|DSPTCHLN-D.RIDGE —s|_122.00| —5,021.52| 418.46 Sa | ft _1017|CEA-HEARDPH 122.00| _ 5,021.52 418.46 | ___| 2S 1018|AEA PH-BRDLY 24.00 987.84 82.32 1019| HMR-SLDVA RD PH 14.00 576.24 48.02 __1020|HEA-CEARD PH __ 122.00| 5,021.52} 418.46) | ff ff __1021|PH TRK HOM-BRDLY LK 24.00) 987.84 82.32 | _ | —_ _4301/BROLYCOTRK#1 24.00 987.84 82.32 _ ee _ - -1302|BRDLYCOTRK#2 24.00) 987.84) 82.32 [oo —[ fof |_1303/BRDLY DAM PH #1 4.00 13.72 _ — _ _1304/BRDLY DAM PH #2 _ 4.00 13.72 - - _1305|/BROLY DAMPH#3 4.00 13.72 | 2 a _ 1306 |BRDLY DAM PH #4 4.00 13.72 jo | a jo} _ 1307/BROLY DAM PH #5 | 4,00 13.72 i. ee - : a : 1308|BROLY DAM PH #6 en) 13.72 _ — - = __ 1309|BRDLY DID TRK #1. 24.00 82.32| i — - | __1310/BROLY DID TRK #2 24.00 82.32 - 1311/BRDLY CO TRK #2 24.00 82.32 1312|BRDLY CO TRK #4 24.00 82.32 2301|XER TRIP DRDG-SLOTN 62.00 2,551.92 212.66 2303|AEA DATA-DRDG RTU 62.00] 2,551.92 212.66 , | “ie — 2304] SLDTNA DATA LOGGER 62.00} _ 2,551.92 212.66 - | __2305|XFER TRIP-BRDLY/SLDTN 51.00} 2,099.16 174,93 : ei _ __2306|XFER TRIP-BRADLY/ORDG | 24.00, _— 987.84, 82.32 a | _ : : fe _ 2307/BRDLYLKTRU(CEA) |‘ 105.00|_—4,321.80| 360.15 ee : | : 1 jo - __2309|BRDLY MTN SCADA DATA __ 2.00} 82.32 6.86 » ee a : re 2310/D.RIDGERTU(CEA) ss |_'122.00/ _—5,021.52, 418.46. 1 Se a _ - __2311|AEA DATA-BRDLY/HMR 24.00| 987.84! 82.32) oe fo __2312/ BRDLY DAM SCADA DATA 4.00| 164.64 13.72 ae - _ - - 2313|DIM RD METERING HEA _ 2.00} 82.32) 6.86 eo | _ oe 2317|BROLY DIAL-UP RTU 105.00} 4,321.80 360.15 : | : 2318|D.RIDGE DIAL-UP RTU. 122,00] 5,021.52| 418.46 . — ft a : — ot __ 2319/BRDLY DSM CKT (CEA) _ 105.00] 4,321.80) 360.15 | tf | ee : - 20|BRDLY DECNET (GVEA) _ te = }22|BRDLY MTR'NG (CEA) _ BRADLEY TOTALS 79,717.45 by K.D. Langit F.\FY98SLD\ AEACKT98.XLS- 5 8/20/97 FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING CKT ANNUAL |JUL COST; AUG SEPT ocT NOV DEC JAN FEB MAR APR MAY JUN TO DATE NO cost cost COST Cost COST COST | COST | COST | COST | COST | COST | COST COSTS 251- loRcuT MILES TERROR LAKE SYSTEM 1401/KEA-TRLK PH 1 20.00 823.20/ 68.60 Se Te a Ak ie __1402|KEA-TRLK PH 2 20.00 823.20, «68.60 or immune (ie 1403|KEA-TRLK PH 3 | 20.00 823.20) 68.60 L Tall pein ; Tei 1404|KEA-TRLKPH4 ss |_—«20.00 823.20 68.60 im Jd 1405|KEA-TRLK PH 5 20.00) 823.20 68.60 [ KEA FAX LINE | 20.00 823,20| «68.60 7|KEA-TRLK RD PH 20.00 823,20| «68.60 TRLK SCADA DIALUP _ 20.00 823.20 68.60 KEA-TRLKDATA KEA-TRLKRTU TRLK SCADA DATA [AEA PH #1 (CVE) —_ 4102/AEAPH#2(CVE) ——s| ~—«70.00| ~—2,856.00] 238.00 l TL a ee TT le | ____ 238.00 ~1103]AEA PH #3 (CVE) 70.00] 2,856.00| 238.00 7 iL age a el | 238.00 1104|AEA PH #4 (CVE) 70.00) 2,856.00 238.00 i meee | ___ 238.00 AEA SCADA (CVE) SOLOMON GULCH TOTALS 1,190.00 «14,280.00 |A<>F INTERTIE SYSTEM 1,805.50) 74,314.36 6,192.87 BRADLEY LAKE SYSTEM TOTALS _| 1,936.77 79,717.45| 6,643.12 ie! a il ze TERROR LAKE SYSTEMTOTALS | 220.00 9,055.20] __—754.60 ol Ss ee ee eT Taco IN GULCH SYSTEM TOTALS | 350.00) _ 14,280.01 Lae ee ee Te ee cea eo eee eee eee ea Prepared by K.D. Langill F:AFY9BSLD\ AEACKT98.XLS- r 8/20/97 FY98 AEA RADIO CIRCUIT MONTHLY BILLING — CKT NO 251 A<>F INTERTIE SYSTEM 0201 |CNTWL-TRK RDO #1 0202 |CNTWL-TRK RDO #2 0203 |CNTWL-TRK RDO #3 0204 |CNTWL-TRK RDO #4 0205 |CNTWL-TRK RDO #5_ CIRCUIT 0301 |BDLY LK OPNS RPTR 0301.1/BDLY LK OPNS RPTR 0301.2|BDLY LK OPNS RPTR 0301.3/BDLY LK OPNS RPTR 0301.4|BDLY LK OPNS RPTR 0301.5|/BDLY LK OPNS RPTR 0302 |RDO-SOLD/HOMER 0303 |SCADA RPTR-LOCAL 0304 |SCADA RPTR-LOCAL TERROR LAKE SYSTEM 0402 |KEA ELBOW RPTR SOLOMON GULCH SYSTEM 0101 |AEA Rptr Tisn/Ens/Div 0102 |Intcm Ckt (CVE) A<>F INTERTIE SYSTEM BRADLEY LAKE SYSTEM TERROR LAKE SYSTEM SOLOMON GULCH SYSTEM reset BRADLEY LAKE SYSTEM i 4 DAM POOL TOTALS Prepared by KD Langill | 49.81 MILES 106.07 106.07 106.07 106.07 106.07 59.22 59.22 49.81 49.81 49.81 57.88 14.65 67.32 72.30 530.35 375.56 14.65 139.62 1,060.18 ANNUAL COST} JUL 5,855.06 5,855.06 5,855.06 5,855.06 5,855.06 3,268.94 3,268.94] 2,749.51 2,749.51 2,749.51 2,749.51 3,194.98 808.68 3,716.06| 3,990.96 29,275.32] 2,439.61 20,730.91) 1,727.58 808.68] 67.39 7,707.02| 642.25 58,521.94 Z 487.92 487.92 487.92 487.92 487.92 309.67 332.58 67.39 cosT 272.41 272.41 229.13 229.13 229.13 229.13) 266.25 -4,876.83 AUG CcOosT SEPT cosT oct cost NOV COST DEC COST FA\FY9BSLD\ AEARAD98.XLS JAN cosT FEB COST MAR COST APR COST MAY cosT JUN Cost , TO DATE COSTS 487.92 487.92 487.92 487.92 487.92 67.39 1,727.58 67.39 4,876.83 8/20/97 Cantwell Chulitna Elbow Mt Elbow Mt Terror Lk Terror Lk Divide Ernestine Tolsona Vdz DOT LOCATION Cooper Mt_ Cooper Mt_ Dm Ridge _ Ninilchik | A<>F INTE SOLOMON _EQUIPMENT _ [A<>F INTERTIE SYSTEM - VHF Repeater MEA Microwave _ BRADLEY LAKE SYSTEM SCADA Radio _ __|SCADA Radio __ _|VHE Repeater oe CEA Base #1 CEA Base #2 HEA VHF Repeater _ CEA UHF Link _ CEA VHF Base TERROR LAKE SYSTEM — VHF Base Station VHR RTU Station VHF Base Station — VHR RTU Station SOLOMON GULCH SYSTEM | CVEA VHF Repeater CVEA VHF Repeater __ _|CVEA VHF Repeater VHF Repeater Prepared by KD. Langill ANNUAL COST 2,682.36 2,682.36 2,682.36 2,682.36 2,682.36 2 6] 2,682.36 "2,682.36 2,682.36 2,682.36 2,682.36 __2,682.36 2,682.36 2,682.36 2,682.36 2,682.36| __2,682.36| JULY COST 2,682.36| 223.53 223.53 ~ 223.53 223.53 223.53 223.53] 223.83 223.53 ~ 223.53) AUG cost F:FYQBSLO\ AEAS&P9B.XLS FY98 AEA SPACE POWER MONTHLY BILLS FEB Cost APR TO DATE COSTS &DAM POOL TOTALS 56 529.56| 400413, | 1 1 | || CG 9/24/97 , +-23-1998 1:51PM FROM MLP POWER MGT/OPS 9@7 263 5441 P.1 NZ a eal Light & boner 1200 East First Avenue Anchorage, Alaska 99501-1685 Telephone: (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 January 23, 1998 Ms. Elaine McCambridge AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Elaine: Please review the invoice package that ML&P received from the Alaska Division of Information Services (DIS). Up until July. 1997 ML&P was invoiced from AEA, not the DIS. Also the AEA invoices to us were for circuits 1006, 2006, 2011, 2012, and 2015 (by our records) through July 1997. . The invoices from DIS for August through the present show: * Circuits 2011, 2012, and 2015-as disconnected. * Added circuits 1002, 1003, 1004, 2005 and 2018. * No record of circuits 1006 or 2006, which we have been paying AEA for (we thought). Please explain why these changes were made on our invoices in order to clarify why our bill is three times higher when billed by DIS. Thanks. Sincerely, DWbopebal 7%-Timothy F. McConnell : } Manager, Power Management ce: Stan Sieczkowski Qvestown from. ML? Putting Energy into Anchorage for Over 60 years DIVISION OF INFORMATION SERVICES #026-5225 SOA-ADM Job Cost Code G/L Account VENDOR CLASS: AFIOP E-501-56600-000 E-501-18100-000 $4,879.22 | E-501-56600-000 $894.12 | E-501-56600-000 ($13,622.00) E-501-31000-000 $425.32 $12,565.94 J E-201-53900-302 $3,455.16 J E-201-53900-303 $4,917.66 | E-201-53900-302 ($20,938.76) E-201-31000-000 R9801 | 003 VENDOR CLASS: FDPOP R9801 | 001 | 53900 R9801 | 002 | 53900 R9801 | 003 | 53900 $3,889.20 | E-301-53900-000 $1,419.28 | E-301-53900-000 $3,576.48 | E-301-53900-000 ($8,884.96) E-301-31000-000 Approval: Approval: COLLECTION \0/| \\\ FE SEE BOTTOM FOR REMITTANCE ADDRESS BILL NUMBER 026-5225 Division of Information Services P.O. Box 110206 Juneau, Ak 99811-0206 Ak Ind Dev. & Export Auth. T1480 West Tudor Anchorage, Ak 99503-6690 Attn: Linda Day DEPARTMENT OF AD MINISTRATION porn? AGENCY CONTACT DIXIE BOGGS DATE FEBRUARY 4, 1998 |(907) 465-5763 MAKE CHECKS PAYABLE TO: STATE OF ALASKA IMPORTANT 1. Please reference bill number on your check. 2. Submit a copy of this form with your payment. DATE SCRIPTION UNIT PRICE D 10 QUANTITY [cost | PER | AMOUNT STATE OF ALASKA FY 98 12/97-1/98 Billing for the month s of December 97 & January 98 Dedicated Circuits 2mo 12151.90 | month 24,303.80 Space & Power 2mo 4694.13| month 9,388.26 Radio Circuits 2mo 4876.:83] month 9,753.66 DEPT OF ADMINISTRATION/DIV OF INFORMATION SERVICES AMOUNT DUE THIS BILL $ 43,445.72 NUMBER AMOUNT DATE | COMMENTS VEN | 4 FIN AMOUNT SY cc EN LC ACCT re 1 24,303.80 02300320 51406 98 2 9,388.26 02300373 [51406 98 | 3 9,753.66 02300372 51406 98 | a | | BILLING AUTHORITY'S NAME TITLE BILLING £ RITY'S SIGNAT! TELEPHONE NUMBER DIXIE BOGGS ACCOUNTING TECHNICIAN /, 2 (907) 465-5763 2-472 (Rev. 6/85) ORIGINAL / RECIPIENT ONE COPY EACH FOR: MITTANCE / DEPT. FIS' PARTMENT CIRCUIT BROLY CO TR (1312/BRDLYCOTRK#4 | 2301|XER TRIP DRDG-SLDTN _ 2303 |AEA DA ‘A-DRDG RTU 2304 |SLDTNA DATA LOGGER 2305 IXFER TRIP- BRDLY/SLDTN 2306 [XFER TRIP-BRADLY/DRDG _ 2307 |BRDLY LK TRU (CEA) 2309 |/BRDLY MTN SCADA DATA. D. RIDGE RTU (CEA) EA DATA-BRDLY/HMR- 2312/BRDLY DAM S SCADA, DA’ 2313 |DIM RD METERING HEA 2317 /BRDLY DIAL-UP RTU 2318 D.RID E DIAL-UP __ 2319|BRDLY DSM CKT (CEA) 2320 |BROLY DECNET (GVEA) BRDLY<>DivCom (MLP 7 "2,551.92 2,099.16 COST FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING ANNUAL JUL AUG COST SEPT COST oct cost NOV COST cost JAN cosT DEC COST 4,321.80 4,394.65) 2 | BRDLY MTR'NG (CEA) 3|KEA-TRLK PH3 _1404|KEA-TRLK PH 4 1405|KEA-TRLK PH 5 ~1406/KEA FAX LINE 1407 |KEA-TRLK RD PH 1408 |TRLK SCADA DIALUP KEA-TRLK DATA KEA-TRLK | RTU AEA PH #1 (CVE) AEA PH #2 (CVE) AEA PH #3 (CVE) |AEA PH #4 (CVE) SOLOMON GULCH TOTALS As>F INTERTIE SYSTEM LEY LAKE SYSTEM TOTALS __ TERROR LAKE SYSTEM TOTALS _ SOLOMON GULCH SYSTEM TOTALS '4-DAM POOL TOTALS Prepared by K.D. Langill _ 2,856.00 2) 856.00 14,280.00 72,489.32 - [79,7 719.10, 9,055.20 14,280.00 175,543.62 4,267.97 1,190.00 6,192.87 6,643.12 754.60 1,190.00 14,780.59 6,282.97 1,190.00 3,924.33| 3,924.33| 3,924.33| 3,924.33 _ 6,282.97] 6,282.97) 6,282.97| 6,282.97 754.60 754.60/ 754.60| 754.60 1,190.00/ 1,190.00] 1,190.00] 1,190.00 12,151.90 1,190.00} 1,190.00| 1,190.00 12,151.90 | 12,151.90} 12,151.90 FAAFY98SLD\ Aeackt96 xis 12,151.90 1,190.00 3,924.33 | 3,924.33 6, 282.97 6, 282.97 754.60 754.60 1,190.00 12,151.90 1,190.00 APR cOsT MAY COST JUN COST TO DATE COSTS 1,488.62 1,488.62 1,488.62 1,224.51 576.24 2,929.22 $76.24 96.04 48.02 2,521.05 1,666.00 ___ 1,666.00 1,666. 00 1,666.00 44,340.94 5,282.20 8,330.00 87,691.99 2/4/98 FY98 AEA VOICE/DATA CIRCUITS MONTHLY BILLING AUG COST OCT NOV DEC | JAN | FEB | MAR | APR | MAY | JUN | TODATE | NO cost COST COST COST cost COST cosT COST cost COST COST | COST COSTS CIRCUIT APAICNTWL PH 2,545.06 1002 _|Fbks<>DivCom(MLP T-1) }[MLP 8-1-97 Ay 893.38 1003 _|Dgls<>DivCom (MLP T- MLP 8-1-97 - = 7 130.17 } Teeland<>DivCom (MLP T-1) | E ; a a 77.31 : j_ || 6,253.66 7 i = 96.04 Li i 984.41 i a — 878.56 GVEA-CNTWUSTVNS/DGLS _ 9,631.44 | T .. | 5,618.34 2003 [Dgls<>DivCom(MLPT-1) | 1,564.08 | a 130.34 2004 |DGLS TLDN XFER TRIP eI 504.21 ‘eeland<>DivCom(MLP T-1) | 7 - 78.89 APA/ANC-FAI DATA #2 Lido inne a 6,314.63 2008 |DOUGLASRTU(CEA) 7.56. 140.63) 63; 140. 140.63) i We 984.41 2016 |AEA/MEA DGL-CHLT AEA/CEA | LKHD-CHLT MLP 8-1-9) DISC 8-1-97 [APA PH-EKLTN 1010 _|CEA<>DivCom Chg 8-1-97_ APA DATA-EKLTN DISC 8-1-97 pat Sy 5 |DISC 8-1-97 DISC 8-1-97 DISC 8-1-97 MUP-EKLTN 2012 |MLP-EKLTNDATA ‘AEA DEA#3 MLP-EKLTN 2,521.05 BROLY- CEA RD PH 4,321.80 : DSPTCH LN-D.RIDGE_ 5,021.52 | 2,929.22 CEAHEARDPH 5 I 2,929.22 AEAPH-BROLY | 876.24 HMR-SLDVARDPH 876.24 Se te 336.14 HEA-CEA RD PH 5,021.52) | HSE =i tt 2,929.22 1 PH TRK HOM-BF o| (987.84 LLL = | 576.24 BROLYCOTRK#1 _987.84| 82.32 82.32 | 876.24 BRDLY CO TRK #2 987.84) 82.32| 82.32| BRDLY DAM PH #1 164.64 13.72 13.72 4|BRDOLYDAMPH#2 5 |BRDLY DAM PH #3 BROLY DAM PH #4 07 |BRDLY DAM PH #5 BROLY DAM PH #6 BRDLY DID TRK # BRDLY DID TRK #2 Prepared by K.D. Langill FAFY9BSLD\ Aeackt98.xis 214/98 CKT NO 251- CIRCUIT CNTWL-TRK ROO #1 __ONTWL-TRK ROO #2 _|CNTWL-TRK | CNTWL-TRK RDO. #4 CNTWL-TRK RDO #5 BDLY LK OPNS RPTR BDLY LK OPNS RPTR -|BDLY LK OPNS RPTR BDLY LK OPNS RPTR |BDLY LK OPNS RPTR RDO-SOLD/HOMER SCADA RPTR-LOCAL SCADA RPTR-LOCAL _|AEA Rptr Tisn/Ens/Div FY98 AEA RADIO CIRCUIT MONTHLY BILLING |A<>F INTERTIE SYSTEM SEPT ANNUAL | JUL | AUG mites | cost | cost | cost 5,855.06] 487.92| 487.92 5,855.06| 487.92| 487.92 OcT COST NOV COST DEC JAN cosT FEB COST 487.92 487.92 Intem Ckt (CVE) eRADEEY TERROR LAKE SYSTEM SOLOMON GULCH SYSTEM _ 14 DAM POOL TOTALS Prepared by KD Langill 3,990.96 29,275.32 2 _Tr07.02 58,521.94 4,876.83 2,439.61 1,727.58 67.39 642.25 4,876.83 4,876.83 __ 2,439.61 41,727.58 | 1,727.58 _ 2,439.61 | _ 2,439.61 1,727.58 4,876.83 4,876.83 4,876.83 F:A\FYQBSLD\ Aearad98.xIs 2,439.61 1,727.58 4,876.83 MAY COST TO DATE COSTS ~aai65 3,415.45 3,415.45 3,415.45 3,415.45 1,906.88 1,603.88 1,603.88 1,603.88 __ 1,603.88 ___ 2,167.70 2,328.06 17,077.27 12,093.03 471.73 | 4,495.76 34,137.80 2/4/98 FY98 AEA SPACE POWER MONTHLY BILLS AUG SEPT oct NOV DEC JAN FEB _COsT | COST | _COST. APR | MAY | JUN cost | COST | COST |TO DATE COSTS _ LOCATION | EQUIPMENT _| ANNUAL COST | JULY COST |A<>F INTERTIE SYSTEM Cantwell [VHF Repeater ss | 2, 682.36 Me MIL I 1864.71 Chulitna MEA Microwave 2,682.36 1,564.71 |A<>F INTERTIE TOTALS BRADLEY LAKE SYSTEM | 3,129.42 MtSite |SCADARadio 7 7 Lo 1,564.71 Mt Site SCADA Radio | 2,682.36 a ae ; 1,864.71 MtSite _|OperationsRadio -s«||—S—«2,682.36 [ : 1,564.71 MtSite [Operations Radio =| —S=—«, 682.36 I - ma 1,564.71 PowerHs _|VHF Repeater 6 ie ff 64.71 Cooper Mt |CEABase #1 2,682.36 ; : 1,564.71 Coopermt |CEABase#2 |S, 682.96) 7 ins See a 1,564.71 Dm Ridge HEA VHF Repeater 2,682.36 : 1,564.71 Homer _|HEAVHF Repeater =| ——(2,682.36| 1,564.71 Ninichik — |CEAUHF Link =| (2,682.96) ni im 1,564.71 CEA VHF Base ; 2,682.36 : 1,564.74] Bradley Totals TERROR LAKE SYSTEM 17,211.81 __|VHF Base Station 7 _ 2,682.36 a L _ 1,564.71 VHRRTU Station | | JOLT ai Ges 1,564.71 VHF Base Station — 1,564.71 64.71 TERROR LAKES TOTAL’ CVEAVHF Repeater I HL : 864.71 CVEAVHF Repeater || ——2,682.96 - 1,564.71 CVEA VHF Repeater 2,682.36 | 1,564.71 1,564.71 JA<>F INTERTIE SYSTEM Pe! 5,364.72} 447.06) 447.06) 447.06) 447.06 447.06) 447.06 44706} - | 3,129.42 BRADLEY LAKE SYSTEM ___ 29,505.96 2,458.83 2,458.83) 2,458.83) 2,458.83) 2,458.83) 2,458.83 2,458.83) - | 17,211.81 TERROR LAKE SYSTEM 10,729.44 894.12 _ 894.12 894.12) 894.12 894.12} 894.12 894.12 6,258.84 894.12 894.12) 894.12 894.12 6,258.84 460415] 460419) 460413] _aeoass) | || 1] saeseai SOLOMON GULCH SYSTEM 4 DAM POOL TOTALS 10,729.44 56,329.56 894.12 894.12 894.12 4,694.13 Prepared by K.D. Langill F:FYQ8SLD\ Aeas&p98.xis 2/4/98 BILL NUMBER - BILL FOR COLLECTION 026-5225 DATE FEBRUARY 4, 1998 SEE BOTTOM FOR REMITTANCE ADDRESS DEPARTMENT OF ADMINISTRATION Division of Information Services P.O. Box 110206 Juneau, Ak 99811-0206 Se AGENCY CONTACT DIXIE BOGGS 907) 465-5763 MAKE CHECKS PAYABLE TO: STATE OF ALASKA Ak Ind Dev. & Export Auth. T0!480 West Tudor Anchorage, Ak 99503-6690 IMPORTANT 1. Please reference bill number on your check. 2. Submit a copy of this form with your payment. Attn: Linda Day UNIT PRICE DATE DESCRIPTION QUANTITY “cost | PER | AMOUNT leave OF ALASKA FY 98 12/97-1/98 Billing for the month s of December 97 & January 98 Dedicated Circuits 2mo 12151.90| month 24,303.80 Space & Power 2mo 4694.13] month 9,388.26 Radio Circuits 2mo 4876.83] month 9,753.66 DEPT OF ADMINISTRATION/DIV OF INFORMATION SERVICES AMOUNT DUE THIS BILL $ 43,445.72 TYPE COMMENTS NUMBER AMOUNT | ___ DATE 24,303.80 02300320 | [2 9,388.26 02300373. ‘| 3 9,753.66 | [02300372 | 4 (oy BILLING AUTHORITY'S NAME TITLE DIXIE BOGGS ACCOUNTING TECHNICIAN 2-472 (Rev. 6/85) ORIGINAL / RECIPIENT TELEPHONE NUMBER (907) 465-5763 mse M re @ Mp 2-13-98 = Se Sam (Teed Bea Felt (ako sewt) ee eee hat 1] 1/ Wh 2009 - EK - ceA CHUGACH ELECTRIC ASSOCIATION, INC. #1 1999 4 ssn Alaska Industrial Development end Export Authority Mr. Dean Strid, Chief Communications Engineer Information Technology Group State of Alaska 5900 East Tudor Road Anchorage, Alaska 99507 Re: Use of Silvertip Communications Site Dear Dean: Chugach is requesting use of the State of Alaska facilities at your Silvertip Communications Site. We very much need to gain control of several circuit re-closers and sectionalizing switches at our Hope Substation which is located approximately one mile down the hill from the Silvertip site. To be able to control these devices remotely through our SCADA system would significantly decrease the amount of time it takes to restore electrical power to the community of Hope; in some cases would also reduce the time it takes to restore transmission outages to sections of the Kenai Peninsula. As you know we have a digital microwave link into Summit Lake, as well as the license and equipment for a microwave link from Summit Lake to-Silvertip. We also have a twenty-five pair communications cable installed along the distribution power line from Hope Substation to your site at Silvertip. We have started the process of obtaining a permit for locating a building and establishing a helicopter landing area at Silvertip, but do not expect the State of Alaska, Department of Natural Resources to issue a permit before next spring. We would like to complete the microwave link into Silvertip before winter and our heavy outage season begins. To do this, we need to obtain space in your Silvertip building on a temporary basis and space on the tower for a six-foot microwave dish and a yagi antenna for a UHF radio. In exchange for the building and antenna space, Chugach would provide the State of Alaska a DS1 circuit from Silvertip through our microwave facilities on the Kenai Peninsula back to Anchorage to tie into your facility at Lake Hood. This would provide the State of Alaska a circular loop from Anchorage around the Kenai Peninsula back into Anchorage by a completely different transmission path. It would provide the State of 5601 Minnesota Drive ¢ P.O. Box 196300 « Anchorage, Alaska 99519-6300 Phone 907-563-7494 « FAX 907-562-0027 Mr. Dean Strid October 20, 1999 Page 2 of 2 Alaska an alternate means of routing 24 of your more important circuits, from the Kenai Peninsula back to Anchorage should one of your normal transmission paths fail for some reason. Next spring or early summer as soon as our permit is obtained, Chugach will place our own building on the site and relocate our equipment out of your building. To keep from building another tower in the vicinity of yours, we would like to keep the two antennas on you tower permanently. We would continue to provide the State the DS1 circuit back to Anchorage for as long as we continue using the tower. If this plan of action is agreeable to you, we will draft a document outlining this agreement and forward it to you. We would very much appreciate it if you would consider this offer and let us know your decision as quickly as possible. If you have any questions or need more information, please contact me at 762-4711 or Steve Spezialy at 762-4756 Sincerely, CHUGACH ELECTRIC ASSOCIATION, INC. Veer (lpr? Vance Cordell Manager, Telecommunications Pe B. Hickey, CEA C. Johnson,CEA S. Sieczkowski, AEA L. Thibert,CEA S. Spezialy,CEA “ Ovm —& NN Ale Cava) COPPER VALLEY ELECTRIC ASSOCIATION, INC. P.O. BOX 45 GLENNALLEN, ALASKA 99588-0045 Glennallen (907) 822-3211 |). jo si a) Valdez (907) 835-4301 | © f= SF Telefax # (907) 822-5586 | || \ i January 20, 1995 Mr. David E. Kendall Star Route Box 115 Mile 56 Richardson Highway Valdez, Alaska 99686 SUBJECT: Response to APUC Complaint C-94-239 Dear Mr. Kendall: The purpose of this letter is to respond to you regarding the complaint you filed with the Alaska Public Utilities Commission concerning Copper Valley Electric Association’s (CVEA) failure to provide central station electric service to the Tiekel River Valley. Ms. Agnes Giles, Chief of the Consumer Protection and Public Information section, has directed CVEA to respond directly to you on the issues raised in your letter of December 10, 1994. As I understand them, the issues raised in your letter are as follows: Issue 1: You have accused CVEA of discrimination by failing to provide or pursue a PVT transformer installation to serve the Tiekel River Valley residents. You have cited the DOT installation at Thompson Pass as precedent setting and, therefore, as the basis for your allegation of discrimination. . CVEA Response to Issue 1: CVEA disagrees that residents of the Tiekel Valley have in any way been discriminated against by the Association’s refusal to pursue the PVT tap. As you know, the Valdez to Glennallen transmission line is owned by the State of Alaska and is operated under an agreement between CVEA and the Alaska Energy Authority (AEA). As such, CVEA requires the approval of the Authority for many operational considerations which may affect the transmission system including interconnection of additional facilities to the system. CC! DwB SES SERVING MEMBER-OWNERS IN THE COPPER RIVER BASIN AND VALDEZ EC. Respdnse to APUC Complaint C-94-239 January 20, 1995 Page 2 Issue 2: The DOT facility in Thompson Pass was opposed by the Alaska Energy Authority at the time of the installation but was later approved because CVEA had already purchased the necessary equipment following a verbal approval by a former AEA project engineer. As you can see from reviewing the May 12, 1988, letter to Doug Bursey from AEA’s Director of Program Development and Facilities Operation, Don Shira, significant concern existed at the time of the installation. The subject of tapping the transmission line for distribution purposes was recently discussed with AEA personnel, and it is our understanding that the AEA is firmly opposed to further attachments to the line. The reason for the AEA’s opposition to tapping the transmission line are clearly outlined in a letter to you from William (Riley) Snell dated August 19, 1994 (attached). Following receipt of your complaint, the subject of tapping AEA owned transmission lines was brought to the Project Management Committee (PMC) of the Four Dam Pool utilities group. CVEA informed the PMC of your request and asked for the State’s position with regard to tapping Four Dam Pool transmission facilities for distribution projects. The State representative reiterated the State’s opposition to any such taps. During the PMC meeting, this issue of tapping Four Dam Pool transmission lines was recently referred to the Technical Standards Committee of the Four Dam Pool for the purpose of establishing written policy on this issue. CVEA does not believe the service provided to the DOT camp is precedent setting in requiring similar attachments for future projects. In accordance with the Long Term Power Sales Agreement between the AEA and the Four Dam Pool Purchasing Utilities, a decision to tap state owned transmission facilities requires the approval of both the AEA and the purchasing utility (CVEA in this case). AEA does not approve of your proposal to tap the transmission line. CVEA concurs with AEA’s decision. To summarize CVEA’s position regarding your allegation that the utility has discriminated against you, I would like to point out that the AEA would not allow a PVT tap on the transmission line even if CVEA thought it was a prudent thing to do. Inasmuch as the State owns the transmission line, I do not see the necessity of pursuing this option further. You have accused CVEA of acting in bad faith for your project and cite as support for your allegation an internal CVEA memo prepared by Robert Wilkinson dated August 29, 1992. In my view, this memorandum represents a cogent evaluation of the facts and circumstances surrounding our dealings with Tiekel River at the time it was written, and to the extent it does not accurately represent the facts, I would appreciate being so advised. I believe the foregoing adequately responds to the allegations outlined in your letter. Ms. Giles requested that I provide you with the terms of our line extension tariff which would apply to a distribution line extension to ‘Response to APUC Complaint C-94-239 January 20, 1995 Page 3 Tiekel Valley. Although I am certain you have it, I have enclosed a copy of our current effective line extension tariff for your review. The relevant section of the tariff for an extension to the Tiekel Valley is Section 7.2. There are a few other points I would like to communicate to you regarding this matter. L. uw In my judgment, CVEA went far beyond good faith in trying to develop a solution to serving the Tiekel River Valley. The bottom line, as with most business decisions, is money. CVEA must protect the financial interests of the members, and the standard method of protection is ensuring that a substantial investment will generate a return for a specified period of time. That policy is set forth in our line extension tariff. Be advised CVEA’s line extension tariff is currently being revised by order of the APUC. The results of the revision may impact the method of return for line extensions in the future. The DOT tap and a tap at Tiekel are not valid comparisons. Building a distribution line to the Thompson Pass DOT site is not a viable alternative. CVEA’s existing Valdez distribution system ends at 10 mile on the Richardson Highway. Given the expense of 16 miles of line and the weather conditions in Thompson Pass, this was not seen as a viable alternative. I believe you are significantly underestimating the cost of the PVT tap. Ifthe tap cost $80,000 in 1988, it is significantly higher today. In addition, Tiekel is one mile from the transmission line. Add $60,000 and add an additional $10,000 for customer installations. Before long you approach the cost of the distribution project. Mr. Kendall, I believe this letter accurately responds to your complaint to the APUC. Should you wish to discuss the correspondence in greater detail, please call me. Yours truly, Clayton Hurless General Manager co Richard Huffman, General Counsel Agnes Giles, APUC CVEA Board of Directors Attachments w:\word\raw\95-007nh.doc Stave Cowper. Governer Alaska Power Authority State of Alaska May 12, 19868 Mr. ony arity. General Manager Copper Valley Electric Association Box 45 Glennallen, Alaska 99586 Subject: Service to DOT Camp at Thompson Pass Dear Doug: On May 10, 1988, the Alaska Power Authority received a telecopy from Frank Bettine stating that Copper Valley Electric Association (CYEA) intends to install the potential transformers at the DOT camp at a Pass. The telacopy also contained sketches of the transformer platform, During a site visit by Larry Wolf and ae Vast fall, Frank introduced the plan for this service to us and indicated that Mr. Harry Beck had approved of this proeeer We indicated at that tima that there is no record of Mr. Beck's approval and that Frank should submit to our office the project plans and a Wa would then review them and initiate our spree) or disapproval depending on the affect this installation would have on our facilities, contracts and directives. This has not bean done to date and we cannot concur with-this project until the necessary documentation is completed and approved. This will also become another ravanue metering point to be included in the Long Term Power Sales Agreement and approved by the PMC. The concapt of attaching to a Power Authority transmission line in this manner {$s not in keeping with our past policies or state statutes for the Power Authority. I ask that proper and sufficient information be forwarded to this office for approval of a request to attach to our facilities in this manner. Do not proceed with attachment to the transmission line until the review and approval is completad, OC PO. Bor AM Juneau, Alaska 99811 (907) 465-3676 Sf PO Box 190869 = 7U1 EastTudorRoad = Anchorage, Alaska 09819-0869 (907) 561-7877 2655/854/1 OT 38Hd 989-228-206: Xd4 91430013 A9| [eA 490009: 111 TS:0T SAVBI“TO Mr. Doug Bui y May 12, 1988 Page 2 Thank you for your attention to this matter. Sf ly; y 4 a ; Dt bee, Donald L. Shira Diractor of Program Development and Facilities Operations LW:DLS:aa ce: Larry Wolf, Alaska Power Authority Frank Bettine, CVEA 2656/854/2 TT = 3Hd 98SS-228-2L06: X44 9143998|3 sell e4 40dd09: 01 25:01 SAVAT/TO COPPER VALLEY ELECTRIC ASSOCIATION, INC. a aol Te, EXTENSION OF FACILITIES Without Special Provisions Upon written application of the owner of any permanent, reasonably dry premises that are accessible year-round by standard four-wheel-drive vehicle that can be served from existing suitable distribution lines by the addition of a primary pole, transformer(s) and necessary conductors (or equivalent) and fulfillment of other line extension criteria set forth in Guidelines for New Services, the Association shall furnish and construct at its own cost such facilities and service connections as are necessary to render service. Requiring Special Provisions Upon written application of the owner of a permanent, reasonably dry, residential or commercial/industrial premises acceptable year-round by standard four-wheel-drive vehicle that requires a line extension or addition of facilities costing more than provided for in Rule 7.1, the Association will provide up to the normal limit of one primary pole, transformer(s) and service drop (or equivalent) with no cash contribution or advance from the member. Where economically feasible and funds are available, the Association will invest additional 50% matching funds for a line extension to serve a member(s), up to a maximum distance of one mile, when the Association is assured that orderly, permanent growth in the area to be served is imminent and the extension will be along publicly maintained roads or within adjacent residential subdivisions meeting current City of Valdez or applicable state and local requirements. In such cases, the member(s) will be required to pay a cash advance-for-construction equal to 50% of the estimated total additional funds required to complete the extension. Line extensions exceeding the Association’s normal limit of one primary pole, transformer(s) and service drop (or equivalent), but not meeting the requirements underlined above, will require that the member(s) served pay a cash advance-for-construction equalling 100% of the estimated additional funds required to complete the extension. This advance will be adjusted to actual cost after job completion. See Rule 7.2.C, Paragraph 5, for refund of advances-for-construction. Tariff Advice No. 109 Effective: Issued by; Tr Valley Electrig’ Association. Inc. By: Title: General Manager Sea eeekee = ee — a ee] ented! homed ‘mene APUC No. _10 Original Version Sheet No. __39 COPPER VALLEY ELECTRIC ASSOCIATION, INC. as EXTENSION OF FACILITIES (CONT.) 7.2. Service Provisions (cont.) Where the Association is not assured that the premises to be served will be occupied permanently and take electric service continuously, or where the applicant’s investment in permanent improvements is insufficient to warrant a line extension up to the Association’s normal limit of one primary pole, transformer(s) and service drop (or equivalent), the member shall provide an advance in lieu of permanent improvements equal to the estimated cost of construction. This advance will be adjusted to actual cost after job completion. See Rule 7.2.C, Paragraph 5 for refund of advances-for-construction. (a) Residential or Commercial/Industrial Subdivision (1) Subdividers shall provide the Association with a plat of their subdivision showing all necessary utility easements, lots to be served, and other necessary information. (2) Subdivider shall make to the Association a payment, as an advance-for- construction, equal to the Association’s total cost of the primary line extension to and within the subdivision. The extension shall include all construction required to serve each lot within the subdivision, including transformers and pedestals if underground construction. (3) Construction may either be overhead or underground, at the option of the subdivider. The Association will prorate the amount per lot from the overall total construction cost and consider the prorated amount as the cost of extending service to each lot within in the subdivision. The prorated amount will not include contributions-in-aid-of-construction. (4) If the applicant elects underground service, the Association requires a non-refundable contribution-in-aid-of-construction equal to the difference, as estimated by the Association, between the cost of the underground service requested and the cost of constructing comparable overhead facilities. Tariff Advice No. 109 Effective: Issued by~ C Valley Electrig Association, Inc. By: Title: General Manager APUC No. _10 Original Version dneet NO. ___ su Cancelling Sheet No.__40___ COPPER VALLEY ELECTRIC ASSOCIATION, INC. ve EXTENSION OF FACILITIES (CONT.) 7.2 Requiring Special Provisions (cont.) (a) Residential or Commercial/Industrial Subdivision (cont.) (5) Service will be extended from the main line to applicants within the subdivision following their routine application for membership and electric service. At such time, all requirements of membership in the Association will be in force. (6) | The Association may, at its option, allow phased development of a subdivision upon the presentation to the Association of adequate security for completion of the subdivider’s obligations herein. (7) At such time that the Association connects a permanent service for a customer, a refund will be made to the subdivider on the basis of the prorated amount for one lot per service connected. (8) Underground Line Construction - At such time that the Association makes permanent connection to the primary system, the Association will make a refund to the subdivider based on the least expensive = | method of construction. - (9) All advances-for-construction made by subdivider which have not been i : refunded after a period of five (5) years from original construction due ‘ to the lack of additional applicants will become the property of the , Association and will no longer be refundable. i ' (b) Mobile Home Courts A i It shall be the responsibility of a Mobile Home Court owner to construct an overhead or underground electrical distribution system which will include the = necessary primary, secondary, and service facilities, as well as the necessary mn transformers and members’ service equipment (excluding the meter) to the Association’s designated location where existing distribution facilities are B available. The electrical distribution system to be installed by the owner must have the Association’s approval prior to energizing the lines. r Tariff Advice No. 109 Effective: - Issued by;— Copper Valley Electrfc Association, Inc. By: Title: General Manager f a im BER = APUC No. _10 Original Version Sheet No. __41 Cancelling COPPER VALLEY ELECTRIC ASSOCIATION, INC. 7.2 EXTENSION OF FACILITIES (CONT.) Requiring Special Provisions (cont. (b) Mobile Home Courts (cont.) Once the installation is completed in accordance with the Association’s approved design, it shall be the Mobil Home Court owner’s responsibility to operate and maintain the underground or overhead secondary voltage distribution system. The Association will assume the responsibility to operate and maintain the primary voltage distribution system. Refunds for Advance-for-Construction A partial or total refund of advance-for-construction for any individual line extension will be made within five years when the requirement for minimum monthly revenue has been met or sufficient additional qualifying permanent structures are served from the extension. Refunds will be made by the Association only upon written request by the member(s) who paid the original advance-for-construction or their bona fide successor in interest. Additional members served from the original line may be required to bear a portion of the original advance-for-construction, in addition to any payments arising from new line extensions to serve them. Refunds of any advance-for-construction will not exceed the normal maximum cost the Association would have borne to serve the new member at the time of the original line extension. After the appropriate above provisions have been met, each applicant for service requiring a line extension may be required to sign a service contract for a term of five (5) years or any term appropriate to his particular case as adjudged by the Association. — Tariff Advice No. 109 Effective: Issued by: Valle’ ic Association. Inc. By: Title: General Manager APUC No. _10 Original Version Sheet No. ___42 Cancelling Sheet No. 42 COPPER VALLEY ELECTRIC ASSOCIATION, INC. a. EXTENSION OF FACILITIES (CONT.) 7.2 Requiring Special Provisions (cont.) (c) Refunds for Advance-for-Construction (cont.) Any line extension must retum minimum revenues on the following basis: (1) (2) (3) (4) (6) If the service point is within 1,500 feet of a state or publicly maintained road--2 % of the estimated cost of construction or 2% of the actual cost of construction, whichever is less. If the service point is over 1,500 feet from a state or publicly maintained road--3 % of the estimated cost of construction or 3% of the actual cost of construction, whichever is less. The minimum monthly bill stipulated in any line extension service contract will not be less than 2% of the cost of providing one primary pole, transformer(s) and a service drop. As stated above, the service contract guarantees the Association a minimum revenue level. The service contract is not intended as a device to promote increased usage of electricity. The Association continues to promote energy conservation among its membership. Whenever more than one member is connected to a line extension, the minimums shall be adjusted to yield the Association, in total minimum revenue, not more than 36% of the cost of the extension in any one year for all members served from the extension. The minimums shall be reasonably allocated to the members from the extension. The Association may terminate all service contracts applying to a line extension whenever revenues derived from the extension provide adequate return on the investment. [ rant Advice No. 109 Effective: Issued by: r Valley Electpic Association, Inc. By: aie Title: __ General Manager an bh! Fa Ew APUC No. _ 10 Original Version Sheet No. ___43 + Cancelling Sheet No. 43 COPPER VALLEY ELECTRIC ASSOCIATION, INC. i: Ted emer Tariff Advice No. __109 Effective: EXTENSION OF FACILITIES (CONT.) By Member Extension of the Association’s facility by an applicant will not be permitted under any conditions; however, the Association will make a physical connection to and provide service to an applicant who at his own expense has constructed his own suitable facilities for distribution of electrical energy, provided the applicant’s facilities are situated within a feasible distance of suitable existing facilities of the Association; the applicant’s facilities are used solely and continue to be used solely to distribute electrical energy to premises owned by the applicant within the boundary of a land area owned by the applicant; and the applicant has installed at the point of connection of the two facilities a suitable means of safely disconnecting his facilities from the Association’s facilities. The point of connection of the two facilities will be the point of receipt of service. Any facilities constructed by the applicant in accordance with the above will be the property of and will remain the property of the applicant, and the Association will not assume responsibilities for the applicant’s facilities. Issued by>>_C: t Valley Eleétric Association, Inc. By: ; Title: General Manager U ime GN 4“ MEP Municipal Light & Power POWER MANAGEMENT 1200 East First @venue Anchorage Alaska 99501-1685 phone 907.263.5450 fax 907.263.5441 a DiC WE Tn) x clic d W ic ) LU oot 13 1999 Alaska Industrial Development and Export Authority October 8, 1999 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of September 1999. Sincerely, Doug Hi Chief Power Dispatcher DH/pjc Attachment CG: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA J. Cooley, CEA R. Morgan, MEA C. Petty, AEA c:\1-patty\IOC\so-oprtr\usage\cov-Itr.doc 05-Oct-99 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD ALASKA INTERTIE USAGE REPORT FY 2000 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHS ML&P TO GVEA 2244 616 38 2898 ML&P DELIVERIES 2244 616 38 0 O 0 0 0 0 0 0 0 2898 ML&EP TO CEA TO CEA TO CEA TO BRAD. LKE TO GVEA AEGET GVEA 18776 846 0 9333 844 0 11667 838 0 0 39776 0 2528 ° CEA BRADLEY LAKE GVEA AIDEA DELIVERIES DELIVERIES DELIVERIES DELIVERIES 19622 0 oO 0 10177 0 O 0 12505 0 oO 0 0 0 0 0 0 0 0 0 0 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 42304 0 0 0 GVEA TO ML&P GVEA RECEIPTS 21020 9949 11705 0 ° 0 0 0 0 0 ° 0 42674 $219,771.10 GVEA TO GVEA TO CEA AEG&T 0 0 0 0 0 0 0 0 AIDEA CEA RECEIPTS RECEIPTS 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 $0.00 $0.00 AIDEA TO CEA 0 0 0 ML&P RECEIPTS 0 0 ° 0 0 0 0 0 $0.00 AIDEA TO ML&P AEGET RECEIPTS 846 844 838 0 eo ooo o 2528 $11,780.48 AIDEA TO AEG&T LINE TOTAL 21866 10793 12543 ° 0 0 ° 0 0 0 0 oO 45202 $210,641.32 05-Oct-99 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ALASKA INTERITE USAGE REPORT FY 2000 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs. MLP TO GVEA 0 0 0 MLP TO = CEA TO GVEA CEA TO AEGT TO GVEA MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES 0 oo oe mo) oo So oo 0 ecocooeo eo OOOO CO te 0 coo o oO OOO OO oO tn AEGT TO DELIVERIES ecco e oO OOO OOO GVEA TO MLP GVEA TO CEA GVEA TO AEGT 0 0 0 GVEA RECEIPTS sooo ooo OOO OC Oe $0.00 0 0 0 RECEIPTS eococooo eo OO OOO $0.00 0 0 0 TO MLP TO CEA TO AEGT 0 CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL 0 ecococoeo ee oO OOO oO $0.00 0 ocooo oO OOOO CO $0.00 0 cooooeo eo oO OC OC CO $0.00 — i — a $0.00 (907) 486-7700 Box 787 i KODIAK, ALASKA 99615 September 17, 1997 Mr. Rod Towell SEAFIRST Columbia Seafirst Center 701 Fifth Avenue, Floor 23 P.O. Box 24565 Seattle, WA 98124 Re: — Disbursement Control Summary 97-98-0012-0012 Dear Mr. Towell: Please disburse funds from the Four Dam Pool Project Management Committee's Initial Project Revenue Fund to the following: Name & Address Control# —_ Description Amount Parisena, Stromberg & Co. 980012 Inv dtd 09/09/97 $ 26,957.00 3301 C Street, Suite 520 Professional Services Anchorage, AK 99503 and Fees through June 30, 1997 Please make these disbursements as soon as possible Lg Walter Sapp Vey PMC Treasurer lo: Dennis Lewis [30 PMC Chairman PMC Secretary To 19874862441 Pas gg-12-1997 @2:S8PM FROM FACSINILE TRANSMISSION PARISENA, STROMBERG & CO. OFFICE PHONE: 563-4547 3301 C. STREET, SUITE 520 FAX PHOME: 561~7683 ANCHORAGE, ALASKA 99503 7 / DESTINATION CITY & STATE: 1A 9 PAX NO. 93b- sue | : F@-(2- (Incl. this page) COMPANY: ATTN/DEPT (Ait COMMENTS SUBJECT: Hee eee eee Ree Pheer ere cont ) C SENDER: (/ rts usa eZ a PARISENA, STROMBERG & CONPANY PAX No. (907) 561-7683 IF YOU DID NOT RECEIVE ALL PAGES, PLEASE CALL (907) 563-4547 . 69-12-1997 2:59PM FROM Ta 19874862441 P.a2 PARISENA, STROMBERG & COMPANY A Professional Corporation Certified Pubiic Accountants 3301 C. Street, Suite 520 Anchorage, Alaska 99503 Tel. (907) 563-4547 FIN. 92-0143184 September 9, 1997 Project Management Committee % Walter Sapp, Treasurer Kodiak Electric Association, Inc. P.O. Box 787 Kodiak, Alaska 99615 INVOICE NO. 586 For professional services rendered through June 30, 1997 in connection with: Fees Consulting - Meeting Attendance (January and May, 1997) $ 4,320 Expense Reimbursement: Per Diem and Lodging (Seattle and Valdez) 1,162 Airfare (Seattle and Valdez) 528 Postage and Express 60 Expense 1,690 Total Meeting Cost 6,010 Fees Annual Audit (160%): 2,600 Audit Expense Reimbursement: Telephone/FAX 46 Total Audit Cost ____ 2,646 Coordinating Services: December, 1996 - September, 1997 10,000 Fees - Accounting assistance 1,650 11,650 , 89-12-1997 B2:S9PM FROM Page 2 Parisena, Stromberg & Company Invoice No. 585 Expense Reimbursement: Tax Fees - J.C. Swailing Postage and Express \Reproduction Supplies, Ete. Telephone/FAX Expense Fees - Annual Budget Expense Reimbursement: Reproduction Total Budget TOTAL INVOICE Ta 19874862441 618 105 258 105 326 1,412 5.040 199 5,239 $ __26.957 Ps O3 BEATY & DRAEGER, LTD. ATTORNEYS AT LAW 3900 ARCTIC BLVD., SUITE 101 ANCHORAGE, ALASKA 99503 ROGER H. BEATY TEL. (907) 563-7889 TERRY P. DRAEGER eae ed FAX (907) 562-6936 nERCEIWEL EWU W ie i) Ih SEP 15 .100q [ ) Tuesday, September 14, 1999 VET aw so oe Alaska K e@ Indusirial Development : ; : nd Export Authority Stan Sieczkowski, Operations Mgr. RE yoy AIDEA 480 W. Tudor Rd. Anchorage, AK 99503 Re: City of Larsen Bay Dear Stan: Thank you for your telephone call on September 13, 199 wherein Valerie and you verified that the bonds would not go into default until the next payment due date of April 1, 2000. As you know, the City of Larsen Bay is doing everything in its powers to enter into an operation and maintenance agreement with KEA or AVEC. If you have any questions, please contact me. Sincerely, BEATY EGER, LTD. ry P. sete TPD/dah Larsen Bay/99L9 AIDEA ce: Allan Panamoroff, Mayor City of Larsen Bay MUN I € 1 P Ae tT Y Oo F a N € H O R @€ G@ E Rick Mystrom = Mayor ECEIVE| |) April 19, 1999 APR22 1989 —~ Alaska Industrial Development and Export Authority MEP Municipal Light & Power Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 POWER MANAGEMENT 1200 East First Avenue Anchorage 7 dioie Dear Sian: 99501-1685 Please find attached the REVISED Alaska Intertie Usage Report for the current e fiscal year through the month of March 1999. This revision was made to show the corrected amount for the January GVEA sale to ML&P. phone 907.263.5450 Sincerely, fax 907.263.5441 CS) Doug Hall Chief Power DiSpatcher DH/pjc Attachment oc: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA J. Cooley, CEA R. Morgan, MEA C. Petty, AEA ¢:\1-patty\I[OC\so-oprtr\usage\coy-Itr.doc 19-Apr-99 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD ALASKA INTERTIE USAGE REPORT FY 99 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs ML&P TO GVEA 684 602 2217 624 239 66 47 65 184 4728 ML&P DELIVERIES 684 602 2217 624 239 66 47 65 184 4728 ML&P TO CEA TO CEA TO CEA TO BRAD. LKE TO GVEA AEG&T GVEA 9912 0 ° 6405 45 0 11313 0 0 11329 27 0 3683 159 0 2442 O 0 1321 72 0 1525 0 0 4762 0 0 O 52692 ° 303 ° CEA BRADLEY LAKE GVEA AIDEA DELIVERIES DELIVERIES DELIVERIES DELIVERIES 9912 0 0 0 6450 0 143 67 11313 0 0 0 11356 O 0 0 3842 0 0 0 2442 0 0 0 1393 0 38 0 1525 oO 0 0 4762 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 52995 0 181 67 GVEA TO MLE&P 143 181 GVEA RECEIPTS 10596 7007 13530 11953 3922 2508 1368 1590 4946 0 0 0 57420 $295,713.00 GVEA TO CEA coo oo oO OO AIDEA RECEIPTS 0 0 oo $0.00 GVEA TO AEGET coo oO oO oO oO oO CEA RECEIPTS 0 67 0 ooo 0 0 0 67 $345.05 AIDEA TO CEA Joo coo o oo 67 ML&P RECEIPTS 0 143 38 ooo °o 181 $932.15 AIDEA TO ML&P 0 0 0 0 AEGET RECEIPTS 0 45 O 27 159 72 ec oo oO 303 $1,560.45 AIDEA TO AEGET eco ec oO oO OO LINE TOTAL 10596 7262 13530 11980 4081 2508 1478 1590 4946 0 0 0 57971 $298,550.65 TBPA Thomas Bay Power Authority — TYEE LAKE HYDROELECTRIC PROJECT — P. O. BOX 1318 WRANGELL, ALASKA 99929 (907) 874-3834 FAX (907) 874-2581 Sept. 30, 1999 AIDEA Attn: Mr. Stan Sieczkowski 480 West Tudor Rd. Anchorage, AK 99503 RE: Wrangell relay operations Dear Stan; During the relay testing that was performed by Chris Zavadlov of Powers Engineers in July of 1999, it was confirmed that all the relays on the Wrangell feeder breaker have had the instantaneous portion of the relays taken out of service some time in the past. I can not find any information to explain the reason for this occurrence. This concerns me because we continually get target drops that are telling us that we are getting an over- current situation. I do not know enough about this continual over-current and what effect that it has on the equipment, if any. The issue at this point is that TBPA has control of the City of Wrangell’s retail relay protection and may be liable for damages initiated from the city of Wrangell feeder breakers. A possibility of rectification is to adjust the settings on the feeder breaker’s protection relays. This may require a coordination study or at least your awareness that this portion of the protection is not in service. The enclosed report is only one of many re-occurring reports that indicate over-current situations. Please give us guidance in what you would like to have done regarding this situation and the liability issues that are connected with it. Sincerely, Ray Alt General Manager enclosures WRANGELL SUB STATION FLAG DROPS NAME. 3 WeEWson/ Date:_ywe ¢=23~97_ Time: /4/4— CUBICLE 1 CST 22__BKR50 ANNUNCIATOR PANEL TRANSFORMER DIFF. 87T-A TRANSFORMER DIFF. 87T-B Row 1 TRANSFORMER DIFF. 87T-C TRANS. HOT OVER-VOLTAGE 59-1 TRANS. DIFF LOCK OVER-VOLTAGE 59-1 ling TRANS. MISC. TROUBLE TRANS. PRESS RELIEF REVERSE POWER 32) TRANS. AIR TROUBLE STATION REVERSE POWER CUBICLE 2 BREAKER 51 OVER-CURRENT 50/51-A TIME INST Row 2 OVER-CURRENT 50/51-B TIME INST | OVER-CURRENT 50/51-C TIME INST |-~}| WRSwyp LINE OVER-CURR OVER-CURRENT 50/51-N TIME INST | MAIN FEEDER FAULT STATION 12.5 KV BUSS OvR-VLT CUBICLE 3 STATION FREQUENCY LOW TRANS. OVER-CURRENT 51T-A TIME INST 125 VDC Low VOLTs TRANS. OVER-CURRENT 51T-B TIME INST 125 VDC BATT. CHGR. TROUBLE TRANS. OVER-CURRENT 51T-C TIME INST TRANS. NEUTRAL 51TN-1-HV TIME INST Row 3: MAIN S1M-A TIME INST LINE 1 FAULT MAIN 51M-B TIME INST LINE 2 FAULT MAIN 51M-C TIME INST LINE 3 FAULT TRANS. NEUTRAL 51TN-2-LV TIME INST [UT BREAKER 52 Row 4 OVER-CURRENT 50/51-A TIME INST |] OVER-CURRENT 50/51-B TIME INST LINE 4 FAULT OVER-CURRENT 50 /51-C TIME INST OVER-CURRENT 50/51-N TIME INST [4 UNDER-FREQUENCY 81-U CUBICLE 4 BREAKER 53 OVER-CURRENT 50/S51A TIME INST Note: OVER-CURRENT 50/51B TIME Inst | 7 After logging all the Annunciator OVER-CURRENT 50/51C TIME InsT | “| alarms, push the ACK button and OVER-CURRENT 50/51N TIME Inst [W/Z then the RESET button to clear the alarms. Alarms that do not CUBICLE 5 BREAKER 54 clear are alarms that are still OVER-CURRENT 50/51-A TIME INST || active. OVER-CURRENT 50/51-B TIME INsT |] OVER-CURRENT 50/51-C TIME INST V1 Note: Return this sheet to the OVER-CURRENT 50/51-N TIME INST controlling station. Tyee/Oper/ Forms/Wrg. Sub 05/08/99 . WRANGELL SUB STATION FLAG DROPS NAME: H fe wsorl Date._ § -Q4Y-99 Time: OFAC CUBICLE 1 CST 22 BKR50 ANNUNCIATOR PANEL TRANSFORMER DIFF. 87T-A TRANSFORMER DIFF. 87T-B Row 1 TRANSFORMER DIFF. 87T-C |_| TRANS. HOT OVER-VOLTAGE 59-1 TRANS. DiFF LOCK OVER-VOLTAGE 59-1 TRANS. MISC. TROUBLE TRANS. PRESS RELIEF REVERSE POWER 32 TRANS. AIR TROUBLE STATION REVERSE POWER CUBICLE 2 BREAKER 51 OVER-CURRENT 50/51-A TIME INST |] Row2 OVER-CURRENT 50/51-B TIME INST i) OVER-CURRENT 50/51-C TIME INST WR SwyD LINE OVER-CURR OVER-CURRENT 50 /51-N TIME INST |1~{ MAIN FEEDER FAULT STATION 12.5 KV BUSS OvR-VLT CUBICLE 3 STATION FREQUENCY LOW UT TRANS. OVER-CURRENT 51T-A TIME INST 125 VDC Low VOLTS uM TRANS. OVER-CURRENT 51T-B TIME INST 125 VDC BATT. CHGR. TROUBLE | (~ TRANS. OVER-CURRENT 51T-C TIME INST TRANS. NEUTRAL S51TN-1-HV TIME INST Row 3 MAIN S1M-A TIME INST LINE 1 FAULT MAIN 51M-B TIME INST LINE 2 FAULT MAIN 51M-C TIME INST LINE 3 FAULT TRANS. NEUTRAL SITN-2-LV TIME INST BREAKER 52 Row 4 OVER-CURRENT 50/51-A TIME INST OVER-CURRENT 50/51-B TIME INST |v LINE 4 FAULT OVER-CURRENT 50/51-C TIME INST |,“ OVER-CURRENT 50/51-N TIME INST UNDER-FREQUENCY 81-U yt CUBICLE 4 BREAKER 53 OVER-CURRENT 50/51A TIME Inst [77 Noi OVER-CURRENT 50/51B TIME INST After logging all the Annunciator OVER-CURRENT 50/51C TIME INST | U4 alarms, push the ACK button and OVER-CURRENT 50/51N TIME INST then the RESET button to clear the alarms. Alarms that do not CUBICLE 5 BREAKER 54 clear are alarms that are still OVER-CURRENT 50/51-A TIME INsT | J active. OVER-CURRENT 50/51-B TIME INST OVER-CURRENT 50/51-C TIME INsT | Note: Return this sheet to the OVER-CURRENT 50/51-N TIME INST controlling station. Tyee/Oper/ Forms/Wrg. Sub 05/08/99 GOLDEN VALLEY ELECTRIC ASSOCIATION INC. PO Box 71249 » Fairbanks, Alaska 99707-1249 * 907-452-1151 ECEIVED) eee October 13, 1999 194999 L Alaska Industrial Development and Export Authority Stan Sieczkowski Alaska Industrial Development and Export Authority 480 West Tudor Anchorage, AK 99503-6690 Subject: Alaska Intertie Usage Report Dear Stan: GVEA, THE ALASKA INTERTIE NORTHERN CONTROL AREA OPERATOR, SUBMITS THE FOLLOWING: Per article 10.1.4.6 of the Alaska Intertie Agreement, we are submitting the Alaska Intertie Usage Report for fiscal year 2000 through the month of September 1999. Born Dray Goer Bradley Evel Sysiem Dispatch Managei Attachment cc: John Cooley CEA Robert Day AMLP Robert Drake MEA Sam Matthews AEGT INTERTIE MIDPOINT AMLP to GVEA FYOO MONTH JULY 2244 AUGUST 616 SEPTEMBER 38 OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YEAR TOTAL 2898 INTERTIE MIDPOINT AMLP to GVEA FYOO MONTH JULY 0 AUGUST 0 SEPTEMBER 0 OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YEAR TOTAL 0 CEA GVEA 18776 9333 11667 39776 CEA to GVEA ooo CEA AEGT 846 844 838 2528 CEA to AEGT ooo ALASKA INTERTIE ENERGY USAGE REPORT (MWh) AEGT to GVEA 0 0 0 BL to GVEA 0 0 0 INTERTIE MIDPOINT GVEA to AMLP 0 0 0 GVEA to CEA 0 oO oO GVEA to AEGT ° oo ALASKA INTERTIE SCHEDULED RESERVES REPORT (MWh) AEGT to GVEA 0 0 0 BL to GVEA 0 0 0 INTERTIE MIDPOINT GVEA to AMLP 0 0 0 GVEA to CEA ooo GVEA to AEGT 0 0 0 AIDEA to AEGT oo ° AIDEA AEGT ooo AIDEA to AMLP 0 Oo 0 AIDEA AMLP ooo AIDEA to MONTHLY CEA TOTALS 0 21866 0 10793 0 12543 coo0cc0oCcce 0 45202 AIDEA to MONTHLY CEA TOTALS 0 0 0 coco oCoCCOOCCoOD 10/13/99 11:28 AN: GVEA RECEIPTS 21020 9949 11705 ALASKA INTERTIE ENERGY RECEIPTS (MWh) CEA RECEIPTS 0 0 0 AMLP RECEIPTS 0 0 0 AEGT RECEIPTS 846 844 838 TOTAL RECEIPTS 21866 10793 12543 ooooo0oo0oo°0c°o 10/13/99 11:28 AM FYOO MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE 42674 GVEA RECEIPTS oO 0 0 ALASKA INTERTIE SCHEDULED RESERVES REPORT (MWH) CEA RECEIPTS 0 0 0 AMLP RECEIPTS 0 0 0 2528 AEGT RECEIPTS 0 0 0 45202 TOTAL RECEIPTS 0 0 0 YEAR TOTAL FYOO MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YEAR TOTAL F BEATY & DRAEGER, LTD. ATTORNEYS AT LAW 3900 ARCTIC BLVD., SUITE 101 ANCHORAGE, ALASKA 99503 EGEIVE) OCT 04 1999 Wy Alaska Industrial Development and Export Authority ROGER H. BEATY TERRY P. DRAEGER Friday, October 01, 1999 Stan Sieczkowski, Operations Mgr. AIDEA 480 W. Tudor Rd. Anchorage, AK 99503 Re: City of Larsen Bay Dear Stan: Pursuant to your request, enclosed are the following: i Pro forma cash flow for utility operation for the year 2000; Zi. Draft of Operation/Maintenance Agreement. TEL. (907) 563-7889 FAx (907) 562-6936 Based upon the aforementioned information, it is anticipated that cash flow from operations ($60,000) will be sufficient to cover the expenses associated with the operation/maintenance agreement. The only participation the city may expect from the state is input in the form of either technical advice and/or funds to get the hydro project to operational standards. Since the hydro project is an asset of the state, the city will want the state's input and assistance to bring the hydro project up to operational status before the city takes over operations and maintenance. If you have any questions, please contact me. Sincerely, “Mone. LTD. P. Draeger, TPD/dah Enclousres Larsen Bay/99L10 AIDEA cc: City of Larsen Bay Percy Frisby, Div of Energy CITY OF LARSEN BAY ELECTRIC UTILITY OPTION REVENUES: Customers 134,000 PCE Credits 75,000 Kodiak Salmon Packers 20,000 TOTAL REVENUES 229,000 EXPENSES: Diesel: Payroll 14,622 Fuel 35,000 Miscellaneous D225 Reserves 22,627 Total Expenses Diesel 74,974 Hydro: Payroll 14,525 APA payments 35,000 Kodiak installation 11,340 Reserves 9.000 Overhead insurance 14,000 Miscellaneous 3,887 Total Expenses Hydro 87,752 TOTAL EXPENSES 162,726 NET INCOME FROM OPERATION 66,274 LARSEN BAY ELECTRIC UTILITY MASTER MAINTENANCE & OPERATING AGREEMENT THIS AGREEMENT is entered into on this day of , 1999 by and between the City of Larsen Bay, an incorporated second class city (hereinafter "the City) and ,an (hereinafter " as WHEREAS, the City is the owner of the Larsen Bay Utility Company (hereinafter "LBUC"); and, WHEREAS, the LBUC supplies electricity to the community; and, WHEREAS, the LBUC owns the diesel generating plant and distribution system which generates and distributes electricity to the City; and, WHEREAS, the Department of Community and Regional Affairs (hereinafter "DCRA") owns the hydroelectric project which also supplies electricity to the distribution system; and, WHEREAS, the City, through the LBUC, has agreed to operate and maintain the hydroelectric project for DCRA; and, WHEREAS, is in a position as an to provide support to the LBUC. NOW, THEREFORE, the parties agree, covenant, and warrant as follows: di: Maintenance and Operation. agrees to provide maintenance and operation support (as more fully set forth in this Agreement) and the City agrees to pay for said services. 2) Services. agrees to provide the services as set forth in Exhibit A. 3) Service Fees. The cost of the services provided by will be as follows: LABOR COSTS Management: $ /hr Costs to be billed at actual Skilled: $ /hr plus 15% markup Administrative SUL hr: 4. Payment. The City agrees to pay for services performed within thirty (30) days of the invoice date. ED! Term. shall start performing services beginning September 1, 1999 and continue said services for a period of one year until August 31, 2000. So long as it is not in default under this Agreement, may, at its sole discretion, extend the term of this Agreement for an additional one-year period by giving the City written notice by June 15, 2000. 6. Binding Effect. All rights, duties, and liabilities herein given to or imposed upon the respective parties hereto extend to and bind the several respective heirs, executors, administrators, successors, and assignees of the said parties. 7. Partial Invalidity. If any term, covenant, or condition of this Agreement or the application thereof to any person or circumstances, shall, to any extent, be invalid or unenforceable, the remainder of this Agreement for the application of such term, covenant or condition of this Agreement shall be valid and be enforced to the fullest extent permitted by law. 8. Waiver. The waiver by either party or breach of any term, covenant, or condition herein contained shall not be deemed to be a continuing waiver of any subsequent waiver or breach of any term, covenant or condition. 9; Entire Agreement. This Agreement and the exhibits attached hereto forming a part hereof set forth all covenants, promises, agreements, conditions, and understandings between either party concerning the Agreement and there are no other covenants, promises, agreements, conditions, or understandings either oral or written between them other than herein set forth. Except as herein otherwise provided, no subsequent alteration, amendment, change, or addition to the Agreement shall be binding upon either party unless reduced to writing and signed by them. 10. Governing Law. This Agreement shall be governed by the law of the State of Alaska and any dispute hereunder adjudicated in the Third Judicial District, State of Alaska. Le Rule of Construction. Each party to this Agreement has had ample opportunity to have this Agreement reviewed by counsel of their own choosing. This Agreement and any related documents shall not be construed against the interests of the drafting party as a result of its preparation or approval of the documents. 12; Counterparts. This Agreement may be executed in separate counterparts, each of which so executed and delivered shall constitute an original, but all such counterparts shall together constitute one and the same instrument. Any such counterpart may comprise one or more duplicates or duplicate signature pages any of which may be executed by less than all of the parties, provided that each party executes at least one such duplicate or duplicate signature page. The parties stipulate that a photostatic copy of an executed original will be admissible in evidence for all purposes in any proceeding as between the parties. IN WITNESS WHEREOF, the parties have executed this Agreement this day of PL Ou THE CITY OF LARSEN BAY By: Its: Mayor STATE OF ALASKA ) THIRD JUDICIAL DISTRICT ) On this day of, 1999, before me, a notary public in and for the State of Alaska, personally appeared ALLAN PANAMAROFF, known to me to be the mayor of the CITY OF LARSEN BAY, the corporation that executed the within instrument, and acknowledged to me that such corporation executed the same. IN WITNESS WHEREOF, I have hereunto set my hand and seal the day and year last above written. Notary Public in and for Alaska My commission expires: STATE OF ALASKA ) ) ss. THIRD JUDICIAL DISTRICT ) THIS IS TO CERTIFY that on this day of , 1999, before me, a Notary Public in and for the State of Alaska, duly commissioned and sworn as such, personally appeared ; known to me to be the of , the corporation named in the foregoing instrument, and who acknowledged to me that the foregoing document was executed on behalf of said corporation for the uses and purposes therein mentioned, by authority of its board of directors. IN WITNESS WHEREOF, I have hereunto set my hand and seal the day and year last above written. Notary Public in and for Alaska My commission expires: 10-J16LH STAVE OF ALASWA —/ swrsmoms comme DEPARTMENT OF NATURAL RESOURCES DIVISION OF LAND 3601 C STREET, SUITE 1080 SOUTHCENTRAL REGION ANCHORAGE, ALASKA 99503-5937 (907) 269-8542 gi : (fe A July 6, 1998 ECG? PE | ae J Alaska Energy Authority JUL 07 1998 480 West Tudor Road Alaska industrial Development Anchorage, AK 99503 and Export Authority Attention: Stan Sieczkowski Operations & Maintenance Manager RE: Land Use Permit LAS 22027 Enclosed are two copies of the pending permit for cross country travel activities on state land in the upper Lane Creek area. Please read the permit and stipulations and let me know if you have any questions. Please sign both copies of the permit on page 4 and return them to this office for the approving signature. Please note that access across other lands may require permits from the appropriate property owners. There are two parcels along the route (ASLS 76-77 and 76-78) located nearer the intertie patented to private individuals which may or may not be on your travel route. It is difficult to tell on the maps if the trail crosses the property. This may be something to watch for when on the ground. Copies of the surveys are enclosed. Matanuska-Susitna Borough tax records would reflect the most current ownership under these ASLS numbers. Once the signed permit copies are returned, the permit will be approved and copies will be sent to you and to Locher Interests, Inc. Do not hesitate to call me if you have any questions at (907)269-8567. Sincerely, Carse Cong ho Carol A. Compton ‘ Natural Resource Officer Enclosure: Permit copies (2) cc: Locher Interests, Ltd. w/permit copy Jim Thrall 406 W Fireweed, Suite 101 Anchorage, AK 99503 ‘} printed on recycled paper b y C.D STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF LAND [ ] Northern Region [x] Southcentral Region [ ] Southeast Region 3700 Airport Way 3601 C Street, Suite 1080 400 Willoughby, #400 Fairbanks, AK 99709 Anchorage, AK 99503-5937 Juneau, AK 99801 (907) 451-2705 (907) 269-8542 (907) 465-3400 1998 LAND USE PERMIT AS 38.05.850 PERMIT # _LAS 22027 ALASKA ENERGY AUTHORITY (AEA), 480 West Tudor Road, Anchorage, AK 99503, hereinafter referred to as Permittee is issued this permit authorizing travel on state-owned land over existing trails with one Nodwell with mounted drill rig. Access is within: Sections 3,4,7,8,9,10,17,18,19 & 20, Township 29 North, Range 3 West, Seward Meridian Sections 10,11,12,13,14,&15, Township 29 North, Range 4 West, Seward Meridian Sections 26,27,28,33,&34, Township 30 North, Range 3 West, Seward Meridian Travel on state owned land is specifically limited to the route(s) identified on Attachment A. Any changes in the access route(s) must be pre-approved. Cross-country travel off established trails must be pre-approved. The effective term of this permit begins July 1, 1998 and ends on October 31, 1998. This permit is not a property right. It is a temporary authorization, revocable by the State with or without cause. No preference right for long term use of the land is granted or implied by the issuance of this permit. The Authorized Officer for the Department of Natural Resources is the Southcentral Regional Manager, Division of Land. The Authorized Officer may designate a representative for administration of specific portions of this authorization. The Authorized. Officer reserves the right to modify these or use additional stipulations as deemed necessary. This permit is issued subject to Permittee’s acceptance of and compliance with the following stipulations and applicable conditions set forth in 11 AAC 96.140. Failure to comply with the terms and conditions set forth herein shall constitute a breach of permit conditions and may subject the permit to suspension or termination. 1. Stipulation Compliance. Permittee shall inform and ensure compliance with these stipulations by his agents, contractors and subcontractors, employees and guests. 2. Permittee will conduct all activities in compliance with all applicable federal, state and local laws. This authorization does not preclude the acquisition of other necessary federal, state or local permits. 3. Indemnification. Permittee assumes all responsibility, risk and liability for all activities of the permittee, its employees, agents, guests, contractors, subcontractors or licensees directly or indirectly conducted in conjunction with this permit, including environmental and hazardous substance risks and liabilities, whether occurring during or after the term of this permit. Permittee shall defend, indemnify and hold harmless the State of Alaska, its employees and agents from and against any and all suits, claims, actions, losses, costs, penalties and damages of whatever kind of nature including all attorney fees and litigation costs, arising out of, in connection with or incident to any act or omission by Permittee, its employees, agents, guests, contractors, subcontractors or licensees unless the sole proximate cause of the injury or damage is the negligence or willful misconduct of the State or anyone acting on the State’s behalf. Within 15 days, Permittee shall accept any such cause or action or proceeding upon tender by the State. This indemnification shall survive the expiration or termination of this Land Use Permit LAS 22027 Permittee: Alaska Energy Authority Page 2 permit. 4. Permittee shall not close landing areas or trails. The ability of all users to access state land or public water must 10. 1H: 12; 13; 14. 1S: not be restricted in any manner. Existing roads and trails shall be used. This permit does not authorize the construction or establishment of pioneer trails or any other type of permanent travel route. Cutting, or disturbance of trees is prohibited. Movement through willow (salix) shall be avoided whenever possible. Vehicles shall be operated in a manner such that the vegetative mat is not disturbed. Blading or removal of vegetative cover is prohibited. Streambanks shall not be altered to facilitate crossings or disturbed in any way. Streambanks inadvertently disturbed, shall be immediately stabilized to prevent erosion. Stabilization shall include re-vegetation to be accomplished during the following growing season if necessary . Vehicle maintenance, storage or stockpiling of material on state land or water is not allowed under this permit. No fuel storage facilities are allowed on state land. No fuel transfer activities will occur within 100 feet of any waterbody. Absorbent pads and materials shall be kept on hand and used to intercept and collect any leakage from equipment during fueling, servicing or transporting. Spill Notification. (A) Permittee shall immediately notify the Department of Natural Resources (DNR) and the Department of Environmental Conservation (DEC) by telephone of any unauthorized discharge of oil to water, any discharge of hazardous substances (other than oil); and, any discharge of oil greater than 55 gallons on land. (B) All fires and explosions must be reported. The DNR 24 hour spill report number is (907) 451-2678; the FAX number is (907) 451-2751. DNR and DEC shall be supplied with all follow-up incident reports. The DEC spill report number is (800) 478-9300. Hazardous materials, petroleum or petroleum products as defined in state and federal regulations shall be disposed of at a DEC approved facility. Debris (such as soil) contaminated with used motor oil, solvents, or other chemicals may be classified as a hazardous substance and must be used, stored and disposed of in accordance with state and federal law. All waste generated during the course of this project shall be collected, containerized and stored so as not to attract wildlife. All solid waste and foreign debris generated by the Permittee and its agents shall be removed upon completion of the project in accordance with federal and state law. Waste, in this paragraph means all discarded matter, including but not limited to, human waste, trash, garbage, litter, oil drums, petroleum, ashes and discarded equipment. Abandonment of supplies, fuel containers, or equipment associated with this project is prohibited. Permittee shall take all reasonable precautions to prevent, and all reasonable actions to suppress forest, brush, and grass fires. With issuance of this permit, the Department of Natural Resources does not assume responsibility for protecting personal property in cases of grass, brush, or forest fires. Land Use Permit LAS 22027 Permittee: Alaska Energy Authority Page 3 16. 17. 18. 19. 20. 21. 22. 23. The Alaska Historic Preservation Act (AS 41.35.200) prohibits the appropriation, excavation, removal, injury, or destruction of any state-owned historic, prehistoric (paleontological) or archaeological site without a permit from the commissioner. Should any sites be discovered during the course of field operations, activities that may damage the site will cease and the Office of History and Archaeology in the Division of Parks and Outdoor Recreation (907) 269-8715/8720 and the appropriate coastal district (Matanuska-Susitna Borough) shall be notified immediately. Representatives and personnel of interested State agencies may inspect the activities of the Permittee at any time. Non-compliance determinations will subject the permitted areas to re-inspection of which the Permittee may be assessed, at the Director’s discretion either a fee of $100 or a fee equal to the actual expenses incurred by the Division of Land (11 AAC 05.010). Site Rehabilitation. In the event any portion of the route is damaged by the activities authorized under this permit, Permittee will rehabilitate the damaged area(s) to the satisfaction of the Authorized Officer. Permittee is responsible for the costs associated with site restoration. Completion Report. A completion report shall be submitted to DNR within 30 days after the expiration of the permit. The report will include: actual dates of travel, any complications that occurred along the authorized route, solid waste management, fuel and hazardous substance spills and their remedies, and any damage to the vegetative mat or streambanks and associated restoration before and after photographs of the permitted activities including photos of all stream crossings, and any inadvertent disturbances to the vegetative mat, spills, or other complications resultant of the permitted activities. Performance Guarantee. The State reserves the right to require a Performance Guarantee during the term of this authorization. The Guarantee assures the Permittee’s compliance with terms and conditions of the authorization. The Guarantee may be utilized by the Division of Land to cover actual costs incurred by the State of Alaska to pay for any necessary corrective action(s) in the event the Permittee does not comply with site utilization and restoration guidelines. Valid Existing Rights. This authorization is subject to all valid existing rights in and to the land covered under this permit. The State of Alaska makes no representations or warranties, whatsoever, either expressed or implied, as the to the existence, number or nature of such valid existing rights. Reservation of Rights. (A) The Division reserves the right to grant additional authorizations to third parties for compatible uses on or adjacent to the land covered under this authorization. Permittee shall not interfere with authorized concurrent users of state land, their agents, employees, contractors, subcontractors and licensees. Violations. This authorization is revocable immediately upon violation of any of its terms, conditions, stipulations or upon failure to comply with any state, federal or local laws, statutes and regulations. Should any unlawful discharge, leakage, spillage, emission or pollution of any type due to permittee’s or its employees, agents, contractors, subcontractors, licensees or guest act or omission, the Permittee, at its expense, shall be obligated to clean the area to the reasonable satisfaction of the State of Alaska. Land Use Permit LAS 22027 Permittee: Alaska Energy Authority Page 4 The Authorized Officer reserves the right to modify or attach additional stipulations before and after this permit is issued. The Permittee will be advised of any such modifications or additions. Where these stipulations differ from those set forth in 11 AAC 96.140, these Special Stipulations will take precedence. DNR has the authority to implement and enforce these stipulations under AS 38.05.850. This permit is not transferable and cannot be assigned or subleased, in whole or in part, to another party. It is issued to authorize specific activities requested by the permittee which are not included in the category of "generally permitted (allowed) uses" (11 AAC 96.010 - .020). Correspondence regarding this permit should be directed to the Department of Natural Resources, Southcentral Regional Office, Upland Services Section, 3601 C Street, Suite 1080, Anchorage, AK 99503-5937, telephone (907) 269-8542. I have read each of the foregoing stipulations, understand and agree to comply with all stipulations and conditions included within this-year permit. Signature of Permittee Date 480 West Tudor Road Anchorage AK 99503 Permittee's Address City State Zip (907) 269-3000 Stan Sieczkowski , Operations & Maintenance Manager (AEA) Contact Person 907) 258-2200 Jim Thrall , Locher Interests, Ltd Contact Person NRMI Signature of Authorized Officer Title Date 1 J FAIRBANKS 184 MI. R11W_ ‘4 summiT 30 mi. 30° R10 Ww aseet Y) Yee = KEG ee: oo} LAND USE PERMIT LAS 22027 Location & Plat Maps (fewer se KG y #4 T3IN 545 g a i! “Mn u No 3 Zz Vv i at SS N ) AGS IN NRA NEN j : R es SV = B Yk = a \P by I Gel N - | , NEI Maw < a z . , NY: 3 x \ SS 2 Xv 8k WIRY : VR ee (NAR eT - s . : \ <A AC ie XN xn Tee at. . ‘Ss AN me 4 . * a : KA PVs i b V AY SRY wha” r S SHC (0 “IN e ea é ~ aN g2N LOD Er) i XAG, 4 7 S YY A \ = A\ SAY D): N he eS, e SS —f _ oe ' ‘ y Bry SY Yea 4 SSR Rees | Ps ie : FR) 5, idles \ ) i * KDI \? LEGEND INFORMATION HYDROGRAPHY, SURVEY LINE SURVEY LOT LINE TOWNSHIYSECTION GRID WA SECTION LINE HWA ROAD TRAM. RAI ROAD HLECTRICAL POWER LINE TELEPHONE LINE POFLINE, AIRFORTILANDING STRIP HORIZONTAL CONTROL CONTROL MONUMENT: me DOUNDARY CLASSINICATION DISPOSAL, MUNICIPAL RESTRICTION VeDERAL ACTION MENTAL HEALTH TRUST LIMITS OF ACTION NAVIGATIONAL AID. CABIN PERMIT ‘TRAPPING CABIN PERMIT ‘TRESPASS LOCATION DAM WEIR, BARRIER @s0 ABPLICATION reas CERTICATES TOWNSHIP 29N RANGE 4W OF THE SEWARD MERIDIAN, ALASKA TR ANTATARD gquapinae AN INDEX OF STATUS PLAT ABBREVIATIONS {5 INCLUDED WITH FAC APERTURE CARD. SET OF STATE STATUS PLATS. STATUS PLAT RAR LIRCTRATION OM (mF AK UMTS REMADN TH THE STATE OWNS ALL. LAND UNDER WATERS THAT ARE NAN W-PACT. ARE SUBILCT TO THE BAR AND FLOW OF THE Tin ARE PIPARIAN OR LITTORAL TU UPLANDS OWNED ®Y THE ST! MSD ON: (Coonpwares, ALASKA STATE. PLANE ZOWE 4 SE CORNER OF TOWNSHE: x $18453 947 Y 31382789 ur 63s He TONG 14038 15028 W inpauceapuy. USGS TALKEBTNA (Cl) AND TALKEDTNA MOUNTAINS («6 BY BUM FROM AERIAL HIGH ALITTUDE. PHOTOGRAPH tn wer LM PROTRACTION DUACRAM S2-% APPROVED 11/14/1009 UGS TRACT A_ 183602) ACRES TRACT BLOT 1, M1 #0 ACRES. TRACT B LOT 2 23.98 ACRES ACCEPTED (VEE197: ADIUSTED ACREAGE TRACT A TO 17.4742 ACRES: O12WIT8 AMS a10103: FLED 111983 ASUS AIONIT, BILD 0827/1983 ASLS ASUI7L: STUD OYINIIE7 ‘ASLS BBOITT: RECORDED (AWN ASLS Na26: RECORDED 107001992 ASLS Boi, RECORDED 01/19/1993 ASLS 910228: RECORDED 31/1993 UTHER ACTIONS AFFECTING OSSPOSAL OR USE OF STATE LAN SEE THE LAS CASES ILE OR ORIGINAL SOURCE DOCUMENTS 4 ADOITIONAL INFORMATION: PXTIRPLY WAN TALKEETNA RECORDING DISTIUCT ENTIRELY WAN MATANUSKA- SUSITNA BOROUGH SURJECT TO SUSITNA AREA PLAN GS 1466, TENTATIVE APPROVAL EXCLUDES SUSITNA RIVER ATTENTION STATUS PLAT USERS: ON 1005 PLAT, LINPS CLOSE FOR ACTIONS THAT EXTEND INTO ADIACENT 11 TMS (NCIUTES STATUS LINES SUCH AS DISPOSAL, MUNI PAL CLASSIICALLUN, ETC, PLEASE RITTR TO ADIACENT TOWNS TO DETERMINE IF ACTIONS EXTIND REYOND THE ROUNDARI! FMS PLAT. REMEMNER TITLE, CLASSINCATNION, AND RISTRK ALWAYS CLOSE ON ALL PLATS. Li A PRODUCT OF 110: STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES LAND RFCORDS (4ORMATION SICTION PLAT CURRENT TO 11/1,V1997, REFER TO ONR'S STATUS PLAT TRACKING SYSTEM (NMCVNTS2) TOR OTHER PENDING ACTIONS ON THOS TOWNSHIPA AT. PORTER IorET ate ee wee we pee were WHEN ty Ne Vintives pees CURES LLUSRATION OH, SOURCE DOCUMENTS Ar Maan ME OFCOM, MECORD LEGEND ass on BASE_INFORMATION. Gee tam mae soe « Fla ———— ‘STREAM 7 soketser an ame warempcoy tone 08 S750" ‘uRVEY MORO Afr TES /RAETMA MUTANS (08) EHOTO REGED PRO ACL _ _ eaten Ge mo ATE OTOORAMT - eas 8 lomacan eww 55 srooee SECONDARY ROAD Sieg Mees se-semh AOR OPCW ta Booman mr LAS 1S ROD my? Pi a a povemy amet ak AD Ce PARROND RECT pw Ue TELHOE UNE ree WORT CONTROL ae ] LTS OF ACTION ——— ARPORTS OR a = UXONS STRES STATUS INFORMATION FEDERAL ACTIONS. REMOTE CABN PRAT TRAPPING CABN PERAT C PER FROM TRESPASS TRESPASS: ROO, AUK ROMO, PER * Growo, CERT Orv SURFACE, APL OV SURFACE, PER Orv SURFACE, CORT RESERVED, APLN RESERVED, CERT OV ISTALLATION, APL Drv ESTALLATION, PER Div INSTALLATION, CERT OMER Acrons 4/TEE me ces On uae Sie ee ‘port 0 wera mee Derma? Ur Taser Ine MECORO O8 TACT ‘Samat? 7S sayin AMA Paw ° ° ® x ° @ e o 3 s 4 a ° ® e _SECTION NUMBERING ow Sp2zyet w)n}e Bsivis seral 4 22) 23) wv) we) M4] 3S | 6 ‘SCALE ‘A PRODUCT OF THE SS 4 STATE OF AL#SKA 249 890 $00.0 woe 2000 sie / (mmm A ht men = tt ot ( DEPARTUENT OF NATURAL RESOURCES, sp ' y “ 20 % +“ — DivnON OF WANA SEMENT - : SS en | TWP Z0N AUTOMATED DRAFTING SYSTEM RNG 3W = | SM gyi, ‘STAC aM oy wATLEBODY —_—_— suv = ass ‘SECTION Ue =a em ‘wAsoR ROAD ‘SECONDARY ROAD Teay a Bovoany te RALROAD — ALECT PWR Une es TELEPHONE, UNE ry peee a. Home CONTROL {. 1 Lats OF ACTION == ws _STATUS_NFORMATION me CLASSIFICATION DsPOsAL Munc rat, RESTRIC TONS FEDERAL ACTIONS, PrVOTe CARN PERT ° r) TRAPPNG CABN PERUT e € PER FROM TRESPASS x TRESPASS ° cove, aN 8 CROUO, PER e CACO, CERT o Dv SURFACE, APLW S s a a ° @ e Dev SURFACE. PER Drv SURFACE, CERT RESERVED, APLN RESERVED, CERT OW FSTALLATION, APL Orv WESTALLATION, PER Orv MESTALLATION, CERT TOWNSHIP 30N RANGE 3W OF THE SEWARD MERIDIAN, ALASKA __ STATUS PLAT __ NE SIFU ET UAT NENTS stu Oe OOM MOO MNCEO PUD 04/23, 82 255 soul icone tum 0 Tati ow OPER ACES AITECING OSROSA 0 WOE & Stat (ees COREL) WATANIBEA SUSI BOROUON COMET AIM TREE ECR OS TRET ‘Siaacl 16 seven ama Maw AST 213083 Fry STRUCTURE A PRODUCT OF THE Sone ne ( paren eros teresa || es _— i Cree OF WANACEMENT t AUTOMATED DRAFTING SYSTEM STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF LAND [ ] Northern Region [x] Southcentral Region [ ] Southeast Region 3700 Airport Way 3601 C Street, Suite 1080 400 Willoughby, #400 Fairbanks, AK 99709 Anchorage, AK 99503-5937 Juneau, AK 99801 (907) 451-2705 (907) 269-8542 (907) 465-3400 1998 LAND USE PERMIT AS 38.05.850 PERMIT # _LAS 22027 ALASKA ENERGY AUTHORITY (AEA), 480 West Tudor Road, Anchorage, AK 99503, hereinafter referred to as Permittee is issued this permit authorizing travel on state-owned land over existing trails with one Nodwell with mounted drill rig. Access is within: Sections 3,4,7,8,9,10,17,18,19 & 20, Township 29 North, Range 3 West, Seward Meridian Sections 10,11,12,13,14,&15, Township 29 North, Range 4 West, Seward Meridian Sections 26,27,28,33,&34, Township 30 North, Range 3 West, Seward Meridian Travel on state owned land is specifically limited to the route(s) identified on Attachment A. Any changes in the access route(s) must be pre-approved. Cross-country travel off established trails must be pre-approved. The effective term of this permit begins July 1, 1998 and ends on October 31, 1998. This permit is not a property right. It is a temporary authorization, revocable by the State with or without cause. No preference right for long term use of the land is granted or implied by the issuance of this permit. The Authorized Officer for the Department of Natural Resources is the Southcentral Regional Manager, Division of Land. The Authorized Officer may designate a representative for administration of specific portions of this authorization. The Authorized. Officer reserves the right to modify these or use additional stipulations as deemed necessary. This permit is issued subject to Permittee’s acceptance of and compliance with the following stipulations and applicable conditions set forth in 11 AAC 96.140. Failure to comply with the terms and conditions set forth herein shall constitute a breach of permit conditions and may subject the permit to suspension or termination. 1. Stipulation Compliance. Permittee shall inform and ensure compliance with these stipulations by his agents, contractors and subcontractors, employees and guests. 2. Permittee will conduct all activities in compliance with all applicable federal, state and local laws. This authorization does not preclude the acquisition of other necessary federal, state or local permits. 3. Indemnification. Permittee assumes all responsibility, risk and liability for all activities of the permittee, its employees, agents, guests, contractors, subcontractors or licensees directly or indirectly conducted in conjunction with this permit, including environmental and hazardous substance risks and liabilities, whether occurring during or after the term of this permit. Permittee shall defend, indemnify and hold harmless the State of Alaska, its employees and agents from and against any and all suits, claims, actions, losses, costs, penalties and damages of whatever kind of nature including all attorney fees and litigation costs, arising out of, in connection with or incident to any act or omission by Permittee, its employees, agents, guests, contractors, subcontractors or licensees unless the sole proximate cause of the injury or damage is the negligence or willful misconduct of the State or anyone acting on the State’s behalf. Within 15 days, Permittee shall accept any such cause or action or proceeding upon tender by the State. This indemnification shall survive the expiration or termination of this Land Use Permit LAS 22027 Permittee: Alaska Energy Authority Page 2 permit. 4. Permittee shall not close landing areas or trails. The ability of all users to access state land or public water must 10. 11. 12. 13. 14. 15. not be restricted in any manner. Existing roads and trails shall be used. This permit does not authorize the construction or establishment of pioneer trails or any other type of permanent travel route. Cutting, or disturbance of trees is prohibited. Movement through willow (salix) shall be avoided whenever possible. Vehicles shall be operated in a manner such that the vegetative mat is not disturbed. Blading or removal of vegetative cover is prohibited. Streambanks shall not be altered to facilitate crossings or disturbed in any way. Streambanks inadvertently disturbed, shall be immediately stabilized to prevent erosion. Stabilization shall include re-vegetation to be accomplished during the following growing season if necessary . Vehicle maintenance, storage or stockpiling of material on state land or water is not allowed under this permit. No fuel storage facilities are allowed on state land. No fuel transfer activities will occur within 100 feet of any waterbody. Absorbent pads and materials shall be kept on hand and used to intercept and collect any leakage from equipment during fueling, servicing or transporting. Spill Notification. (A) Permittee shall immediately notify the Department of Natural Resources (DNR) and the Department of Environmental Conservation (DEC) by telephone of any unauthorized discharge of oil to water, any discharge of hazardous substances (other than oil); and, any discharge of oil greater than 55 gallons on land. (B) All fires and explosions must be reported. The DNR 24 hour spill report number is (907) 451-2678; the FAX number is (907) 451-2751. DNR and DEC shall be supplied with all follow-up incident reports. The DEC spill report number is (800) 478-9300. Hazardous materials, petroleum or petroleum products as defined in state and federal regulations shall be disposed of at a DEC approved facility. Debris (such as soil) contaminated with used motor oil, solvents, or other chemicals may be classified as a hazardous substance and must be used, stored and disposed of in accordance with state and federal law. All waste generated during the course of this project shall be collected, containerized and stored so as not to attract wildlife. All solid waste and foreign debris generated by the Permittee and its agents shall be removed upon completion of the project in accordance with federal and state law. Waste, in this paragraph means all discarded matter, including but not limited to, human waste, trash, garbage, litter, oil drums, petroleum, ashes and discarded equipment. Abandonment of supplies, fuel containers, or equipment associated with this project is prohibited. Permittee shall take all reasonable precautions to prevent, and all reasonable actions to suppress forest, brush, and grass fires. With issuance of this permit, the Department of Natural Resources does not assume responsibility for protecting personal property in cases of grass, brush, or forest fires. Land Use Permit LAS 22027 Permittee: Alaska Energy Authority Page 3 16. 17. 18. 19. 20. 21. 22; 235 The Alaska Historic Preservation Act (AS 41.35.200) prohibits the appropriation, excavation, removal, injury, or destruction of any state-owned historic, prehistoric (paleontological) or archaeological site without a permit from the commissioner. Should any sites be discovered during the course of field operations, activities that may damage the site will cease and the Office of History and Archaeology in the Division of Parks and Outdoor Recreation (907) 269-8715/8720 and the appropriate coastal district (Matanuska-Susitna Borough) shall be notified immediately. Representatives and personnel of interested State agencies may inspect the activities of the Permittee at any time. Non-compliance determinations will subject the permitted areas to re-inspection of which the Permittee may be assessed, at the Director’s discretion either a fee of $100 or a fee equal to the actual expenses incurred by the Division of Land (11 AAC 05.010). Site Rehabilitation. In the event any portion of the route is damaged by the activities authorized under this permit, Permittee will rehabilitate the damaged area(s) to the satisfaction of the Authorized Officer. Permittee is responsible for the costs associated with site restoration. Completion Report. A completion report shall be submitted to DNR within 30 days after the expiration of the permit. The report will include: e actual dates of travel, e any complications that occurred along the authorized route, ¢ solid waste management, e fuel and hazardous substance spills and their remedies, and e any damage to the vegetative mat or streambanks and associated restoration e before and after photographs of the permitted activities including photos of all stream crossings, and any inadvertent disturbances to the vegetative mat, spills, or other complications resultant of the permitted activities. Performance Guarantee. The State reserves the right to require a Performance Guarantee during the term of this authorization. The Guarantee assures the Permittee’s compliance with terms and conditions of the authorization. The Guarantee may be utilized by the Division of Land to cover actual costs incurred by the State of Alaska to pay for any necessary corrective action(s) in the event the Permittee does not comply with site utilization and restoration guidelines. Valid Existing Rights. This authorization is subject to all valid existing rights in and to the land covered under this permit. The State of Alaska makes no representations or warranties, whatsoever, either expressed or implied, as the to the existence, number or nature of such valid existing rights. Reservation of Rights. (A) The Division reserves the right to grant additional authorizations to third parties for compatible uses on or adjacent to the land covered under this authorization. Permittee shall not interfere with authorized concurrent users of state land, their agents, employees, contractors, subcontractors and licensees. Violations. This authorization is revocable immediately upon violation of any of its terms, conditions, stipulations or upon failure to comply with any state, federal or local laws, statutes and regulations. Should any unlawful discharge, leakage, spillage, emission or pollution of any type due to permittee’s or its employees, agents, contractors, subcontractors, licensees or guest act or omission, the Permittee, at its expense, shall be obligated to clean the area to the reasonable satisfaction of the State of Alaska. Land Use Permit LAS 22027 Permittee: Alaska Energy Authority Page 4 The Authorized Officer reserves the right to modify or attach additional stipulations before and after this permit is issued. The Permittee will be advised of any such modifications or additions. Where these stipulations differ from those set forth in 11 AAC 96.140, these Special Stipulations will take precedence. DNR has the authority to implement and enforce these stipulations under AS 38.05.850. This permit is not transferable and cannot be assigned or subleased, in whole or in part, to another party. It is issued to authorize specific activities requested by the permittee which are not included in the category of "generally permitted (allowed) uses" (11 AAC 96.010 - .020). Correspondence regarding this permit should be directed to the Department of Natural Resources, Southcentral Regional Office, Upland Services Section, 3601 C Street, Suite 1080, Anchorage, AK 99503-5937, telephone (907) 269-8542. I have read each of the foregoing stipulations, understand and agree to comply with all stipulations and conditions included within this-year permit. Signature of Permittee Date 480 West Tudor Road Anchorage AK 99503 Permittee's Address City State Zip (907) 269-3000 Stan Sieczkowski , Operations & Maintenance Manager (AEA) Contact Person 907) 258-2200 Jim Thrall , Locher Interests, Ltd Contact Person NRMI Signature of Authorized Officer Title Date LAND USE PERMIT LAS 22027 Location & Plat Maps Attachment A 4 3 200 000 FEET (ZONE 3) (i ANCHORAGE 152 Mi. 2 = a WILLOW 83 Mi. RW Fpl een ” Rh _D \(CSe / . \( G2 Cf } He m i) ce ‘ FAIRBANKS 184 MI. SUMMIT 30 MI. 30° R10 W Laer ne \ INEORMATION + DEK nrocraniy ——— survey un: a SURVEY Lor LINE: > —— = Towsinsicrion Gen . = VE SECTION LINE, ee CHWAY, re ROAD meeenene- ‘TRAN. i+ RAMROAD pe 2 LICTRICAL POWER LINE ts THLePnone une HS PEUINE, AIRFORTILANDING STRIP a HORIZONTAL CONTROL © CONTROL MONUMENT STATUS INFORMATION me +s nounpaRY '—— + cAssincaTion °———— DISPOSAL We urcra + RESTRICTION *—-—— WDeRAL ACTION MENTAL HEALTH TRUST LIMITS OF ACTION 4& NAVIGATIONAL AID ° CABIN PERMIT o x ‘TRAPPING CABIN PERMIT TRESPASS LOCATION ASUREACE_ WATER RIGHTS. e@30 TOWNSHIP 29N RANGE 4W OF THE SEWARD MERIDIAN, STATUS PLAT CRA LUSTRATION UNC, SOURCE DUC TMONTS REMADE TIE: 14 TR AANTATARS THE STATE OWNS ALI. LAND UNDER WATERS THAT ARE NAV W- PACT, ARE SURJLCT TO THE PRB AND FLOW OF THE 1: ARE PIPARIAN OR LITTORAL TU UPLANDS OWNED 8Y THE ST ASED OW: (COORDINATES: ALASKA STATE. PLANE ZONE 4 SE CORNER OF TUWNSHIP: x Stsass 947 Y yissimo ur ay NEN ONG 14038 18028 w mnpaoceapay. USGS TALKERTNA (Cl) AND TALKELTNA MOUNTAINS (« BY BUM FROM APRIAL HIGH ALITTUDE PHUTOGRAPH) Un wer: BLM PROTRACTION DUACRAM S2-% APPROVED 11/14/19 URS TRACT A. !43602) ACRES TRACT BLOT 1, 1 #0 ACRES. TRACT BLOT 2 25.98 ACRES. ACCLETID VE197K: ADJUSTED ACREAGE TRACT A TO 17,474.23 / yy Ste BEC 4 ‘ " ASLS 910225: RECORDED wW31/1993 UTHER ACTIONS AFFECTING DSSPOSAL OR USE OF STATE LA. SEE THE LAS CASLAILE OR ORIGINAL SOURCE DOCUMENTS 1 ADOMTIONAL (FORMATION: Uno wim ( } ATTENTION STATUS PLAT USERS: ON (15 PLAT, LINES CLOSE FOR ACTIONS THAT FXTEND INTO ADIACINT 1 | VMS (NC) UES STATUS LINES SUCH AS DISPOSAL, MUNI WPA ! CLASSINCA LUN, ETC, PLEASE RETTR TO ADIACENT TOWNS TO DETERMINE IF ACTIONS EXTEND REYOND THE BOUNDARI sao eer AN INDEX OF STATUS PLAT ABBREVIATIONS 1S INCLUDED WITH FACH APERTURE CARD SET OF STATE STATUS PLATS. « FURS PLAT, REMEMMER TITLE, CLASSIICANION, AND RISTRI ALWAYS CLOSE ON ALL PLATS. Pi ‘A PRODUCT OF 110: ‘ STATE OF ALASKA ‘ DEPARTMENT OF NATURAL RESOURCES LAND RECORDS (ORMATION SICTION ae trans ar machine sven eben nba ona aepene tarts nner cecum etl . LEGEND -BASE_INFORMATION. ew mene Pee My erorRenT ny weet et AMIE ELUSIRATION OY, SOURCE OOCLMENTS ATMA TE OFTEN MECORD es oF cooneeu res sed STATE MAN ZONE CONN Tome. wareencoy —— ‘SURVEY = See ee ‘SECTION UME =e am ‘WAJOR ROAD SECONDARY ROAD TRA eee BOUNDARY -_—, RALROAD —s—- TUECT pwr Ue — TELPHONE UNE ee aad a WORT CONTROL “t ] Lars OF Acton as one STRUCTURE TRAPPING CABN PORMT C PER FROM TRESPASS TRESPASS. CROUO, APU ROO, PER * Grown, CERT OV SURFACE, APL | 274 a OV SURFACE, PER Orv SURFACE, CORT RESERVED, APN RESERVED, CERT OV FESTALLATION, APLC DY IISTALLATION, PER DV INSTALLATION, CERT ° ° e x ° ® e o 3 s 4 a ° ® e _SECTION NUMBERING: RD 4 7] els e|o wis [ale 23} 2 s 9] 20] 2 6 Ne 31] 32] 33 | 54] 35 | 38 [s|sle so} 29 26 | 25 SCALE 40 S00 500.9 1902000 a eee “e 20 ws J i SS ee S10 Yoh meh = 2040 toot ee o Lp tee! A PRODUCT OF THE y STATE OF MASxA (( DEPARTUCNT OF NATURAL PESOURCES sp | aS O10 OF ANA EEN TWP'20N AUTOMATED DRAFTING SYSTEM RNG 3W i UIT CONTA CMO ~ SM iM: ae ofr, TOWNSHIP 30N RANGE 3W = OF THE SEWARD MERIDIAN, ALASKA __ STATUS PLAT __ UN STANTON OE MUAY EMMIS 1M OI CORO ‘STREAM WATERBODY suv == SECTION UN -——_— Asn ROAD SECONDARY ROAD tray a povoary en RALROAD ———- LECT PWR Ue ——— TELEPHONE UNE or) reeune A 7 WORE CONTROL ‘cy ) Lats OF ACTION moe wear Pek TMMEE DA MAM TENS (78) Me PCO aE vt 8 FEM oe TONNE OES weer Armed 8939 mer & Chane AMC PUD 04 13, AE — AIRPORTS OR I LWwosa stRPs STATUS INFORMATION me CLASSINCATION DsrosaL, UNC ra, RESTRICTIONS, FEDERAL ACTIONS PEYOTE CADRE PERT ° e TRAPPING CABH PERUT o PER FROM TRESPASS. x TRESPASS ° POW, AAW 8 ROUND, PER e CACO, CERT a Dv SURFACE, APL a s 4 a ° @ e OF Sat 188 ESOL O/ MTANIDCA SUSI BORON GMAT OPM THREE TA AECOROWE OSTRCT SAAC! 10 Srv ARCA RAN Oy SURFACE, PER Dv SURFACE, CERT \ SG ACSEAVED, APN 7 Pe: ee PESLRVED, CERT a OY STALLATION, APLC ss 23 Saeco hae I ; STRUCTURE Ov ISTALLATION, CERT ‘A PROOUCT OF THE F STATE OF ALASKA ( mauneniererodeeneea =| ae we j (rN OF UAMACEMENT t AUTOMATED DRAFTING SYSTEM Protracted Sections ; 3 and 4, T29N, R3W, S.M., ALASKA (0810) RECORD BASIS OF BE: ™| EAST (Troe Mean) S280 00 (True) ange 3278.20 (GRID) SEC FOR Ses LAT @2* 30°23 201" CONG 149° 49° 36:173 s0'26"€ 2640.83 (Gm0) TYPICAL MONUMENT MARKINGS mound won wected on om occensery 10 #90h monument. The tract he chews Himbertine, ond no freee ware ovetlabie the mounds ore made of forge fat slave tike stones. TWis treet Ia subject to © 50 foot sonament wach side of the section line which te reserved tothe State of Aloune for public regimens unter 0, The claimants corners ware recovered ia close proximity '0 ‘end were weed 10 control the location of the treet corners All bemrings, distances and coordinates vhows are Doved on the Aimaha Coordinate Syuiem, Zone 4, unless otherwise noted Thin servey woe eccomptohed In sceordonce with OTE $1.76-75 ant A& 38.08 077 He eroinage ways exist within this wurvey, the land in subject SITE OF STONE SIZE OF STONE fo sermet eter ran ott AT con SELEC int T General Selection - 1464 T tative Approvol dated 5/25/66 com |, ASL 177 LAT 68° san ree” LONG 149° 49'35.436° 193,98 198 198 xe "328,200 48 10" WORTH EGAL WP" ‘A tract of land located in the Northeast 1/4 of See.3 ond the North west 16 of Sec.4,T29N, RSW, SM, Alosha ond more fully described 2 follows: Beginning ot the North IA comer of See.3 9 bros cop monument Lat. 62* 38° 23.20", Long. 149°48' 39.70, Y= 3,156,992, X= 534,801, Zone 4 Thence $54°46'46"W. @ distonce of 3,183.21 feet ‘0 Corner |, o brass cop monument ond the true point of beginning. Thence N66*50'S9" Wa distance of 329.92 feet to Corner 2, 0 brass cop monement. Thence N23*O9'O"E. o distence of 659.83 feet 10 Corner 3, 2 brass cop monument. ‘Trance S66* 50' 59". © brase cap monument, ‘Thence $23°09'01" W. © Gistonce of 659.83 feet fo ihe true point of beginning. Containing 5.00 acres more or less. Beorings ond distances are Alaska Stole Plone, Zone 4 moo® 14° 52" w. Gistonce of 329.92 feet to Comer 4, _—— 400" 08 01" (Trae ene) 3290 00 west crmey (TRUE WEAN) (31 Dt BLM Bross cop monuments found ap monuments sat this survey 4.30" Galvanized Iron pipe #85 rebor 30” long. set ALASKA STATE LAND SURVEY No. 76-77 (AS PROVICED BY AS 38.05.077) STONE MOUND DATA SEARO ANO DrsTaNCe TO accessony_ 10" NORTH 10 wom 10" NORTH 10 NORTH 10" west 10 wORTH ‘62° 3a! 99 208" (eASS_OF_cogRDINATES PROTRACTED. 354, a "syd aan SURVEYOR'S CERTIFICATE | hereby certity that | om property registered ond licensed 0 practice lond surveying in the State of Alaska, ond that this plat represents @ survey made by me or under my direct supervision, ond the monuments shown thereon ‘octuolly mist os described, ond that al! dimensions and ‘other details. ore correct. aj J. Reg. No. 3796-5 en.) cea A TA ECTOA TES Nea) i900 VICINITY MAP I" = | MILE OWNERSHIP CERTWICATE ihe undersigned, seruby certty thot | am te Director, Alewhe Division of Londy, ond thet the State of Alesha is the omer of ASLS 76-77 2 chee hereon | hereiy eppsene thts corety ent piel forthe Siete of Aloka = a js LESSEE CERTIFICATE he iP th eng, Ney catty et | om the eae mw hereon ond 1 hereby opprove this wrvey and plot MARLENE T, TIS -- 4-26-77 Moriene J. Titws Date ADL No. 59498 BY ese AT BRVEY (0 AT NOTARY'S NOTARY'S ACKNOWLEDGEMENT Subverted end worn to batre me teZi%ey ot Aas l 177 “Aesop tel: oon a iy comaission expires STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF LANDS ANCHORAGE, ALASKA ALA*KA STATE LAND SURVEY No. 76-77 LOCATED wiTHim SECTIONS Sond 4, T 29m, CONTAINING 5.00 ACRES. Me, ALAS ‘DRAWN BY ARS. 10/27/78 S_ wasrueno. 76.27 sMeeT! OF 1 war 2173 94 LEGAL DESCRIPTION A troct of land locoted in the NWi/4 of Sec. 34 ond the SWI/4 of , ‘See. 27, TSON, RSW, Seward Meridian, Aloska ond more fully described ‘ 08 follows: Beginning at the South 1/4 corner of Sec. 34, @ brass cap monument, Lot. 62° 38°23. 20°, Long 149° 48° 39.70", Y= 3,156,992, X= 5M,801, Zone 4 ! i NOTES ! 1. TWe rect 1s mdject to @ 50 foot eovement | och wide of the section line which e reserved to the Stote of Aloake for pubile Nohways wnder AS. 19.10.010. | | 2. The cleimonte corners were recovered in close promimity to ond were used to control the lecation of the tract corners ‘Trance NOS*I7'27"W. @ distance of 4,716.44 feet to Cor.1, the true point of beginning, @ brass cop monument 1 & Thence N6O*37'30"W, a distance of 329.92 leet to Cor. 2, @ brass Cap monument, Thence N29° <2’ 30"E.@ distonce of 659.63 feet to Cor. 3, © brass cop monu-ent. ‘Thence $60° 37'30"E. a distonce of 329.92 feet to Cu. 4, © brass cop monument, ‘Thence $29°22'S0"W. @ distence of 659.85 feet to the ' true polat of beginning. Containing 5.00 eeres more or lees. Beorings ond Getonces ore Aloshe Stete Pione, Zone 4 ‘3. All beorings ond coordinates shown ore daved on the Alesha Coordinate System, Zomm 4, wtess otherwiee noted 4. Thie marvey wos occomplished in occerdence with OTE Si 76-74 ond AS. 38.05.077 5. Ne Groinage ways exist within this survey, The land Ie mabject 10 norma! water runott. © Stove mounds wer erected ot sock erected os on occessory te eech monament ‘Ths treet is ebowe timberiiag, and no frees were avoitable - the mounds ore move of large, let, siete lite stones, 3280.00 ( Tree teen) ‘SELECTION INFORMATION: General Selection~ 1470 Tentative Approval dated 5/18/66 STONE MOUND DATA SIZE OF STONE SITE OF STOME BEANIE AND ESSORY DISTANCE TO ACCESSORY 10" NORTH 10" womTW 10" NonT 10° NORTH Yasar yavar 5280.00 (TRUE MEAN) are 2640.63 (mio) 99° 51'197 E (GRID) RECORD AND BASIS OF BEARINGS — 792187 eS) a mm vues 1p monuments. set this survey (AS PROVIDED BY AS. 36.05.077) Protracted Sections 27 & 34, Tract A, T3ON, R3W, S.M, ALASKA ALASKA STATE LAND SURVEY No. 76-78 — PROTRACTE a ——=$——— FAST (te ene) - 2 | & . 5200.00 ( TRUE) : Naor ay'se"e 5279.47 (GMO) - = Ser | 26 N wn Dg => LAT. 6238100 4337 Come. r49°ae' 4a 73 Ys 3,161, 608.348 Xe S31, 366.098 8200.00 |.) 6 t 77-33 _ C—O % | Talkeetna | J: 3) 7a . 9:42 A. ‘ ie aS) OL I fice. see ps ea af | hereby certify that 1am property registered and licensed to proctice lond surveying in the Stote of Aloske, ond that this plat represents a survey mode by me or under my direct supervision, ond the monuments. shown thereon cctually exist a8 described, ond that ol! dimensions ond other details are correct Registered Land Surveyor Reg.No. 3796-5 Mey \ 7-6 MF USGS TALKEETMA MTS (7-6) 1949 VICINITY MAP I” = | MILE OWNERSHIP CERTIFICATE |, the undersigned, hereby cortity Met | om the Dwector, Alaske Division of Londs, and that the State of Aloske 1 the owner of ASLS 78-78 8 shown hereon. | hereby approve this marwey ond plat ‘or the Siete of Alesha —_ Sree acl _ Dore Director, Alek? Olvision of Lote NOTARY'S ACKNOWLEDGEMENT Subscribed ond sworn to before me mis, 229 2 4. My Commences expires : “ LESSEE CERTIFICATE : 1, the undersigned, herehy certty thet | om the lemee 09 shore Nereon end | hereby opprove this survey ond pict, fa 4-26-77 Cote ADL Na $9497 “av NOTARY'S ACKNOWLEDGEMENT Subscribed ond mom Yo bore me i Many ot Aaa f orr es Ne My Commission expires STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF LANDS ANCHORAGE, ALASKA ALASKA STATE LAND SURVEY No. 76-78 LOCATED WITHIN PROTR: “ED SECTIONS 27 and 34, ‘CONTAINING 3 00" Joly 28,1978, My 28197 TION, RSW, SM ALASKA DRAWN BY ans. 10/30/78 was ruemo 76-28 sneer 35 MEP Municipal Light & Power POWER MANAGEMENT 1200 East First Avenue Anchorage Alaska 99501-1685 phone 907.263.5450 fax 907.263.5441 November 9, 1999 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: ECEIVE NOV 12 1999 nC H O R @€A G@ E Rick Mystrom = Mayor D Alaska Industrial Development and Export Authority Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of October 1999. Doug Hall Chief Power Dispatcher DH/pjc Attachment CC: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA J. Cooley, CEA R. Morgan, MEA C. Petty, AEA c:\1-patty\IOC\so-oprtr\usage\cov-Itr.doc ALASKA INTERTIE USAGE REPORT FY 2000 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs ML&P TO ML&P TO CEA TO CEA TO CEA TO BRAD. LKE TO GVEA TO GVEA TO GVEA TO AIDEA TO AIDEA TO MONTH GVEA GVEA AEG&T GVEA ML&P CEA AEG&T CEA ML&P JULY 2244 18776 846 0 0 0 0 0 0 AUGUST 616 9333 844 0 0 0 0 0 0 SEPTEMBER 38 11667 838 0 0 0 0 0 0 OCTOBER 211 14908 329 0 0 0 0 0 0 NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 3109 ° 54684 0 2857 ° oO ° ° 0 0 ML&P CEA BRADLEY LAKE GVEA AIDEA GVEA AIDEA CEA ML&P AEG&T DELIVERIES DELIVERIES DELIVERIES DELIVERIES DELIVERIES RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS LINE TOTAL JULY 2244 19622 0 0 0 21020 0 0 0 846 21866 AUGUST 616 10177 0 0 0 9949 0 0 0 844 10793 SEPTEMBER 38 12505 0 0 0 11705 0 0 0 838 12543 OCTOBER 211 15237 0 0 0 15119 0 0 0 329 15448 NOVEMBER 0 0 0 0 0 0 0 0 0 0 0 DECEMBER 0 0 0 0 0 0 0 0 0 0 0 JANUARY 0 0 0 0 0 0 0 0 0 0 0 FEBRUARY 0 0 0 0 0 0 oO 0 0 0 0 MARCH 0 0 0 0 0 0 0 0 0 0 0 APRIL 0 0 0 0 0 0 0 0 0 0 0 MAY 0 0 0 0 0 0 0 0 0 0 0 JUNE 0 0 0 0 0 0 0 0 0 0 0 YR TOTAL 3109 57541 0 0 0 57793 0 0 0 2857 60650 ENERGY $ YTD $297,633.95 $0.00 $0.00 $0.00 $13,313.62 $282,629.00 11/02/1999 AIDEA TO ooo°o 11/02/1999 ALASKA INTERITE USAGE REPORT FY 2000 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs ML&P TO ML&P TO MONTH GVEA JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 0 0 ocooo oooo ML&P CEA DELIVERIES DELIVERIES JULY 0 AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL RESERVE $ YTD eooeoeoaeaa eae eo oo eoeoaceaaeo oe OO CEA TO GVEA ooon BRADLEY LAKE DELIVERIES eceoeoeoeoe eo oO OOO oO Oo CEA TO eoooo GVEA DELIVERIES ecooeoeoe eo OOOO oO CEA TO AEG&T coon AIDEA DELIVERIES coeoeoeoeoe ea O OOO oO BRAD. LKE TO GVEA ocoooono GVEA RECEIPTS ecooaoaoee eo eee CO $0.00 GVEA TO ML&P cocoon AIDEA RECEIPTS eooaoaoeea ea oO COO CO Oo $0.00 GVEA TO CEA ecooo CEA RECEIPTS coooec ee oO OC CO Oo $0.00 GVEA TO AEG&T coo°o ML&P RECEIPTS eoooeceoea oOo OO oO AIDEA TO CEA oooo°o AEG&T RECEIPTS coooeceaaea oO Ao oO oO $0.00 AIDEA TO ML&P ocoooco LINE TOTAL coooeceoaea eo oO oOo $0.00 AIDEA TO AEG&T ooo°o GOLDEN VALLEY ELECTRIC ASSOCIATION INC. PO Box 71249 « Fairbanks, Alaska 99707-1249 * 907-452-1151 May 18, 1999 Stan Sieczkowski Alaska Industrial Development and Energy Authority 480 West Tudor Anchorage, AK 99503-6690 Subject: FY0O Intertie Usage Estimate Listed below, by month, is GVEA’s projected intertie usage for FYOO. Month/Year MWH Jul 99 3,941 Aug 99 12,342 Sep 99 15,579 Oct 99 8,000 Nov 99 2,500 Dec 99 5,000 Jan 00 5,000 Feb 00 2,500 Mar 00 2,000 Apr 00 8,000 May 00 7,000 Jun 00 21,525 Total FYOO 93,387 MWH Brad Evans sen Dispatch Manager Bcd eeooea cc: Mike Kelly Robert Hansen Steve Haagenson GOLDEN VALLEY ELECTRIC ASSOCIATION INC. PO Box 71249 « Fairbanks, Alaska 99707-1249 * 907-452-1151 May 18, 1999 Stan Sieczkowski Alaska Industrial Development and Export Authority 480 West Tudor Anchorage, AK 99503-6690 Subject: Determination of the FY00 Minimum Intertie Transfer Capability Rights (MITCR) Per Section 7.2, we are submitting the peak loads for MITCR calculation for GVEA. 1996-1997 1997-1998 1998-1999 134.1 Mw 168.8 MW 175.5 Mw — —_ Brad Evan System Dispatch Manager esha cc: Mike Kelly Robert Hansen Steve Haagenson GOLDEN VALLEY ELECTRIC ASSOCIATION INC. PO Box 71249 » Fairbanks, Alaska 99707-1249 * 907-452-1151 May 18, 1999 Stan Sieczkowski Alaska Industrial Development and Export Authority 480 West Tudor Anchorage AK 99503-6690 Subject: GVEA FY00 Alaska Intertie Operating Budget Submittal Attached is GVEA’s FY00 budget submittal for: 1. NORTHERN HALF TRANSMISSION LINE MAINTENANCE AND WORK PLAN 2. SUBSTATION PREVENTIVE MAINTENANCE PLAN FOR HEALY, GOLD HILL, AND CANTWELL SUBSTATIONS ao System Dispatch Manager cc: Monte Ervin Mike Wright ANCHORAGE-FAIRBANKS INTERTIE Fy _ 2000 TRANSMISSION LINE MAINTENANCE (Northern 1/2) AND WORK PLAN Summary 3 ea. Routine Patrols 1 ea. Ground Patrol 1/10 Climbing Inspection Insurance TOTAL TRANSMISSION LINE MAINTENANCE (Northern 1/2) Re-level Structures Rebuild and Reclear ROW Reclearing TOTAL SPECIAL PROJECTS Special Projects and Adjust Guys Landing Pads Page 1 Rev. 5-99 Yearly Cost $ $ 12,582 15,000 31,800 1,750 61,132 30,000 45,000 20,000 95,000 Rev. 5-99 Fy 2000 ANCHORAGE-FAIRBANKS INTERTIE PREVENTIVE MAINTENANCE AND WORK PLAN of Approximately 85 Mile of Intertie Line (Northern 1/2) Intertie Transmission Line Maintenance Program Section 3.0 AEA Preliminary Draft Routine Patrols, Aerial Special Patrols, Aerial Emergency Patrols, Aerial Ground Patrols Climbing Inspections There are many conditions that occur which cause operating problems on a transmission line or limit its useful life. The above maintenance tasks will help discover these conditions and corrective action may prevent serious damage or line failure. Page 2 Rev. 5-99 FY 2000 ANCHORAGE-FAIRBANKS INTERTIE PREVENTIVE MAINTENANCE BUDGET INTERTIE TRANSMISSION LINE NORTHERN PORTION Routine Patrols Routine visual aerial inspection patrol. Pilot and helicopter (fuel furnished) by contract or by owner’ furnished each occurrence. Recommend every 120 days. Three per year. Time Per Hour Total Yearly Helicopter and pilot wet 6 hrs flying $520.00 $3,120 Standby time for helicopter 2 hrs standby 0 0 One Line Foreman Inspector 8 hrs ST 74.29 594 One Manhaul Vehicle 8 hrs ST 20.00 160 Infrared Camera 8 hrs 20.00 160 w/helicopter mount High Intensity Light on 8 hrs 20.00 160 helicopter Total $4,194 3 ea. Routine Patrols/Year $4160 x 3 = $12,582/yr Special Patrols Special aerial patrol is a non-scheduled or a short notice scheduled visual inspection of the line performed after there has been a momentary interruption due to severe weather or indication of problems in vicinity of the line. Time Per Hour Total Helicopter and pilot wet 6 hrs flying $520.00 $3,120 Standby time for helicopter 2 hrs standby 0 0 One Line Foreman Inspector 8 hrs ST 74.29 594 One Manhaul Vehicle 8 hrs ST 20.00 160 Infrared Camera 8 hrs 20.00 160 w/helicopter mount High Intensity Light on 8 hrs 20.00 160 helicopter Total $4,194* *(NOT INCLUDED IN BUDGET ESTIMATE) Page 3 Rev. 5-99 Emergency Patrols Non-scheduled aerial visual inspection when there is an apparent permanent fault on the line and the protective circuit breakers are locked out. Time Per Hour Total Helicopter and pilot wet 6 hrs flying $520.00 $3,120 Standby time for helicopter 2 hrs standby 0 0 One Line Foreman Inspector 8 hrs ST 74.29 594 One Manhaul Vehicle 8 hrs 20.00 160 High Intensity Light with 8 hrs 20.00 160 helicopter mount Total $4,034* * (NOT INCLUDED IN BUDGET ESTIMATE) Ground Patrols Summer or winter ground patrol. Estimated one patrol per year. Total Equipment Required $ 7,500 (est.) Total Labor Required 7,500 (est.) Total 15,000 One Ground Patrol/Year $15,000 Page 4 Rev. 5-99 Climbing Inspections Climbing inspection, per tower, every ten years unless needed in severe weather areas or remote locations. Estimated 424 towers. Labor Time Per Hour Total Foreman 1 hr st $ 74.29 $74.29 Lineman 1 hr ST 74.29 74.29 Apprentice i he St 63.14 63.14 Equipment Equipment Manhaul 1 hr 20.00 20 Possible helicopter .33 hrs 520.00 171 Tracked Manhaul 2 hrs 150.00 300 Lodging & meals (3 man @ 160/day and 10 towers/day) 48 Total $ 750/tower Climbing Inspection (1/10 above) for yearly = $31,754 Special Insurance Special Insurance Required by Contract $ 1,750 TOTAL TRANSMISSION LINE MAINTENANCE $ 61,132 NOTE: 1) Supervision and recordkeeping costs are included in the overhead for the manhour rate. 2) More helicopter time, in addition to that shown, may be necessary for access on routine ground patrol and climbing inspections. Page 5 Special Projects ho Re-level Structures and Adjust Guys - $30,000 Work includes rigging towers and lowering point of attachment on pilings. A permanent notation will be left on the piling to note work done in case of future jacking. Estimated costs include 30 man/hrs per tower, equipment, helicopter, and room and board. Estimated costs for structures that only require re-plumbing include 12 man/hrs. per tower, equipment, and helicopter. Ds: Rebuild and Reclear Landing Pads - $45,000 Again, this is a continuation of rebuilding the original construction helipads. Work includes installing new foundations and stringers with decking. Some structures will only require clearing an area large enough for helicopter access and leveling. 3. ROW Reclearing - $20,000 This work will include selective reclearing in areas where growth has a possible impact on access or operation. Particular attention will be on “helicopter access only” areas. TOTAL SPECIAL PROJECTS = $95,000 Page 6 Fy 2000 GVEA EQUIPMENT Equipment Cost per Hour Snow Machine $ 15.00 Pick-up (4x4) 12.00 Service Truck (4x4) 20.00 Bucket Truck (wheel) 65.00 Digger Truck (6x6) 100.00 Dozer 350-550 60.00 Trailers (small) 7.00 Lowboy Trailer 20.00 Tractor 70.00 Terra Flex Digger 100.00 Manhaul Track Vehicle 65.00 Kershaw Brushcutter 100.00 Portable Building 25.00 Terra Flex Bucket 105.00 ATV (small) 15.00 Hagglund Bearcat 206 150.00 Page 7 GVEA LABOR COSTS Position STRAIGHT TIME Dispatcher Electrician/Lineman Accounting Superintendent OVERTIME Dispatcher Electrician/Lineman Accounting FY 2000 Rev. 5-99 Total Current GVEA Cost/ Base Rate Overhead Manhour $34.40 $44.72 S79 12 $32.30 $41.99 $74.29 $29.55 $38.42 $67.97 $36.80 $47.84 $84.64 $51.60 $44.72 $96.32 $64.60 $41.99 $106.59 $44.33 $38.42 $82.74 Page 8 ACCOUNT NUMBERS AEA INTERTIE MAINTENANCE BASIC ACCOUNT NUMBERS Transmission Operation 560 Operation Supervision and Engineering 562 Station Expense 563 Overhead Line Expense Transmission Maintenance 568 Maintenance Supervision and Engineering 570 Maintenance of Station Equipment 571 Maintenance of Overhead Lines Detailed Accounting Codes Tieline Substation Operation/ Man/hr. Inventory Substation Maintenance Man/Hr. Working Patrol Ground Mile 563.11 Aerial Patrol Mile 563.310 Climbing Inspection Structure 563.12 Insulator (replace) String 571.10 Right-of-Way Reclear Acre 571.11 and Treatment Culvert & Gate Each 571.12 (repair & installation) Tower Repair Structure 571.13 Conductor & Hardware Position 571.16 Inventory/Repair or Replace Emergency Patrol Mile 571.14 Emergency Repair (major) Incident 571.15 Operations Supervision Man/Hr. 560.10 and Engineering Maintenance Supervision Man/Hr. 568.10 and Engineering Page 9 HLS 562.10 570.10 560.10 568.10 Cws 562:..71 570.44 560.10 568.10 GHS 562) ..12 570.12 560.10 568.10 Rev. 5-99 DGS 562.14 570.14 Rev. 5-99 FY_ 2000 ANCHORAGE-FAIRBANKS INTERTIE SUBSTATION PREVENTIVE MAINTENANCE PLAN AND BUDGET HPS, GHS, CWS SUMMARY Yearly Costs SCADA Maintenance $21,284 Walk Through Monthly Inspection 23,607 Minor Inspections 9,453 Major Inspections 9,984 Insurance 500 TOTAL SUBSTATION MAINTENANCE $64,828 Page 1 Rev. 5-99 FY _ 2000 ALASKA INTERTIE SUBSTATION PREVENTIVE MAINTENANCE AND WORK PLAN Substation Maintenance Program Gold Hill 100 M.V.A. 138-69-13.8 KV Transformer Static VAR System SVS Building Sequence of Events Recorder and Remote Synchronizing Equipment Healy 138 KV main and transfer bay with line exit 138 KV circuit switcher 33.3 M.V.A. 138-12 KV transformer Static VAR System SVS Building Relaying control and metering Fault Recorder and Events Recorder Remote Synchronizing Equipment Cantwell 345 KV line disconnect switches 161 KV circuit switcher 5000 KVA 138-24.9 KV transformer 24.9 KV vacuum reclosers 24.9 KV bus and line exits Transformer, metering relaying controls 24.9 KV control and metering SCADA RTU Page 2 Rev. 5-99 Fy 2000 ALASKA INTERTIE SUBSTATION PREVENTIVE MAINTENANCE PLAN AND BUDGET Walk Through Monthly Inspection Visual and walk-through inspection once a month on each substation. This can be accomplished in a normal working day. Time Per Hour Total Yearly Electrician Inspection 8 hrs ST $74.29 S59de32 Vehicle Manhaul 8 hrs ST S12;500) $ 96.00 Total each $690.32 (HEPA MGHS CWS) S690LS2) sci — $2070.96 $2070.96 x 12 months $24,951.52 Minor Inspection Once a year. Visual and operational inspections, electrical testing and cleaning, oil samples, recloser load tap changing equipment--each substation. Time Per Hour Total Yearly Foreman 16 Bre ee $74.29 $1188.64 Electrician L6uhrs usm $74.29 $1188.64 Vehicle Manhaul 16 ches aor S200 S920 0 Substation) Madintiawel crane LOmlrs mol $45.00 Sa 20E00 Total each $3,289.28 (HLP, GHS CWS) $3289.28 x 3 = $9,867.84 Major Inspection Once every six years. Remove equipment from service and check for operation and work on under clearance -- each substation. Labor Time Per Hour Total Yearly Foreman 40 hrs ST $74.29 $2971.60 Two Electricians 40 hrs ST ea $74.29 ea $5943.20 Lead Lineman 40 hrs ST $74.29 $2971.60 Lineman 40 hrs ST $74.29 $2971.60 Labor Total $14,858.00 Page 3 Major Inspection (continued) Equipment Time Per Hour Total Yearly Vacuum Pump and Filter Press with: 6 Clean Drums $25.00 $ 150.00 Subst. Maint. Trk #60 40 hrs $45.00 $1800.00 Service Truck 40 hrs $14.00 $ 560.00 Vacuum Pump & filter 40 hrs $40.00 $1600.00 press Rent Doble Test Equip $1000.00 Equiment Total $5110.00 Total Labor & Equipment $19,968.00 Yearly = 1/6 total (HLP, GHS, CWS) $3328 x 3 = $9,984.00 Tests and Inspections can be found under Section 2.0 of: Alaska Power Authority Alaskan Intertie Maintenance Plan Insurance Special Insurance Required by Contract $ 500.00 SCADA Maintenance Normal maintenance for GHS, HLS (2), $ 21,284.00/yr CwS, and Communication circuits involved with these RTU’s and that protion of Master Station maintenance approved for Intertie usage. This is estimate billed on actual. SUBSTATION MAINTENANCE TOTAL * $66,055.36/yr * Supervision, accounting and recordkeeping costs are included in the labor overhead rate. Page 4 GVEA EQUIPMENT Equipment Snow Machine Pick-up (4x4) Service Truck (4x4) Bucket Truck (wheel) Digger Truck (6x6) Dozer 350-550 Trailers (small) Lowboy Trailer Tractor Terra Flex Digger Manhaul Track Vehicle Kershaw Brushcutter Portable Building Terra Flex Bucket ATV (small) Hagglund Bearcat 206 FY _ 2000 Page 5 Cost per Hour Sieeltay. -00 20. -00 100. 60. -00 -00 70; -00 -00 100). 25% L051. Si 1501 12 65 a 20 100 65 00 00 00 00 00 00 00 00 00 00 Rev. 5-99 Rev. 5-99 FY 2000 GVEA LABOR COSTS Total Current GVEA Cost/ Position Base Rate Overhead Manhour STRAIGHT TIME Dispatcher $34.40 $44.72 $79.12 Electrician/Lineman S32 ..30 $41.99 $74.29 Accounting $29.55 $38.42 $67.97 Superintendent $36.80 $47.84 $84.64 OVERTIME Dispatcher $51.60 $44.72 $96.32 Electrician/Lineman $64.60 $41.99 $106.59 Accounting $44.33 $38.42 $82.74 Page 6 ACCOUNT NUMBERS AEA INTERTIE MAINTENANCE BASIC ACCOUNT NUMBERS Transmission Operation 560 Operation Supervision and Engineering 562 Station Expense 563 Overhead Line Expense Transmission Maintenance 568 Maintenance Supervision and Engineering 570 Maintenance of Station Equipment STL Maintenance of Overhead Lines Detailed Accounting Codes Tieline Substation Operation/ Man/hr. Inventory Substation Maintenance Man/Hr. Working Patrol Ground Mile 563.11 Aerial Patrol Mile 563.10 Climbing Inspection Structure 563.12 Insulator (replace) String 571.10 Right-of-Way Reclear Acre 571.11 and Treatment Culvert & Gate Each 571.12 (repair & installation) Tower Repair Structure 571.13 Conductor & Hardware Position 571.16 Inventory/Repair or Replace Emergency Patrol Mile 571.14 Emergency Repair (major) Incident 571.15: Operations Supervision Man/Hr. 560.10 and Engineering Maintenance Supervision Man/Hr. 568.10 and Engineering Page 7 HLS 562.10 570.10 560.10 568.10 Cws 562.11, 570 4:1. 560.10 568.10 GHS 562.12 570512 560.10 568.10 Rev. 5-99 DGS 562.14 570.14 CHUGACH ELECTRIC ASSOCIATION, INC. ASSOCIATION, INC. EGEIVE } April 9, 1999 \\ APR 1 2 1999 Alaska Industrial Development Mr. Stan Sciezkowski and Export Authority AIDEA 480 W Tudor Rd. Anchorage, AK 99503 Re: — Failed Battery at Daves Creek SVS Dear Stan, This letter is to inform you that the Daves Creek SVS substation battery bank, ID # BAT 200, has failed. High temperature cells, approximately 20°F above ambient, were found during a station inspection on 3/23/99. The battery was impedance tested the following day. The impedance was so high it exceeded the range of the test equipment and at this time batteries were noted to be bulging and some of the cases cracked. On 3/25/99 a mobile battery unit was installed. The battery has failed and must be replaced immediately. The battery is an Exide 125VDC valve regulated lead acid battery. It was installed in 1992 when the station was built and has lasted seven years. Though sold as a 20-year battery, this is typical of the life of valve regulated batteries as experienced by Chugach Electric. Of note is that the battery failed rather suddenly not allowing for a planned replacement. To remedy the situation a new battery is being ordered. It will be a real 20-year life battery, wet cell acid or NICAD, and not a valve regulated one. The cost will be approximately $25,000 including installation. The replacement is to be installed within three months. Sincerely, C= CD e os ge Paul Risse Manager, Substation Operations PR/Is (I:/Technical Services/Substation/Letters/daebatte.doc) cc: Brian Hickey, CEA 5601 Minnesota Drive ¢ P.O. Box 196300 ¢ Anchorage, Alaska 99519-6300 Phone 907-563-7494 # FAX 907-562-0027 Swan Lake Hydroelectric Project Field and Travel AIDEA SWAN LAK' Principal Associate Senior Scientist Project Scientist Scientist 3 Scientist 2 Scientist 1 Senior Technician Technician Support Information Services (2%) Field Equipment (day) Nuclear Density Gauge (hr) Vehicle (mile) Soil Samples (rings) Soil Samples (tubes) OVA-FID, or PID (hr) Gas and O2 Meters (hr) Water Quality Testing (day) Data Logger Development and Sampling Pumps (day) Vapor Extraction Equipment Air Sparging Equipment Water Disposal Equipment Disposable Bailers 2-inch Disposable Bailers 3-inch Disposable Filters CAD Drafting (hr) Phone (min) Cellular Phone (min) Fax (pg) Copies (pg. Airfare (trip Rental Car (day) Meals (day) Drilling (lump) Outside Contractors Analytical testing (lump) (GE!) Film and Developing Shipping FIELD AND TRAVEL TOTAL El JOB #7388-001-00 PAPA PAAHAHA HAH PRPPHPPAPPHAPPAPAAHAPAPAAAAPAHAAAAHAAAAHAPAAANHN Ff Rate 144.00 137.00 115.00 102.00 93.00 82.00 70.00 70.00 57.00 57.00 10.00 10.00 0.50 3.00 6.00 20.00 10.00 50.00 300.00 100.00 500.00 500.00 50.00 10.00 20.00 20.00 65.00 0.50 1.00 0.12 0.12 700.00 50.00 20.00 50.00 5,000.00 30.00 100.00 Qual COON 50 oooo°o Pe ooocoococoeoeoeorcooecoeceacecoeeeceececeececeeaeaoaceaeeeoeceeo ed PPP AHAFAPAPPAPHAPAPAPAAAAHAAAAAPAPAPPAPAPHADPAPAAADPAPHA#DAADAAAAHAAAAAPAPHAH ANNA TOTAL 288.00 4,650.00 100.00 $5,836.76 CITY of WRANGELL, ALASKA INCORPORATED JUNE 15, 1903 BOX 531, 99929 (907) 874-2381 FAX: (907) 874-3952 ECEIVE NOV 3 1999 Alaska Industrial Development and Export Authoritv ADOPTED AUGUST 1972 October 29, 1999 Mr. Stan Sieczkowski Alaska Energy Authority 480 West Tudor Road Anchorage, Alaska 99503 RE: City of Wrangell Emergency Power Dear Mr. Sieczkowski, This morning, October 29, 1999, Ms. Jane Heineman of Powers Engineers discussed with you the possible situation the City of Wrangell could encounter if we had a generator failure while the Tyee Transmission line is still being repaired. The City is trying to formulate an alternate plan should one of our generators fail during the next couple of weeks and are asking the cooperation of the AEA to help see us through these times. The City of Wrangell is willing to absolve AEA of any wrongdoing during the periods when a back feeding would occur during the use of Silver Bay Logging Company’s generating capacity. At the same time, the City is willing to pay for switching gear damage should it occur and is a result of the backfeeding as well as pay for the costs for an employee to perform the switching at the Thomas Bay Power Authority’s Wrangell yard. Ms. Heineman has spoken with Mr. Ron Beazer of Powers Engineering about the new relay settings for Silver Bay Logging to facilitate the use of their power source, if needed. A public announcement will be aired over KSTK to advice consumers on Feeder #4 to disconnect item such as computer, TV’s, VCR’s and the likes because of possible voltage frequency variations. We trust that AEA will work with the City of Wrangell during these precarious times until the Tyee line is energized and the City has upgrade it’s generation equipment. Should you have any questions, please feel free to contact me. Yours truly, —— David L. Soulak City Manager CC: Mayor Neimeyer City Council Jim Nelson ae Municipality of Anchorage Municipal Light & Power Pe eae, Wega 1200 East First Avenue Anchorage, Alaska 99501-1685 June 13, 1995 Telephone: (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 Alaska Industrial Development and Export Authority 480 W. Tudor Road JUN 15 1995 Anchorage, AK 99503-6690 Alaska Industria] Development Attention: Riley Snell and Export Authority Executive Director Dear Mr. Snell: The IPG at its April 13, 1995 meeting passed the following resolution: "Subject to AIDEA approval, the IPG authorizes Chugach to proceed with routing studies, preliminary design, and environ- mental work necessary to perform Phase | on the Southern It is the intent of the IPG that Chugach will not be required to advance fund any payments to contractors or consultants. In the meantime, the Parties will negotiate in good faith to complete a Construction Management Agree- ment”. The IPG members have also executed a "Memorandum Of Understanding In Aid Of Beginning Activities To Build The Southern Interties". Among other things this Memorandum of Understanding is to facilitate the IPG Resolution on routing and environmental work. Chugach will deliver copies of this Memorandum under separate cover. With these actions we hope to begin on the Southern Intertie. a Thomas R. Stahr Chairman, IPG Sincerel CC: IPG Members Putting Energy into Anchorage for Over 60 years code of federal regulations BLM - AK -GI-91-005-1840-964 Public Lands: Interior 43 PART 4 Department Hearings and Appeals Procedures Subpart E- Special Rules Applicable to Public Land Hearings and Appeals U.S. Department of the Interior Bureau of Land Management Alaska State Office Division of Conveyance Management Office of the Secretary of the Interior PART 4—DEPARTMENT HEARINGS AND APPEALS PROCEDURES Subpert 8—Spedel Rules Applicodle to Public land Hearne: aad Apeesi: Arreats Paocesones Finality of decision; reconsideration. 4.410 Who may appeal. Ae vee: how taken, mandatory time 4.412 Statement of reasons, statement of standing, written arguments, briefs. 4.413 Service of notice of appeal and of other documents. : 4.414 Answers. ACTIONS BY BOARD OF LAND APPEALS 4.418 Request for hearings on appeals in- volving questions of fect. Subpert E—Speciel Rules te Public Lend Heerings end Ap- Avtnonity: Sections 4.470 to 4.478 of this Subpart E also issued under authority of sec. 2, 48 Btat. 1270; 43 U.S.C. 3150. Cross Rerenence: Bee Subpart A for the authority, jurisdiction and membership of the Board of Land Appeals within the Office of Hearings and Appeals. For general rules applicable to proceedings before the Board of Land Appeals as well as the other Appeals Boards of the Office of Hearings and Appeals, see Subpart B. Aprzats Paocepunss APPEALS PROCEDURES; GENERAL 04.400 Definitions. As used in this subpart: (a) “Secretary” means the Secretary of the Interior or his authorized repre- sentatives. (b) “Bureau” means Bureau of Lard Management. (ce) “Board” means the Board of Land Appeals in the Office of Hear- ings and Appeals, Office of the Secre- tary. The terms “office” or “officer” as used in this subpart include “Board” where the context requires. - (4a) “Administrative jew judge" means an administrative law judge in the Office of Hearings and Appeals, Office of the Secretary, appointed under section 3105 of Title & of the United Btates Code. 046.408 Documents. (a) Grace period for filing. When. ever a document is required under this subpart to be filed within a time and It ts mot received tn the proper office during that time, the delay in fing will be waived if the document ts filed not later than 10 days diter it was required to be filed and it ts determined that the docu. ment was transmitted or probably transmitted to the office in which the filing is required before the end of the period in which it wag required to bé {lled, Determinations under this para- graph shall be made by the officer before whom ts pending the appeal in connection with which the document ts required to be filed. (b) Transferees and encumbrancers, Transferees and encumbrancers of land the title to which is claimed or ts in the process of acquisition under any public land law shall, upon filing notice of the transfer or encumbrance in the proper land office, become enti- tled to receive and be given the same notice of any appeal, or other proceed- ing thereafter initiated affecting such interest which Is required to be given to a party to the proceeding. Every such notice of a transfer or encum- brance will be noted upon the records of the land office. Thereafter such transferee or encumbrancer must be made a party to any proceedings thereafter initiated adverse to the entry. (c) Service of documents. (1) Wher- ever the regulations in this subpart re- quire that a copy of a document be served upon a person, service may be made by delivering the copy personel- ly to him or by sending the document by registered or certified mall, return receipt requested; to his address of record in the Bureau. (2) In any case service may be proved by an acknowledgment of serv- Ice signed by the person to be served. Personal service may be proved by ® written statement of the person who made such service. Bervice by rests- tered or certified mal! may be proved by a post-office return receipt showing that the document was delivered at the person's record address or showing that the document could not be deliv- ered to such person at his record ad- dress because he had moved therefrom without leaving a forwarding address or because delivery was refused at that eddreas or because no such address exists. Proof of service of a copy of a document should be filed in the same office in which the document Is filed except that proof of service of a notice. of appeal should be filed in the office of the officer to whom the appeal is made, if the proof of service Is filed later than the notice of appeal. (3) A document will be considered to have been served at the time of per- sonal service, of delivery of a regis- tered or certified letter, or of the teturn by post office of an undelivered registered or certified letter. (36 PR 7186, Apr. 15, 1871, as amended at 36 PR 16117, Aug. 13, 1671) 04403 Summary dismicsal. An appeal to the Board will be sub- fect to summary dismissal by the Board for any of the following causes: (a) If a statement of the reasons for the appeal is not included in the notice of appeal and is not filed within the time required; (b) If the notice of appeal is not served upon adverse parties within the Ume required; and (c) Lf the statement of reasons, if not contained in the notice of appeal, is Bot served upon adverse parties within ma) Ht te etnte statement of standing re- quired by §4.412(b) is not filed with the Board or is not served upon ad- Verse parties within the time required. (36 FR 7186, Apr. 16, 1071, as amended at 47 WR 26302, June 18, 1982) 00603 Pinality ef decislen; recencider- bien. 4 decision of the Board shall consti- tute final agency action and be effec- tive upon the date of issuance, unless the decision itself provides othewise. The Board may reconsider a decision tn extraordinary circumstances for Sufficient reason. A petition for recon- sideration shall be filed within 60 days after the date of a decision. The peti- 43 CFR Subtitie A (10-1-89 Edition’ tion shall, at the time of filing, state with particularity the error claimed and include alJ arguments and sup- porting documents. The petition may include a request that the Board stay the effectiveness of the decision for which reconsideration is sought. No answer to a petition for reconsider- ation is required unless so ordered by the Board. The filing, pendency, or denial of a petition for reconsideration shall not operate to stay the effective- ness or affect the finality of the deci- sion involved unless so ordered by the Board. A petition for reconsideration need not be filed to exhaust adminis- trative remedies. (63 PR 21308, June 6, 1987) APPEALS TO THE BOARD OF LAND APPEALS 04.410 Whe may appeal. (a) Any party to 8 case who is ad- versely affected by a decision of an of- ficer of the Bureau of Land Manage- ment or of an administrative law judge shall have a right to appeal to the Board, except— (1) As otherwise provided in Group 2400 of Chapter II of this title, . (2) To the extent that decisions of Bureau of Land Management officers must first be appealed to an adminis- trative law judge under § 4.470 and Part 4100 of this title, (3) Where a decision has been ap- proved by the Becretary, and (4) As provided in paragraph (b) of this section. (bo) Por decisions rendered by De- partmental officials relating to land selections under the Alaska Native Claims Settlement Act, as amended, any party who claims a property inter- est in land affected by the decision, an agency of the Federal Government or @ regional corporation shall have a right to appeal to the Board. (41 PR 26302, June 16, 1063) aan A bow pl 2d Makes maadatery (a) A person who wishes to appeal to the Board must file in the office of the officer who made the decision (not the Board) a notice that he wishes to appeal. A person served with the deci- sion being appealed must transmit the notice of appeal in time for it to be Office of the Secretary of the interior filed tn the office where it ts required to be filed within 30 days after the Gate of service. If a decision is pub- shed in the Feorna, ReoisTer. 0 Berson not served with the decision must transmit a notice of appeal in time for it to be filed within 30 days after the date of publication. (b) The notice of appeal must give the serial number or other identifica- tion of the case and may include a statement of reasons for the appeal, a statement of standing If required by § 4.412(b), and any arguments the ap- Dellant wishes to make. (ce) No extension of time will be granted for filing the notice of appeal. If a notice of appeal ts filed after the grace period provided in § 4.401(a), the notice of appeal will not be considered and the case will be closed by the offi- cer from whose decision the appeal is taken. If the notice of appeal is filed during the grace period provided in § 4.401(a) and the delay in filing ts not waived, as provided in that section, the notice of appeal will not be considered and the appeal will be dismissed by the Board. (RB. 2478, as amended, 43 U.S.C. 1201; sec. 28, Alaska Native Claims Settiement Act, as amended, 43 U.S.C, 1601-1628; and the Ad- ministrative Procedure Act, § U.S.C. 581, et eeq.) (36 FR 7106, Apr. 16, 1971, as amended at 36 FR ty Aug. 13, 1971; 49 FR 6373, Feb. 21, 1984 04.412 Statement of reasons, statement of standing, written arguments, briefs. (a) If the notice of appeal did not in- clude a statement of the reasons for the appeal, the appellant shall file such a statement with the Board (ad- dress: Board of Land Appeals, Office of Hearings and Appeals, 4015 Wilson Boulevard, Arlington, VA 22203) within 30 days after the notice of was filed. In any case, the Board will permit the appellant to file additional statements of reasons and written arguments or briefs within the 30-day period after the notice of appeal was filed. (b) Where the decision being ap- pealed relates to land selections under the Alaska Native Claims Settlement Act, as amended, the appellant also shall file with the Board a statement of fects upon which the appellant 3 relles for standing under § 4.41% within 30 days after filing of im notice of appeal. The statement may be included with the notice of appeal fled pursuant to § 4.411 or the state. ment of reasons filed pursuant to paragraph (a) of this section or be flled as a separate document. ~~. (c) Fatlure to file the statement of reasons and statement of standing within the time required will subject the appeal to summary dismissal as provided in § 4.402, unless the delay in {ling ts waived as provided in 04.401¢a). (47 FR 26392, June 18, i902) 04.413 Service of notice of appeal and of ether documents. (a) The appellant shall serve a copy of the notice of appeal and of any statement of reasons, written argu- ments, or briefs on each adverse party named tn the decision from which the appeal is taken and on the Office of the Solicitor as identified in para- graph (c) of this section. Service must be accomplished in the manner pre- scribed in §4.401(c) of this title not later than 16 days after filing the doc- ument. (b) Failure to serve within the time required will subject the appeal to summary dismissal as provided in §4.402 of this title. (cX1) If the appeal ts taken from a decision of the Director, Minerals Management Service, or of the Direc- tor, Bureau of Land Management, the appellant will serve the Associate Bo- Ucitor, Division of Energy and Re- sources, Office of the Solicitor, US. Department of the Interior, Washing- ton, DC 20240. (2) If the appeal is taken from a de- eision of other Bureau of Land Man- agement (BLM) offices listed below (see § 1821.2-1(d) of this title), the ap- pellant shall serve the appropriate Re- gional or Field Solicitor as identified: () BLM Alaska State Office, includ-. ing all District and Area Offices within its area of jurisdiction: Regional Solicitor, Alaska 4230 University Drive Suite 300, Anchorage, AK 99508-4626* (i) BLM Arizona Btate Office, in- cluding all District and Area Offices *New address as of 4/6/92 within its area of Jurisdiction: tor, U.S. Department of the Inte- ree so. North Becond Street, Buite 160, Phoenix, AZ 66004-3004; (iu) BLM California State Office, in- cluding all District and Area Offices within its area of jurisdiction: Bolicitor, Pacific Southwest Region, U.S. Department of the Interior, 2800 Cottage Way. Room E-2753, Sacra- mento, CA 06825-1690; (iv) BLM Colorado State Office, in- cluding all District and Area Offices within its area of jurisdiction: Bolicitor, Rocky Mountain Region, US. Department of the Interior. P.O. Box 26007, Denver Federal Center. Denver, CO 00228; (v) BLM Eastern States Office, in- cluding ali District and Area Offices within its area of jurisdiction: Associate Golicitor, Division of Energy and Resources, Ollice of the Bolicitor, U8. De- — of the Interior, Washington, DC 40; (vi) BLM Idaho State Office, includ- ing all District and Area Offices within its area of jurisdiction: Field Solicitor, U.S. Department of the Inte- rior, Federal Buliding, U.8. Courthouse, gue Port Street, Box 620, Boise, ID (vil) BLM Montana State Office, in- cluding all District and Area Offices within its area of jurisdiction: Field Solicitor, U.S. Department of the Inte- tor, PO. Box 31394, Je mie ea ah204 Billings, MT 60167. (vill) BLM Nevada State Office, in- cluding all District and Area Offices Within its area of jurisdiction: Regional Golicitor, Pacific Southwest Region, U.8. Department of the Interior, 2008 Cottage Way, Room : mente. CA thea8 pan, E-2763, Gacza (Ix) BLM New Mexico Btate Office, luding all District and Area Offices Within its area of jurisdiction: + Wield Solicitor, U.S. Department of the Inte- . P.O. 1M Box 1043, Banta Pe, MN 67564- (3) BLM Oregon State Office, in- Guding all District and Within its area of cog Offices 43 CER Subtitice A (10-1-sy samen, Regional Golicitor, Pacific Northwest Region, U.8. Department of the Interior. Lioyd 600 Bullding, Suite 607, 600 N.E. Multnomah Street, Portland, OR 07233; (x) BLM Utah State Office, includ- ing all District and Area Offices within its area of jurisdiction: Regional Solicitor, Intermountain Region, UB. Department of the Interior, 6201 Federal Bullding, 125 South State Street, Salt Lake City, UT 64136-1180; (xt) BLM Wyoming State Office, in- cluding. all District and Area Offices within its area of jurisdiction: Regional Solicitor, Rocky Mountain Region, U.S. Department of the Interiors, P.O. Box Pett Denver Federal Center, Denver, CO (3) If the appeal is taken from the decision of an administrative law judge, the appellant shall serve the at- torney from the Office of the Solicitor who represented the Bureau of Land Management or the Minerals Manage- ment Service at the hearing or, in the absence of a hearing, who was served with a copy of the decision by the ad- ministrative law judge. If the hearing involved a mining claim on national forest land, the appellant shall serve the attorney from the Office of Gen- eral Counsel, U.S. Department of Agri- culture, who represented the US. Forest Service at the hearing or, in the absence of a hearing, who was served with a copy of the decision by the administrative law jucge. (4) Parties shall serve the Office of the Solicitor as identified in this para- Graph until such time that a particular attorney of the Office of the Solicitor files and serves a Notice of Appear- ance or Substitution of Counsel. Thereafter, parties shall serve the Office of the Solicitor as indicated by the Notice of Appearance or Substitu- tlon of Counsel. (d) Proof of such service as required by §4.401(c) must be filed with the Board (address: Board of Land Ap- peals, Office of Hearings and Appeals, 4015 Wilson Boulevard, Arlington, VA 22203), within 18 days after service unless filed with the notice of appeal. (63 PR 13267, Apr. 32, 1088) 04416 Answers. If any party served with a notice of appeal wishes to participate in the broceedings on appeal, he must file an wrevewe we err ~~ i. answer within 30 days after service on him of the notice of appeal or state- ment of reasons where such statemen! was not included in the notice o) appeal. If additional reasons, writter arguments, or briefs are filed by the appellant, the adverse party shall have 30 days after service thereof on hir within which to answer them. The answer must state the reasons why the answerer thinks the appeal should not be sustained. Answers must be filec with the Board (address: Board ol Land Appeals, Office of Hearings ana Appeals, 4015 Wilson Boulevard, Ar- lington, VA 22203) and must be servea on the appellant, in the manner pre- scribed in § 4.401(c), not later than 15 days thereafter. Proof of such service as required by § 4.401(c), must be filed with the Board (see address above) within 16 days after service. Failure to answer will not result in a default. If an answer is not filed and served within the time required, it may be disregarded in deciding the appeal, uniess the delay in filing is waived as provided in § 4.401(a). ACTIONS BY BOARD OF LAND APPEALS 04.415 Request fer hearings on appeals lavelving questions ef fact. Either an appellant or an adverse party may, if he desires a hearing to present evidence on an issue of fact, request that the case be assigned to an administrative law judge for such oa hearing. Such a request must be made in writing and filed with the Board within 30 days after answer is due and @ copy of the request should be served on the opposing party in the case. The allowance of a request for hearing is within the discretion of ‘the Board, and the Board may, on Its own motion, refer any case to an administrative law Judge for a hearing on an issue of fact. If a hearing ts ordered, the Board will specify the issues upon which the hearing Is to be held and the hearing 4 cueen in accordance with E 439, and the general rules in Subpart B of this part. Wa i ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY /= ALASKA @@E™ =ENERGY AUTHORITY a 480 WEST TUDOR ANCHORAGE, ALASKA 99503 907 / 269-3000 FAX 907 / 269-3044 MEMORANDUM TO: Ray Alt Thomas Bay Power Authority John Hunter Copper Valley Electric Association Tom Waggoner Ketchikan Public Utilities Wes Hillman Kodiak Electric Association FROM: Stan Sieczkowski ie TTT Operations Manag DATE: November 9, 1999 SUBJECT: — Insurance Documents Transmitted for your information is the insurance company’s collection of mechanical and electrical maintenance tips. This information is intended to be a reference and supplement the power production operations. The Four Dam Pool Technical Standards are the only approved maintenance practices by the Four Dam Pool Project Maintenance Committee and shall prevail. | intend this information to be useful as a reference and a guide if appropriate. Attachment oc Dennis McCrohan, AIDEA Brad Berdoy, Chubb Insurance - - FEDERAL ENERGY REGULATORY COMMISSION ROUTING CODE WASHINGTON, D.C. 20426 OFFICIAL BUSINESS PENALTY FOR PRIVATE USE, $300 P-420 STAN SIECZKOWSKI, MANAGER ALASKA ENERGY AUTHORITY 480 WEST TODOR ROAD ANCHORAGE, AK 99503 EGEIVE NOV 24 1999 Alaska Industrial Development and Export Authority bb /b2/1/ Ch At) OA YY ool: + BILLING CODE 6717-01-M UNITED STATES OF AMERICA FEDERAL ENERGY REGULATORY COMMISSION Ketchikan Public Utilities Project No. 420-009 Alaska NOTICE OF AVAILABILITY OF DRAFT ENVIRONMENTAL ASSESSMENT (November 12, 1999) In accordance with the National Environmental Policy Act of 1969 and the Federal Energy Regulatory Commission's (Commission) regulations, 18 CFR Part 380 (Order No. 486, 52 F.R. 47897), the Office of Hydropower Licensing has reviewed the application for a new license for the Lockhart Hydroelectric Project, and has prepared a Draft Environmental Assessment (DEA). The project is located on Ketchikan Creek and Granite Basin Creek, near the City of Ketchikan, in Ketchikan Gateway Borough, Alaska. The project uses lands administered by the U.S. Forest Service in the Tongass National Forest. The DEA contains the staff's analysis of the potential environmental impacts of the project and concludes that licensing the project, with appropriate environmental protective measures, would not constitute a major federal action that would significantly affect the quality of the human environment. Copies of the DEA are available for review in the Public Reference Room, Room 2A, of the Commission's offices at 888 First Street, N.E., Washington, D.C. 20426. Any comments should be filed within 30 days from the date of this notice and should be addressed to David P. Boergers, Secretary, Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426. For further information, contact Charles Hall, Environmental Coordinator, at (202) 219-2853. Linwood A. Watson, Jr. Acting Secretary UNITED STATES OF AMERICA FEDERAL ENERGY REGULATORY COMMISSION November 12, 1999 To the Agency/Party Addressed: In accordance with the National Environmental Policy Act of 1969 and the Federal Energy Regulatory Commission's regulations, 18 CFR Part 380 (Order No. 486, 52 F.R. 47897), Office of Hydropower Licensing staff have reviewed the application for, and prepared the enclosed Draft Environmental Assessment (DEA) on the relicensing of the Ketchikan Lakes Hydroelectric Project, and has prepared a Draft Environmental Assessment (DEA). The project is located on Ketchikan Creek and Granite Basin Creek near the City of Ketchikan, in Ketchikan Gateway Borough, Alaska. The project uses , lands administered by the U.S. Forest Service in the Tongass National Forest. The DEA contains staff's analysis of the environmental impacts of the proposal and concludes that approval, with appropriate environmental protective measures, would not constitute a major federal action significantly affecting the quality of the human environment. Please submit any comments within 30 days of the date of this letter. Comments should be addressed to David P. Boergers, Secretary, Federal Energy Regulatory Commission, 888 First Street, N.E., Washington, D.C. 20426. Enclosure: Draft Environmental Assessment cc: Public Files Mailing List DRAFT ENVIRONMENTAL ASSESSMENT FOR HYDROPOWER LICENSE Ketchikan Lakes Hydroelectric Project FERC Project No. 420-009 Alaska (State Review No. AK9608-09J) Federal Energy Regulatory Commission Office of Hydropower Licensing Division of Licensing and Compliance 888 First Street, NE Washington, D.C. 20426 and USDA Forest Service Tongass National Forest Ketchikan Ranger District 3031 Tongass Avenue Ketchikan, AK 99901 yov 129 TABLE OF CONTENTS SUMMARY. «js: neers 6's 5 gore 6 ¥ storere § 2 eH ES SUEIU TS RH 83 SOME EE SRT IT ShGin wae v 1. IL. Il. IV, APPLICATION .. PURPOSE OF ACTION AND NEED FOR POWER A. Purpose of Action IB. “Need ROBBOWER «cre + 5 ere ss eras eet et Ses sore 2 Pein e © PROPOSED ACTION AND ALTERNATIVES A. KPU’s Proposal i. Project Description ae Project Operation ............. 3: Proposed Environmental Measures oats 4. Staff Recommended Modifications to KPU's Proposed Project .. 11 Ss Forest Service Required Conditions B. No Action Alternative ota C. Alternatives Considered But Eliminated from Further Consideration .. . 14 Li Federal Government Takeover, .......... 2.000 0s00eessewess oie 14 2 INonispowes, Picenge) ic zs itie « « eierte « « © inroxe 6.0 0 ners vw stewie 6 ip 14 CONSULTATION AND COMPLIANCE A. — Agency Consultation ........... B. Interventions . . Cc. Scoping ...... D. — Water Quality Certification .. E. Coastal Zone Management Act . ENVIRONMENTAIZANALYSIS occ... <5 stores crores s power ps cers As ers es 18 A. General Description of the Project Locale . B. Cumulative Impacts ................0.0eee00s pitts) s 6 = PTS 25 GwITa SE G KPU’s Proposed Action 1. Geology and Soil Resources . . 20 2. Climate, Meteorology, And Air Quality . : Bs Water RESOURCES iar; seks os Pie gs SERRE Pelee 2 cones weet = 4. Aquatic Resources 5 Terrestrial Resources ..... ate - 66 6. Endangered, Threatened, and Sensitive Species . 69 fie) AOSUNCUICS) ora <ivtcyoiy 2s eras = elas 2s Seto s eae s = ees coors 73 8. Caltitral Resogrces! .:< «.s tres +5 gr is 5 ars 25 3 ae £89882 sem 74 9. Recreational Resources 10. Land Use 11. Socioeconomics D. No Action Alternative VI. DEVELOPMENTAL ANALYSIS ...........0.0.0 00sec eve cence eee 84 A. Power and Economic Benefits of the Project . . 84 B. Cost of Environmental Enhancement Measures . - 86 C. Pollution Abatement Benefits .......... ctomors’ 96 azeraaeney 93 VII. COMPREHENSIVE DEVELOPMENT AND RECOMMENDED ALTERNATIVE v5 RARTOST IASB MAGTLT S BiavEsT ES eS aoa & w noanl WiSioresele mSRAIaTelw winners 66 94 VIII. CONSISTENCY WITH COMPREHENSIVE PLANS ................-.. 99 A. Tongass National Forest Land and Resource Management Plan . 100 B. North American Waterfowl Management Plan........... - 100 C. Alaska Outdoor Recreation Plan .........0000sssveesssovsecsees 101 IX. RECOMMENDATIONS OF FISH AND WILDLIFE AGENCIES ........ 101 X. FINDING OF NO SIGNIFICANT IMPACT XI. LITERATURE CITED XII. LIST OF PREPARERS .. List of Figures Figure Page Figure 1. Project Location Map . 22 Figure 2. Project AreaMap......... 23 Figure 3. Profile of pipelines and tunnels . . 25 Figure 4. Ketchikan Lakes elevation history .............. 00. ce eee eeeeeee 28 Figure 5. | Mean Monthly Precipitation in Ketchikan . . 28 Figure 6. Aquatic resources map Table 1. Table 2. Table 3. Table 4. Table 5. Table 6. Table 7. Table 8. Table 9. Table 10. Table 11. Table 12. Table 13. Table 14. Table 15. Table 16. Table 17. Table 18. Table 19. Table 20. Table 21. Table 22. Table 23. Table 24. Table 25. Appendix A List of Tables Table Page Project Land Ownership 8 Basic Hydrologic Data for the Ketchikan Lakes Project . . . 26 Annual and monthly inflow data (cfs) for Ketchikan Lakes . .27 Annual and monthly flow data (cfs) for Granite Basin Creek . . 29 Estimated flow depths (feet) in Ketchikan Creek below the tailrace .... 31 Computed average unregulated monthly flows for Ketchikan Creek below POwerh tise (1993 = 1995) sires 3 5 sioreses sarge vo soneiels soemni ve winiaes ADF&G's instream flow reservation request Species list and codes for fish occurring within the Ketchikan Creek watershed Salmon escapement surveys (1978 - 1995) . . Ketchikan Creek fish species periodicity chart ..................... 42 Sport fish harvested by species in Ketchikan Creek (1990 to 1994) .... 44 Summary of snorkeling and fish trapping results in the Ketchikan Creek system August and September 1997 and April 1998 ................ 47 Summary of key aquatic habitat parameters in the Ketchikan Creek system August and September 1997 ..49 How the Ketchikan Lakes Project affects water temperatures. 55 Ramping rates recommended by ADF&G .............0 20000 61 Estimated change in depths with a ramping rate of 30 cfs/hour for two stream channels in Ketchikan Creek below the tailrace .................6.. Dominant Vegetated Communities in the Project Vicinity . Wetland Types Within the Project Vicinity . Species of Concern that Could Occur in the Project Area ............ U.S. Forest Service Sensitive Species That Could Occur in the Project Area Taka! ss GakeNaset > feeHeoh cs ONSKo¥S] oie “HeNatet 510 iovaHeTo+ eo ov EOMsFAr ois Redaio?- ss lokexers- 6 “oRezsi 71 Estimated capital costs and levelized annual costs of alternative water quality enhancement/mitigation measures ...........60.0 000 eee e sence ees 87 Estimated capital costs and levelized annual costs of stream flow gaging alternatives 6.0.0.0... c ccc c cece cece e eee een e teen ene eee 89 Estimated capital costs and levelized annual costs of alternative fish habitat Onan cements 5 sasis ws x sissies 5 ores 059 eerie 05 «Meza wn 9 gaosere vin wuenes« 0 intraers 92 Estimated capital costs and levelized annual costs of alternative Ketchikan Lakes enhancement measures ssass) ¢ ¢ siams ss afew: ¢ <5 omens «ss omens ¢ 25 ome. 93 Analysis of fish and wildlife agencies' recommendations ........... 103 Appendices aes Forest Service Section 4(e) Recommendations iv SUMMARY Ketchikan Public Utility (KPU) proposes to continue to operate the existing Ketchikan Lakes Hydroelectric Project (project) located on Ketchikan Creek in the City of Ketchikan on Revillagigedo Island in Southeastern Alaska. The project has undergone several modifications since it was first constructed in 1903. Now, with a generation capacity of 4,200 kilowatts (kW), this combined purpose project supplies part of the electricity needs of the City of Ketchikan and all of its municipal water supply requirements. Parts of the project occupy federal lands administered by the U.S. Forest Service (FS) and the Bureau of Land Management (BLM). The FS lands are managed by the Ketchikan Ranger District of the Tongass National Forest. This draft environmental assessment (DEA) is a cooperative undertaking between the FS and the Federal Energy Regulatory Commission (the Commission or FERC). KPU followed the Commission's alternative licensing procedures and filed an applicant prepared environmental assessment with its application for a new license in June, 1998. KPU proposes no capacity or operating changes, but does propose a number of measures for the protection and enhancement of environmental resources. This DEA analyzes the effects of continued project operation and recommends conditions for a new license for the project. In addition to KPU’s proposal, we consider two alternatives: () KPU's proposal with staff modifications and (2) no-action. Based on our analysis, we recommend licensing the project as proposed by KPU with staff modifications. The recommended staff modifications include or are based in part on recommendations made by the federal and state resource agencies that have an interest in the resources that may be affected by continued project operation. The measures we recommend include: monitoring flows and water temperature; providing minimum instream flows for fish; setting limits on the rate project flows are changed under normal operating conditions (ramping rates); making fish habitat improvements in Ketchikan Creek; providing for future measures to maintain and enhance fishery resources and recreational use of project lands and waters after the project is retired, or when water treatment facilities are constructed (removing the necessity of restricting public access for the protection of drinking water quality); and measures to protect resources, including cultural resources and values, from damages caused by any operating or maintenance actions that may arise during the term of a new license. On the basis of our independent analysis, we conclude that issuing a new license for the project, with the environmental measures that we recommend, would not be a major federal action significantly affecting the quality of the human environment. DRAFT ENVIRONMENTAL ASSESSMENT Federal Energy Regulatory Commission Office of Hydropower Licensing Division of Project Review Ketchikan Lakes Hydroelectric Project FERC No. 420-000-Alaska I. APPLICATION The City of Ketchikan, Alaska under the name of Ketchikan Public Utilities (KPU) applies to the Federal Energy Regulatory Commission (Commission) fora new license for the Ketchikan Lakes Hydroelectric Project (project or Ketchikan Lakes Project). The Ketchikan Lakes Project is located on Ketchikan Creek in Southeast Alaska, within and adjacent to the City of Ketchikan, Alaska (figure 1). Figure 2 shows the location of project facilities, which extend north from the city, across state lands, and into National Forest lands administered by the U.S. Forest Service, Tongass National Forest (FS), and lands managed by the Bureau of Land Management (BLM). Under the Federal Power Act (FPA), the portion of the Tongass National Forest within the project boundary is reserved by the federal government for power development. The 4.2-megawatt (MW) project is an existing combined-purpose facility operated by KPU. The project uses the runoff to Ketchikan Lakes and storage in Ketchikan Lakes, together with run-of-river flow diverted from Granite Basin Creek, to generate electricity and to provide a water source for the Ketchikan municipal water system. | By an Act of Congress dated July 27, 1939, the municipal water supply is protected jointly by the City of Ketchikan and the FS. The Act states that this land is "...reserved from all forms of location, entry, or appropriation, under the mineral or nonmineral land laws of the United States, and set aside as municipal water-supply reserves for the use and benefit of the people of the city of Ketchikan, a municipal corporation of the Territory of Alaska The Ketchikan Lakes Project is the modern product of “numerous improvements to the first hydroelectric public utility in Alaska. The early workings were first constructed at Ketchikan in 1903, as noted in Water Powers of Southeast Alaska, a report prepared in 1947 by the Federal Power Commission and the FS. The original license was issued to the Citizens’ Light, Power, and Water Company in 1928. The City of Ketchikan purchased the project in 1935. The original license for the project expired on June 30, 1970. The project continued operating under annual licenses until a new license was issued on June 30, 1982. —d TONGAS§ NATIONAL FOREST ISTATE MENTAL HEALTH TRUST 13 GRANITE BASIN Figure 1. — Project Location Map (Source: KPU, 1998) KPU elected to use the Commission’s alternative licensing process and filed an applicant-prepared environmental assessment (APEA) with its application for a new license. In a December 16, 1996 Letter of Understanding, the Commission and the FS agfeed to cooperate in the preparation of a joint environmental assessment process to support each agency’s decisions on re-licensing as required by the National Environmental Policy Act (NEPA). 3 Il. PURPOSE OF ACTION AND NEED FOR POWER A. Purpose of Action The Commission must decide whether to relicense the project, and what conditions should be placed on any license issued. The FS must decide what license conditions are needed for the adequate protection of National Forest System lands, if the Commission grants a new license. In this EA, we assess the environmental and economic effects of: (1) operating the project as proposed by KPU, (2) the No Action Alternative, and (3) operating the project with staff-recommended modifications to the project as proposed by KPU. We also assess alternative generating capacities, decommissioning the project, federal government takeover, and non-power license. B. Need For Power Hydroelectric energy is critical to the Ketchikan community due to its relatively low cost. The only other electric energy available is from diesel generation, which is much more expensive due to fuel and operating costs. KPU strives to generate as much electricity as possible with hydropower, and as little as possible with diesel. The total annual energy available from the project ranges from 16 to 23 million kilowatt hours (kWh) on an annual basis. Additional generation resources have been added to the KPU system to accommodate load growth. The total electric energy generated at all of the plants owned or operated by KPU in 1995 was 160 million kWh and of this amount 17.4 million kWh was generated at the Ketchikan Lakes powerhouse. KPU owns or operates additional hydroelectric power facilities at Beaver Falls, Silvis Lake, and Swan Lake. The total amount of hydroelectric power generated by KPU in 1995 was 122 million kWh, with Ketchikan Lakes providing about 14 percent of this amount. KPU also operates three diesel generator sets at the Bailey powerhouse to supplement the hydroelectric generation as required. The other hydropower operations are not restricted by the domestic water supply constraints that influence operation of Ketchikan Lakes. Therefore, KPU uses other hydropower facilities (Silvis Lake and Beaver Falls) and Swan Lake (operated by KPU) for load following; Ketchikan Lakes is operated to produce energy while maintaining relatively stable water level in Fawn Lake. Diesel generation is significantly more expensive than hydropower due primarily to the fuel costs. Therefore, it is desirable to generate as much electricity as possible with hydroelectric power and to minimize diesel generation. However, the operators must take 4 precautions not to deplete water storage too severely before running the diesels because there is not enough diesel capacity to cover the full load. There is presently 12,500 kW of diesel capacity. System load peaks at 30,000 kW. The operational adjustments are determined by evaluation of all the data available to the operators including reservoir levels, time of day, precipitation in progress, and time of year. The total hydroelectric capacity owned or operated by KPU is 45,700 kW but generation at this level cannot be sustained. The amount of hydroelectric capacity available to KPU is dependent on precipitation and reservoir levels. The plant factor (percentage of power generated versus rated capacity of the plants) for all hydroelectric power combined in 1995 was 41 percent. This was with very little water spilled and produced a total of 122 million kWh. Total KPU generation in 1995 was 160 million kWh, with 38 million kWh from diesel. The overall operating mode is to generate as much as possible with hydroelectric sources (avoiding spills) while taking care to preserve enough water in storage to always have enough hydroelectric energy available to meet total load by the combination of hydropower and diesel generation. This overall objective, and the need to provide reliable municipal water, prescribe the operation of the project. II. PROPOSED ACTION AND ALTERNATIVES A. KPU’s Proposal i; Project Description Subsequent to the 1947 Water Powers report, there have been modifications to the project, however, the basic arrangement remains the same as it was in 1947. Figure 2 shows key project components including the Ketchikan Lakes, the Granite Basin diversion, the Fawn Lake forebay and power tunnel, access roads and the powerhouse. Enhancements have been added since the original construction to optimize use of the water resource, to provide for reliable municipal water supply, to provide for a minimum flow in Ketchikan Creek, and to comply with basic needs for modernization. The project uses the runoff to Ketchikan Lakes and storage in Ketchikan Lakes, together with run-of-river flow diverted from Granite Basin Creek, to generate electricity and to provide a water source for the Ketchikan municipal water system. Ketchikan Lakes are natural lakes which have been increased in capacity by construction of a dam at the outlet of the lower lake. No changes are proposed to the project which consists of the following features: Ketchikan Lakes, Dam and Spillway: The Ketchikan Lakes are now interconnected by a channel which has been deepened between the two lakes to expedite 5 flow from the upper to the lower lake. The upper and lower lakes are about equal in surface area, with a total combined surface area of 632 acres. The dam is a rockfill embankment with a wooden core wall. The total crest length is 1,163 feet; the maximum height is 30 feet. The spillway crest elevation is 348 feet; the crest height of the dam is 355 feet. The spillway was reconstructed in 1978, to pass the probable maximum flood. The spillway is a concrete crest weir, 103 feet in width. The spillway chute beyond the concrete apron is excavated in bedrock and discharges to Ketchikan Creek. Fawn Lake: Fawn Lake serves as the forebay to the tunnel penstock. It has a maximum surface area of 3.1 acres and a gross storage volume of about 40 acre-feet. Fawn Lake is created by two rockfill dams: the main dam is about 385 feet long and 22 feet high; and the smaller dam is about 200 feet long and 15 feet high. The top of both dams is at elevation 352 feet. Both dams are rockfill with wooden cores. There is a spillway cut in rock at the west end of the smaller (north) dam, discharging overflow back to Ketchikan Creek. The spillway crest is at elevation 348 feet, which is the same as the Ketchikan Lakes spillway. Ketchikan Lake to Fawn Lake Conveyance: The conveyance from Ketchikan Lake to Fawn Lake consists of a combination of pipelines and tunnels. Two 4-foot by 6.5-foot parallel tunnels, one 280 feet long and the other 300 feet long, convey the water from an invert elevation of 310 feet in Ketchikan Lakes to two 1,800-foot-long, 54-inch diameter above ground conduits. One of the pipelines was a 54-inch wood stave pipe that was recently replaced with a 54-inch ductile steel penstock. The other is a 54-inch concrete cylinder pipe. Each of the two conduits can be isolated by valves at the tunnel portal and the Ketchikan Lakes dam. The pipelines connect through a concrete vault to a 1,127-foot-long tunnel having a cross section of 7 feet by 8 feet and terminating in Fawn Lake below the normal low water level. This conveyance operates as an inverted siphon and the capacity is dependant on the relative water levels in Ketchikan Lakes and Fawn Lake. The system is designed to convey an average flow of 120 cubic feet per second (cfs) during low water conditions. Granite Basin Diversion: The Granite Basin diversion structure is a 30-foot-long, 6-foot-high concrete dam equipped with three roller gates which can be used to sluice out the impoundment near the diversion intake, to control the amount of flow entering the diversion, or to pass the flow by the diversion gate. The top of the roller gates is at elevation 464 feet. The Granite Basin diversion has no useable storage. Granite Basin Diversion to Fawn Lake Conveyance: A 1,170-foot-long, 5-foot by 7-foot cross section tunnel with an inlet just upstream of the dam at an invert elevation of 457 feet and an outlet elevation of 442 feet discharges diverted Granite Basin Creek flows into a 150-foot-long natural drainageway to Fawn Lake. There is a concrete flume at about the middle of the tunnel, crossing an unnamed channel. This flume was previously 6 a wooden structure but was recently replaced with concrete. The maximum capacity of this diversion and the conveyance to Fawn Lake is about 160 cfs but it seldom reaches capacity. Power Tunnel: Water from the Fawn Lake forebay is conveyed to the powerhouse through a 7-foot by 8-foot in cross section, 3,473-foot-long tunnel. There are two sections of tunnel on a shallow grade, 0.5 percent and 1.0 percent, with a 427-foot section in the middle at 42 percent grade. About 360 feet ahead of the powerhouse, the tunnel is terminated with a concrete plug. The plug is penetrated by three, 36-inch-diameter ductile iron penstocks running to the powerhouse, and two, 12-inch-diameter ductile iron water lines which run to the municipal water supply chlorination facility. The tunnel inlet structure is equipped with a slide gate at the forebay. The invert of the tunnel is 305 feet at the inlet and 95 feet at the concrete bulkhead. Powerhouse: The powerhouse is located on the west side of Ketchikan Creek just north of Fair Street in the City of Ketchikan. There are three turbine generator sets of similar design in the powerhouse. The turbines are horizontal Francis type directly connected to the generators. Each unit is rated 1,400 kW, giving a total installed capacity of 4,200 kW. The plant is remotely controlled from KPU’s Control and Dispatch Center at the Bailey power plant in Ketchikan. The flow rate through each unit at full capacity is estimated to be 75 cfs. Access Roads: An access road beginning in the City of Ketchikan leads to Fawn Lake and then, through FS lands to Ketchikan Lake. Recently, the lower portion of this road was relocated to remove it from private land. As a result, a new survey was conducted. This survey reflects the new location of the access road and resulting revised project boundary up to the Ketchikan Lakes (see figure 2). The access road is controlled by a gate, which is locked to prevent public access. A side road through FS lands provides access to the Granite Basin diversion. The total length of the access road is about 2 miles. Transmission: A substation on Fair Street, adjacent to the powerhouse is part of KPU’s distribution system and not under the Commission’s jurisdiction. Only the generator leads to the substation are considered a part of the project and under the Commission’s jurisdiction. The generator bus voltage is 4.16 kilovolt (kV). There is a 5,000 kilovolt amperes (kVA) transformer, stepping the generator voltage up from 4.16 kV to 12.47 kV, which is the distribution voltage. Project Lands: Components of the project involve about 863 acres located within the project boundaries shown in figure 2. Lands of the United States total about 826 acres. The northern portion of the project, beginning about half way between Fawn Lake and Ketchikan Lakes and including the Ketchikan Lakes, is located on about 778 acres of 7 federal lands administered by the FS (Tongass National Forest). There are also about 48 acres administered by the BLM. Non-federal lands (City of Ketchikan and private ownership) make up about 37 acres. Table 1 summarizes the amount and ownership of project lands, much of which is also located within the area reserved for municipal water supply for the City of Ketchikan. Table 1. Project Land Ownership (Source: KPU, 1998) FEDERAL NON-FEDERAL Tongass National Forest BLM Private | Ketchikan | TOTAL | PARCEL (Acres) | (Acres) | (Acres) (Acres) (Acres) Ketchikan Lakes 744.94 (1) - - 26.86 (1) | 771.80 Forebay-Diversion 33.00 (1) 37.96 (1) | _— = 70.96 Power Tunnel _ | 5.18 (2) 1.27 (3) 0.10 6.55 Powerhouse _ _ _ | 4.70 4.70 Access Road _ 5.08 3.75 (4) 0.08 8.91 Total | 777.94 48.22 5.02 31.74 862.92 (1) Wholly within and covered by U.S.C. Act of 7/27/39. (2) 0.92 acres within and covered by U.S.C. Act of 7/27/39. (3) Wholly within U.S. Survey No. 2635. (4) 2.64 acres within U.S. Survey No. 2635. 2. Project Operation To maintain the Project's combined mission to generate electricity and to provide water to the Ketchikan municipal water system, water from Ketchikan Lakes and the Granite Basin diversion are conveyed to Fawn Lake, which is a small manmade lake. Fawn Lake is the forebay to the tunnel and penstock system of the hydroelectric plant (powerhouse). About 360 feet above the powerhouse, three 36-inch steel penstocks (pipes) tap the water behind a concrete plug in the tunnel. In addition to the three penstocks, two 12- inch water lines lead from the tunnel plug to the municipal water supply. The municipal water does not pass through the power plant. The tailrace from the powerhouse discharges back to Ketchikan Creek just north of the bridge on Fair Street. Part of the tailrace flow is diverted directly to City Park and the Deer Mountain Fish Hatchery on the south side of Fair Street. This flow returns to Ketchikan Creek south of the bridge on Fair Street. The Ketchikan Lakes power plant is remotely operated by the Central Control and Dispatch Center at the Bailey power plant in downtown Ketchikan. The Ketchikan Lakes operating criteria is based upon domestic water supply requirements together with optimizing electrical energy production. This results in the plant being utilized primarily for energy production and very little load following. The power supply objective is to utilize all available water for electric energy production. The water supply objective is to maintain constant supply pressure and good water quality, which is achieved by maintaining a stable water level in Fawn Lake. The operating criteria which satisfies both of these criteria is to maintain the water level in Fawn Lake at or above 325 feet elevation; and to avoid rapidly changing the water level in Fawn Lake. This can be accomplished by discharging from Fawn Lake at the same rate at which water comes in from both Granite Basin Creek and Ketchikan Lakes, with the water level at an elevation of 325 feet or more. Inflow from Granite Basin Creek is run-of-river. Inflow from Ketchikan Lakes varies with the relative water levels in Ketchikan Lakes and Fawn Lake. The Ketchikan Lakes plant is normally operated so that the water level in Fawn Lake is near 325 feet; with the allowance that it can range up to the spillway elevation of 348 feet. The rate of change is held down to a rate which avoids turbidity introduced from turbulence in the reservoir. The water level at Fawn Lake, and resulting pressure in the penstocks, is significant to the operation of the municipal water system. From the water supply viewpoint, it is preferable to maintain constant pressure in the penstocks. This influences the operation of the hydropower facility. The system operators have achieved a high degree of success in utilizing all of the water, which means avoiding spills from the reservoir, in conjunction with meeting the municipal water supply requirements. KPU has alternative generation resources which are capable and preferable to Ketchikan Lakes for peaking capacity and Automatic Generation Control (AGC). Therefore, predominantly operating the Ketchikan Lakes power plant as an energy production unit in conjunction with the municipal water supply is compatible with the overall needs of KPU. In addition to providing hydroelectric energy and municipal water, the project is operated to assure that there is a minimum flow of at least 35 cfs returned to Ketchikan Creek. This includes flow diverted to the City Park and Deer Mountain Fish Hatchery in addition to flow returned directly to Ketchikan Creek from the tailrace of the powerhouse. The bypassed reach of stream between Ketchikan Lakes and the return flow from the powerhouse to Ketchikan Creek is 8,100 feet of stream. This reach of stream is rugged, with minimal access, and a number of physical barriers that prevent upstream fish movement. There is about 2,100 feet of Granite Basin Creek bypassed between the diversion and the confluence with Ketchikan Creek. This section is also rugged with many small waterfalls. 3. Proposed Environmental Measures KPU proposes to incorporate the following environmental measures into the project: . Continue to operate and maintain the oily water separator installed in the powerhouse in 1997 to remove all oil from water before it is discharged into the project tailrace. . KPU would continue to manage the watershed to protect the water quality and would continue to operate Fawn Lake to minimize turbidity to protect the water quality. . KPU would install remote water level monitoring equipment at Fawn Lake to allow greater lead times for making flow ramping decisions which would in turn enable a decrease in ramping rates. . KPU would continue to provide 4.5-cfs flow to the Deer Mountain Fish Hatchery. ° KPU would continue to maintain the 35-cfs minimum flow at the tailrace. . KPU would install weirs below both the Ketchikan Lakes dam and the Granite Basin diversion to monitor the seepage that currently occurs from the Ketchikan Lakes dam and the Granite Creek diversion and, if future repairs would reduce seepage, commits to maintain through some other means an amount of flow equal to the amount of the seepage flows measured during the first two years of seepage monitoring. . If KPU ever plans to improve the Ketchikan Lakes dam, they would monitor the temperature of the seepage flows over a one-year period prior to making any improvements. 10 ° KPU would conduct flow monitoring for five years just upstream of the tailrace to measure seasonal variability of flows in the bypassed reach of Ketchikan Creek. . KPU would donate $15,000 to Alaska Department of Fish & Game (ADF&G) to remove the five-foot barrier on Ketchikan Creek downstream of Rainbow Falls, to develop and implement a plan for improving fish rearing habitat in Ketchikan Creek between the tailrace and the existing fish ladder, and/or to improve fish access to Schoenbar Creek. . If public recreation access is opened to Ketchikan Lakes, KPU would consult with ADF&G about conducting fish studies in Ketchikan Lakes. . KPU would calculate hourly flows through the turbines by statistically correlating power output (kW) to flow rates (cfs) and use this information to consider alternate water level fluctuation (ramping rate) options that do not negatively affect project operations and would be more beneficial to the fishery downstream of the tailrace. . Use of the Deer Mountain Trail within the Ketchikan Lakes watershed would continue. . If KPU adds water filtration to its water treatment facility, KPU would consult with the FS about reopening the Ketchikan Lakes watershed to public recreation. 4. Staff Recommended Modifications to KPU's Proposed Project After considering comments and recommendations of government agencies, non- government organizations, and the public, the staff recommends adopting KPU's proposed project, with the following additions or modifications. . Monitor the temperature of leakage flows from project dams for a period of up to five years. . Maintain a continuous minium flow through the project of 47 cfs, except in the event of a plant power trip or for the purpose of protecting the water supply purposes of the project, when the flow may be reduced to 35 cfs. . Limit ramping rates to obtain the following maximum stage changes in Ketchikan Creek downstream from the project tailrace: February 16 to May 31 1 inch per hour during daylight hours; 2 inches per hour maximum at night 11 June 1 to September 15 1 inch per hour maximum September 16 to February 15 2 inches per hour maximum . Develop and implement a plan to monitor project flows and ramping rates, in consultation with NMFS, F WS, FS, and ADF&G. . Develop and implement a fisheries habitat enhancement plan showing the detailed design and feasibility of: (1) removing the five-foot barrier on Ketchikan Creek, (2) improving access to (but not passage through) the Shoenbar Creek culvert, (3) enhancing 2,000 square feet of salmonid rearing habitat, and (4) extending the existing fish ladder on Ketchikan Creek. The plan shall be developed , in consultation with NMFS, FWS, FS, and ADF&G. . Adopt appropriate measures if any cultural resources are disturbed during future project operation and maintenance activities. 5. Forest Service Required Conditions Appendix A is the August 18, 1999, preliminary license terms and conditions filed by the FS under section 4(e) of the FPA. The FS' final terms and conditions, which will be issued by the FS and included in the final EA, would become mandatory in any license issued by the Commission for the Ketchikan Lakes Project. The following summarizes the FS' preliminary license conditions. Conditions 103, 104 and 105 are standard FS conditions dealing with general land management issues and dispute resolution. Six of the conditions would require KPU to prepare a plan and/or consult with the FS and resource agencies prior to commencing any new construction or modification of existing facilities. These six conditions are for the protection of natural heritage resources (condition 110), visual resources (condition 118) and sensitive plant resources (condition 121), and for the management of erosion (condition 117), solid waste and wastewater (condition 126), and hazardous waste (condition 127). Four of the FS preliminary conditions deal with project-specific lands issues. Condition 122 requires a protocol for providing access to FS personnel to project lands; condition 123 requires KPU to obtain an access easement on non-federal lands for use by the FS and the public; condition 124 requires KPU to survey an existing project road and amend the project boundaries to reflect the true location of the road; and condition 125 provides for the cessation of the licensees rights to project lands and waters at the end of the license period, unless a new license or annual licenses are obtained. 12 Four of the FS conditions are the same or similar to recommendations for measures made by KPU or the fishery agencies. If and when recreational access is allowed to Ketchikan Lakes, Condition 111 requires KPU to file and implement a comprehensive study plan to manage fish populations and habitat in and above Ketchikan Lakes. Condition 112 requires KPU to provide and maintain gages and gaging stations for measuring stream flow, reservoir storage and energy generation. Condition 113 requires monitoring of the leakage flows and temperatures from Ketchikan Lakes dam and Granite Basin Creek diversion dam, to establish a minimum flow and temperature criteria to be maintained by KPU if it ever decides to repair those leaks; condition 114 requires KPU to operate Fawn Lake to minimize turbidity and to continue operating an oily water separator at the powerhouse for the protection of water quality. Conditions 115 and 116 are re-opener conditions providing for potential future modifications to project facilities or operations for the benefit of fish and wildlife resources if ordered by the Commission upon its own motion or upon the recommendation of the Secretary of Agriculture or the ADF&G (condition 115), or constructed by the United States at its own expense (condition 116). Condition 119 requires KPU to undertake a recreation study and implement the resulting recommendations for recreational use of the Ketchikan Lakes watershed, when KPU decides to provide water supply treatment, thereby ending the need to restrict access to this area. The FS and KPU negotiated this recommendation during the prefiling consultation of the applicant-prepared EA process. Condition 120 requires KPU to work with the resource management agencies to develop a Resource Coordination Plan for the purpose of documenting mutual agreements concerning efficient and economical project operation and maintenance, and construction of future facilities. The objectives of this plan are to: (1) facilitate ongoing communication among KPU, and all the resource management agencies regarding project-related operation and maintenance activities and construction projects; and (2) ensure that KPU field personnel and contractors conduct future project operation, maintenance, and construction without unduly affecting natural and cultural resources. B. No Action Alternative Under the no action alternative, the project would continue to operate under the terms and conditions of the existing license, and no new environmental protection, mitigation, or enhancement measures would be implemented. We use this alternative to establish the baseline environmental condition for comparison with other alternatives. 13 C. Alternatives Considered But Eliminated from Further Consideration 1. Federal Government Takeover Public Law 278, enacted in 1953, 67 Stat. 587, made the provisions of the Federal Power Act pertaining to federal takeover inapplicable to projects owned by municipalities. Therefore, federal takeover is not a reasonable alternative. 2. Non-power License A non-power license is a temporary license which the Commission would terminate whenever it determines that another governmental agency will assume regulatory authority and supervision over the lands and facilities covered by the non- power license. At this point, no agency has suggested a willingness or ability to do so. No party has sought a non-power license and we have no basis for concluding that the project should no longer be used to produce power. Thus, we do not consider non-power licensing a realistic alternative to relicensing in this circumstance. IV. CONSULTATION AND COMPLIANCE A. — Agency Consultation The Commission’s regulations require prospective applicants to consult with state and federal environmental resource agencies and the public before filing a license application. This consultation is also the first step in complying with the Fish and Wildlife Coordination Act, the Endangered Species Act, the National Historic Preservation Act, and other federal statutes. Pre-filing consultation must be complete and documented in accordance with the Commission’s regulations. Public notification and requests for comments were issued: 1) with the Notice of Intent to file a relicense application filed with the Commission on June 1, 1995 and published in the Federal Register; 2) at the time of public scoping as described below; 3) during the preparation of study plans; 4) when the draft study reports were completed; and 5) when the applicant prepared preliminary draft EA (PDEA) and draft application were completed. In addition, the Commission issued a notice accepting the application and requesting comments and agency-recommended license terms and conditions on January 13, 1999. The following entities filed comments: 14 Entity Date U.S. Department of the Interior (Interior) March 5, 1999 National Marine Fisheries Service (NMFS) March 8, 1999 Alaska Department of Fish & Game (ADF&G) March 11, 1999 Alaska Department of Natural Resources (ADNR) April 9, 1999 U.S. Department of Agriculture, Forest Service (FS) April 21, 1999 In letters dated June 4, 1999 and August 18, 1999, FS filed revisions to its preliminary recommended terms and conditions. In letters dated June 10, 1999 and August 13, 1999, KPU filed a letter commenting on some of the agency recommended terms and conditions. B. Interventions In addition to filing comments, organizations and individuals may petition to intervene and become a party to the licensing proceedings. No one petitioned for intervenor status in this proceeding. C. Scoping On April 3, 1996, KPU sent a letter to interested parties providing notice that they had initiated the process to relicense the Ketchikan Lakes Project. KPU indicated its intention to prepare, and file with its license application, a PDEA pursuant to section 2403(b) of the Energy Policy Act of 1992. KPU requested that certain of the Commission’s post-filing requirements for scoping, and requests for agency and public comments be moved to the pre-filing stages. The Commission approved the use of this process and KPU advised interested parties that under this process, opportunities for commenting would not decrease, but the timing would change and some information traditionally found in the license application would instead be found in the PDEA. On August 15, 1996, KPU sent to the agencies, Tribes and interested parties an Initial Consultation Package/Scoping Document 1 (ICP/SD1), which describes project operations and environmental resources that the project may affect. In addition to written comments solicited by the ICP/SD1, two public scoping meetings were held on September 18, 1996, at 1:00 p.m. and 7:00 p.m. at KPU’s office in Ketchikan, Alaska. A site visit of the project was conducted on September 19, 1996. 15 Commission staff, Greystone representatives, representatives of the FS and the Alaska Department of Fish & Game (ADF&G) attended the two meetings. A transcript of the meetings was recorded to document attendants comments. The following agencies filed written comments in date order: Entity Date Alaska Division of Governmental Coordination (ADGC) August 20, 1996 U.S. Army Corps of Engineers (COE) September 23, 1996 Alaska State Historic Preservation Officer (ASHPO) September 24, 1996 Alaska Department of Fish and Game (ADF&G) November 19, 1996 Tongass National Forest(Forest Service) December 4, 1996 U.S. Fish and Wildlife Service (FWS) December 5, 1996 Following the initial consultation/scoping meeting and a comment period, the issues raised were reviewed and a summary of the comments was developed and presented in Scoping Document 2 (SD2). Based on the results of the scoping process, SD2 was prepared and distributed in April 1997. The identified environmental concerns are addressed in appropriate sections of this EA. Those issues include the following: Wetland: . Potential effects of the Project’s flow modifications on wetlands should be assessed in the bypassed reaches of Granite and Ketchikan Creeks, and in Ketchikan Creek below the tailrace. . Potential effects of the Project’s flow modifications on aquatic habitat in the bypassed reaches of Ketchikan and Granite Creeks. Specifically, there is concern regarding the potential elimination of instream flows throughout the Ketchikan Creek bypassed reach (there is concern about the lack of a project flow regime for the bypassed reach). s 8 Potential effects of project facilities and operations on aquatic habitat and fish migration below the powerhouse. There is concern that the current flow regime (volume, variability and timing) is inadequate and is affecting fish resources and spawning habitat of Ketchikan Creek below the 16 powerhouse. There is specific concern about the potential for stranding of fry due to flow being reduced during critical times. . Potential Project-related modification of stream temperatures and effects on the fishery in Ketchikan Creek and adjacent fish hatchery. . Potential effects of flow and lake level fluctuations on the fishery in Ketchikan Lakes, particularly the effects on brook trout spawning. Wildlife . Potential mortality to birds via bird collisions with the powerline running from the powerhouse to the city (Note: the powerline is not part of this project, but is included here because it was brought up as an issue.). Rari reatened or Endangered Species . Potential effects of continued project operations on any threatened, endangered, and sensitive plant and animal species. Water Resources . Potential effects of project operation and maintenance activities on turbidity and water temperature downstream of the hydroelectric plant. . Effects of project operations on water quality for municipal water supply purposes. Recreation . Potential effects of restricting access and use of the Ketchikan Lakes (as required by EPA to protect water supply) on recreational opportunities in the area - (Note: This issue is not directly related to the hydropower project - The same restrictions would apply whether or not hydropower operation continues.). Cultural and Historic Sites . Potential for project facilities to be eligible for inclusion in the National Register of Historic Places. As part of defining the scope of this EA, we considered the boundaries of the potentially affected area for each resource or environmental issue. For physical and biological resources, the study area was limited to the Ketchikan Lakes watershed. Socioeconomic resources included the Ketchikan borough. 17 D. Water Quality Certification KPU requested 401 certification from the Alaska Department of Environmental Conservation (ADEC) on May 30, 1997. A description of the Ketchikan Lakes Project operations and a summary of water quality data derived from the inlet to the municipal water supply was attached to that request. If the ADEC doesn't act on the request within one year from the date they received it, certification is deemed waived under section 4.380 f)(7)(ii) of t he commission's regulations. Since the ADEC has not acted on KPU's request, certification is deemed waived. E. Coastal Zone Management Act Ina letter from the Alaska Division of Governmental Coordination (ADGC) dated October 8, 1999, FERC was notified that the state is in the process of reviewing the project for consistency with the Alaska Coastal Management Program (ACMP). V. ENVIRONMENTAL ANALYSIS This section begins with a general description of the project area, followed by a discussion of resources that could be cumulatively affected by the project and other developmental uses. Following the cumulative analysis section, is a detailed analysis of the environmental effects of the alternatives on each resource area. The analysis looks at: (1) the effects of the project as proposed by KPU; (2) agency and staff recommended environmental enhancements, and (3) the No Action alternative. A. General Description of the Project Locale Ketchikan is located in southeast Alaska on the south side of Revillagigedo Island, which has an area of 1,168 square miles. The project is located on Ketchikan Creek, which drains into the East Channel of Tongass Narrows, which connects to the Pacific Ocean through the Revillagigedo Channel and the Clarence Strait. The watershed for the Lower and Upper Ketchikan Lakes is about 8.15 square miles. Including the Granite Creek Basin above the diversion dam, the total drainage area tributary to the Fawn Lake forebay is about 11.2 square miles. The drainage basin is about 4 miles long and 2.5 miles wide. The topography of the Ketchikan Creek watershed is typical of southeast Alaska, with steep slopes rising from sea level. Slopes are typically heavily forested with muskeg, occurring in low, stream-bottom areas. During the Pleistocene Epoch, glaciers advanced over the entire Revillagigedo Island region at least once, and probably several times. The last glacial period ended about 13,000 years ago. Combined glaciation and fluvial erosion 18 resulted in the formation of present landforms as U-shaped valleys; elevated terraces; elongated lakes, such as the Ketchikan Lakes; and deeply scoured embankments, inlets, and passages. B. Cumulative Impacts According to the Council on Environmental Quality’s regulations for implementing NEPA (40 CFR § 1508.7), an action may cause cumulative impacts on the environment if its impacts overlap in space and/or time with the impacts of other past, present, and reasonably foreseeable future actions, regardless of what agency or person undertakes such other actions. Cumulative effects can result from individually minor but collectively significant actions taking place over a period of time, including hydropower and other land and water development activities. The scoping process identified the geographic area of analysis to be the Ketchikan Creek watershed and Ketchikan area. Water quality, fisheries, and recreation were determined to be potential resources for which cumulative impacts could occur. There are no current plans for other activities within the upper Ketchikan Creek watershed (above the project tailrace) that would impact water quality, fisheries, or recreation. Much of this portion of the watershed is a designated municipal water-supply source. In accordance with requirements of the Environmental Protection Agency (EPA), KPU restricts the access and use of this portion of the watershed to protect the water supply source from potential contamination. The lower Ketchikan Creek watershed, which provides the majority of the creek’s anadromous fish habitat, is extensively developed for residential and related urban uses by the City of Ketchikan. Any past, current or future project-related impacts to water quality, fisheries and recreation in this portion of the watershed would, therefore, be cumulative with effects from past and future non-project-related development in this part of the watershed. Growth in Ketchikan is anticipated, and recreation use within the Ketchikan area would be expected to grow as both population and tourism increase. In our analysis of each of the affected resources, we describe the effects and any specific measures KPU, the agencies or we recommend for mitigating project effects that contribute to cumulative impacts on other beneficial resource uses. C. — KPU’s Proposed Action This section analyzes the environmental effects of the proposed project and modifications to the proposed project the agencies and staff recommend. The effects are analyzed for each resource that may be affected. 19 1. Geology and Soil Resources Affected Environment hy/T oy hy The project area is situated in the southwestern portion of Revillagegedo Island, one of the larger islands (1,168 square miles) of the Alexander Archipelago of southeastern Alaska. Revillagegedo Island is located within the Southeast Alaskan section of the Pacific Coast Mountains Physiographic Province (Williams, 1958). This section is characterized by rugged, glacially scoured peaks, lakes, and fjords. During the Pleistocene Epoch, glaciers advanced over Revillagegedo Island at least once, if not several times. The last glacial period ended about 13,000 years ago. Combined glaciation and fluvial erosion has resulted in the U-shaped valleys; elevated terraces; elongated lakes; and deeply scoured embankments, inlets, and passages. Elevations in the project area range from about 100 feet above sea level at the lower (southwestern) end of the penstock tunnel to about 500 feet along the project area boundary around Ketchikan Lakes. Below the dam, land within the project area is moderately sloping while it is steeply to very steeply sloping around the lakes. Geology Base rock within the project area formed when a plutonic body intruded into pre- existing, metamorphosed sedimentary rock. This metasedimentary bedrock dates from Paleozoic or Mesozoic time. It outcrops from the southern end of the project area to the southern end of Lower Ketchikan Lake. The plutonic body is described as a stock comprised of gabbro, a dark, coarse-grained igneous rock. This gabbro stock dates from Tertiary time. Near the south end of the project area, the metasedimentary bedrock grades into metamorphosed volcanic rock (Berg et al., 1988). The steep slopes surrounding the valley are mantled by colluvium, a mixture of unsorted, glacially-deposited rock material and post-glacial fragments of decomposing bedrock. These colluvial deposits reach several feet in thickness on the lower slopes. The valley of Ketchikan Creek is covered with deposits of Quaternary (Pleistocene and post-Pleistocene) alluvium. These poorly sorted stream deposits of sand, gravel, cobbles, and boulders rest on metasedimentary and metavolcanic bedrock and are up to 15 feet thick. A small area of Quaternary elevated marine deposits is found at the lower end of the access road corridor. These deposits consist mostly of sand and fine gravel (Lemke, 1975). 20 Minerals Metallic mineral deposits have been identified in the Ketchikan area, and some resource development (including gold mining) has occurred in the past. However, there are no active mines or significant known deposits within the project area (Bunditzen et al., 1982 & 1996). Two claims and one prospect have been identified in the area below the Ketchikan Lakes dam (Berg et al., 1981). Geologic Hazards The Ketchikan area has been placed in seismic zone 2 on a scale of 0 to 3 (with 3 being the highest risk zone). Moderate earthquake-related damage to man-made structures is possible. The magnitudes of the largest expected events would register in the 4.5 to 6.0 range (Richter Scale) in Ketchikan. However, the possibility of larger events can not be ruled out. Steep terrain, significant precipitation, and shallow soil depths accompanied by limited infiltration capacities could result in instability, particularly during a seismic event; however, the area surrounding the lakes do not exhibit fractured or loose rock poised to fall. Avalanches are not uncommon in winter. There is an avalanche chute on the western shore of the lower lake which stops just short of the water, and several on the eastern shore which reach the water (R&M Engineering, 1995). The FS has identified recurrent rock slide zones both east and west of the southern half of the Upper Ketchikan Lake on geographic information system (GIS) vegetation mapping (USDA, Tongass National Forest, 1996). Soils Soils within the Tongass National Forest have been mapped in the Ketchikan area (USFS, undated). This mapping is stored in the Forest's GIS data base. Mapping unit descriptions for these soils are also available. Descriptions of the soil mapping units which occur in the National Forest portion of the project area are as follows: Vixen-Traitors complex, 75-100 percent slopes. Vixen soils consist of fine sandy loam and silt loam which becomes gravelly with depth. They are deep, moderately well drained and well drained soils which have developed in residual and colluvial material derived from metamorphic bedrock. Traitors soils consist of silt loam and fine sandy loam. They are shallow, moderately well drained and well drained soils which have derived from metamorphic bedrock. This soil complex is found on the east side of the southern half of Lower Ketchikan Lake. 21 Tonowek and Tuxekan soils, 0-15 percent slopes. Tonowek soils consist of very fine sandy loam near the surface and very gravelly sand at depth. Tuxekan soils consist of silt loam and loam near the surface and extremely gravelly loamy sand at depth. Both are very deep, well drained soils which have developed in alluvium. These soils are found in the alluvial valleys above upper Ketchikan Lake and below Lower Ketchikan Lake. Kaikli mucky peat, 35-60 percent slopes. This soil consists of peat and muck with athin layer of silt loam at depth. It is a moderately deep, very poorly drained soil which has developed primarily in organic material. This soil is found to the south and east of the south end of Lower Ketchikan Lake. Shakan-McGilvery association, 60-150 percent slopes. Shakan soil predominantly consists of gravelly and very gravelly sandy loam. It is a moderately deep and moderately rapidly drained soil which has developed in colluvium. McGilvery soil consists of peat overlying a thin layer of very gravelly silt loam. This soil is shallow and well drained and has developed in organic material. This association is found on the west side of the southern half of Upper Ketchikan Lake. Tokeen gravelly sandy loam, 35-60 percent slopes; Tokeen gravelly sandy loam, 60-75 percent slopes; and Tokeen gravelly sandy loam, 75-100 percent slopes. These soils consist of gravelly sandy loam and gravelly loam. They are moderately deep, well drained, and have formed in colluvium derived from granitic bedrock. They comprise about half of the shoreline soils around Ketchikan Lakes. Rock outcrop, 75-150 percent slopes. Areas of rock outcrop are characterized by an absence of soil development. In addition to metamorphic and granitic bedrock, these areas include unconsolidated talus deposits. Scattered soils of varying types are present in these areas including those of the Traitors, Helm and Shakan series. Rock outcrop is present in several areas along the shoreline of both Upper and Lower Ketchikan Lakes. Soils in the portion of the project area which is to the south of the Tongass National Forest have not been mapped. This area has been examined on stereo pairs of natural color aerial photography for the area (USFS, 1973). Most of this area appears similar in slope, geomorphology, and vegetation to the adjoining area within the Forest south of Lower Ketchikan Lake. Those areas within the Forest are mapped as Kaikli mucky peat, 35-60 percent slopes and Tonowek and Tuxekan soils, 0-15 percent slopes. Therefore, the study area south of the Forest boundary has been tentatively mapped as a complex of these two soil mapping units. 22 Environmental Impacts and Recommendations Continued operations of the hydroelectric facilities would likely result in both long- and short-term effects on both the geologic and soil resources. Future excavation of rock in the project area for use in road construction and/or maintenance would alter the local physiographic and geologic conditions; however, impacts, although long-term, would be limited to approved quarry sites that would be selected based on minimizing effects to other resources. No additional new road construction is planned. Road maintenance would infrequently require minimal quantities of rock. For the duration of the project and continued use of the Ketchikan Creek watershed as the primary source of municipal water supply, mineral exploration and development would be prohibited in the project area and watershed. Therefore, anticipated impacts from mineral development in the watershed would not occur. Although possible, the likelihood of a seismic event in combination with high slope-instability conditions that could affect the project is minimal. An earthquake larger than 6.0 on the Richter Scale would be required to result in a significant mass wasting event or events, which could directly impact the Project’s dams or produce an over- topping of a dam by displacement of impounded water from slope failures. None of the recorded seismic events that have been recorded within about 120 miles of the project area have exceeded a magnitude of 5.0 (KPU, 1992). Impacts to soils from continued operations of the project would likely be limited to short-term accelerated soil erosion and soil loss events. Road and ditch maintenance could leave loosened soil materials on the surface. The exposed soil materials would subsequently be subject to entrainment by runoff from precipitation events. However, rock is used in most road and ditch maintenance activities which limits the exposure of soil materials to the forces of water erosion. Maintenance of buried penstocks, if necessary, would likely expose excavated soil materials to accelerated erosion conditions; however, exposed soil materials would be replaced and stabilized shortly after cessation of repair or maintenance activities. Accelerated soil loss conditions would be limited by minimizing the extent and duration of soil exposure. Implementation of an erosion control plan with any future ground disturbing activity [FS 4(e) condition No. 117] would minimize erosion. Unavoidable Environmental Impacts: Continued project operation would require routine maintenance of project access roads and occasional land disturbances to repair project facilities. These activities would result in minor short- and long-term impacts on soils and geologic resources. 23 2. Climate, Meteorology, And Air Quality Affected Environment The project lies at elevations ranging from sea level at the Tongass Narrows to 3,014 feet msl on Diana Mountain at the upper end of the watershed above Upper Ketchikan Lake. The project is located at latitude 55° 21' N and longitude 131° 39' W. The climate is classified as marine, and is characterized by relatively narrow temperature ranges and relatively heavy precipitation amounts. Ketchikan's average monthly temperature is 45.9 degrees Fahrenheit (°F). August is the hottest month with an average temperature of 58.7°F and January is the coldest month with an average temperature of 34.2°F. Precipitation amounts in the Ketchikan area are extremely variable within short distances, due to the rugged topography and close proximity to the ocean. Ketchikan averages 155.22 inches of precipitation per year, including an average of 37.4 inches of annual snowfall. The wettest month is October with an average monthly precipitation of 22.55 inches, and the driest month is June with an average monthly precipitation of 7.36 inches. (values‘derived from the period 1922 to 1987, University of Alaska Arctic Environmental Information Center, from City of Ketchikan, 1992, Beaver Falls Hydroelectric Project). Environmental Impacts and Recommendations The project would have no effect on climate/meteorology. However, the loss of this hydroelectric power generation capacity would require replacement with an equal amount of new hydroelectric power generation, that would have environmental impacts elsewhere, or with additional diesel generation which would result in increased air emission impacts. Unavoidable Environmental Impacts: None 3. Water Resources Affected Environment The Ketchikan Lakes consist of two adjacent natural lakes that serve as the Ketchikan municipal water supply as well as providing hydroelectric power to KPU. The useable volume of the two lakes was increased to 13,600 acre feet by construction of a dam at the outlet of the lower lake. Development of this site began in 1903. There have been a number of stages in the development of the site’s hydroelectric power since that time, including the construction of the Granite Basin Creek diversion. The present system has been about the same for approximately 30 years. 24 There are numerous, small, unnamed streams flowing into Ketchikan Lakes within the 8.5-square mile watershed above Ketchikan Lakes dam. The upper inlet is fed by a small, unnamed, alpine lake south of John Mountain, 2,000 feet upstream and 770 feet higher in elevation. Water from Ketchikan Lakes is conveyed by pipelines and a tunnel to Fawn Lake, which is at the same elevation as Ketchikan Lakes (figure 3). Granite Basin Creek flow is also diverted to Fawn Lake. Figure 3. _ Profile of pipelines and tunnels. (Source: KPU, 1998) Ketchikan Creek extends 7,400 feet from the embankment on Lower Ketchikan Lake to the tailrace of the power plant, located in the city of Ketchikan. There are small pools, 340 to 750 feet in length, located above the three falls in the bypassed reach. Scout Lake is a small lake on the west flank of Deer Mountain at an elevation of 280 feet, and feeds the Ketchikan Creek bypassed reach. There are no other significant streams in the study area. Table 2 presents basic hydrologic data for the Ketchikan Creek watershed. The average annual runoff for Ketchikan Creek is 155,800 acre feet and the maximum historic annual runoff occurring during the 1917-1918 water year was 178,000 acre feet at USGS Site 1506400, located 0.4 miles upstream of the mouth of Ketchikan Creek, in the center 25 of Ketchikan (USGS, 1996). There is no stream gaging record for the inflow to Ketchikan Lakes, which comes from numerous small streams Table 2. Basic Hydrologic Data for the Ketchikan Lakes Project. (Source: USGS Water Resources Division, 1996) Drainage area of Ketchikan Creek'? 13.5 sq. mi. Drainage area above Ketchikan Lake’ 8.5 sq. mi. Drainage area above Granite Basin Diversion* | 3.0 sq. mi. Maximum Discharge - Ketchikan Creek" 4,400 CFS Minimum Discharge - Ketchikan Creek! 3.6 CFS Average Annual Discharge - Ketchikan Creek'* 205 CFS Average Annual Discharge per square mile - Ketchikan Creek” 15.2 Average Annual Runoff - Ketchikan Creek'** 155,800 AF Maximum Annual Runoff - Ketchikan Creek (1917-18)' 178,000 AF ‘USGS Water Resources Diversion - Flow Data from USGS Site 1506400 2Federal Power Commission and the USDA Forest Service, 1947 Area above the gage site just below the confluence of Schoenbar Creek “Discharge at gage site below confluence of Schoenbar Creek ‘Average of 7 years with complete USGS flow record, 1910-11, 1915-19, 1965-67 Table 3 shows the predicted mean monthly flow of Ketchikan Creek, with upper and lower deviations. The community of Ketchikan receives an average of 155.2 inches of precipitation per year, with average monthly rainfall ranging from 7.1 inches for June to 21.9 inches for October (figure 4). Periods without measurable precipitation are short; the longest period was 21 days in July and August of 1924. Figure 5 shows the recent historical variation in elevation of the reservoir. The water level in the 13,600 acre-foot Ketchikan Lakes is gaged on a continual basis, with the data transmitted to the Bailey power plant. The spillway elevation is 348 feet, and between January of 1990 and December of 1995, the elevation ranged from an elevation of 328 feet up to the spillway or higher. There were only four very brief periods in the four-year interval when the lake level was at or above the spillway. The average daily discharge from Ketchikan Lakes and Granite Basin Creek is about 150 cfs as estimated by hydrologic techniques. Based upon the amount of power generated at the powerhouse during a typical year, this appears to be a realistic value. For example, the average daily flow through the powerhouse in 1995 was about 120 cfs. Adding 12 cfs for domestic water and 10 cfs for losses would give an average of 142 cfs for 1995. 26 Table 3. Annual and monthly inflow data (cfs) for Ketchikan Lakes. (Source: USFS Water Resources Atlas) MEAN ] 90% LOWER 90% UPPER | LIMIT ESTIMATE LIMIT Annual 102.9 119.4 138.4 January 34.9 69.6 138.7 February 33.0 55.8 90.7 March 22.1 38.9 68.6 April 49.5 57.3 66.3 May 84.9 127.9 192.7 June 108.8 166.2 248.2 July TS 119.7 189.5 August 75.8 116.6 179.4 September 99.6 138.8 193.4 October 146.3 201.6 277.9 November 92.0 131.8 188.9 December 42.1 77.0 141.0 EXCEEDENCE FLOW, CFS EXCEEDENCE LEVEL 5 percent NA NA | NA 15 percent 170.4 201.1 NA 50 percent 76.9 95.4 118.3 85 percent 2215 43.8 851.7 95 percent 11.5 23.4 47.5 Ketchikan Lakes Elevation Granite Basin Creek. Granite Basin Creek is not gaged. The average monthly discharge above the diversion is estimated to be about 45 cfs (USFS, unknown). The capacity of the diversion tunnel at Granite Basin Creek is large relative to the average daily flow and therefore diverts a high percentage of the flow. It is estimated that the flow exceeds the tunnel capacity less than 5 percent of the time, meaning that spills occur only 5 percent of the time or less. Table 4 shows the estimated mean flow of Granite Basin Creek, with upper and lower deviations, on a monthly basis. Table 4. Annual and monthly flow data (cfs) for Granite Basin Creek. (Source: USFS Water Resources Atlas) 90% LOWER MEAN 90% UPPER LIMIT ESTIMATE LIMIT Annual 38.76 45.12 a203: January 8.14 16.35 32.85 February 10.82 17.99 29.93 March 7.09 12.85 23.26 April 15.99 18.63 21.70 May 40.68 62.02 94.54 June 48.30 75.35 117.54 July 36.33 58.79 95.13 August 31.96 49.76 7748 September 89:15, 55.03 Tie October 53.38 74.22 103.19 November 33.00 47.77 69.17 December 12.65 23.83 44.90 EXCEEDENCE FLOW, CFS EXCEEDENCE LEVEL 5 percent 108.74 134.34 165.96 15 percent 66.16 78.42 92.95 50 percent 26.00 32.32 40.17 85 percent 7.46 14.62 28.66 95 percent 2.83 5.81 11.92 1990 - 1995 350 To i 345 1 it 340 H H 2 H 335 H 1 A IH H 330 1 1 HTT il ol : 320 +H H+ HH 1/99 7/90 1/91 7/91 1/92 7/92 1/93 7/93 1/94 7/94 1/95 7/95 Elevation - Feet Figure 4. _ Ketchikan Lakes elevation history. (Source: Greystone, 1998) S 1922 - 1996 a 8 2s g [ 4 5 20 & ii 2 15 Oo = 10 z = 8, 2 £ 2 of < Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Month Figure 5. | Mean Monthly Precipitation in Ketchikan. (Source: Greystone, 1998) 28 29 Fawn Lake. Fawn Lake is a very small reservoir, built to serve as a forebay for the powerhouse penstock, as well as a common collection point for the flows from both Ketchikan Lakes and Granite Basin Creek. Since the reservoir is small relative to the capacity of the penstock, the water level can be drawn down rapidly by opening the gates to the power turbines. Depending upon the amount of flow coming into Fawn Lake from Granite Basin Creek, and other factors, it may be possible to draw the level in Fawn Lake down so rapidly that turbidity is created. Since this water is the source of the domestic water supply, it is important to avoid turbidity. Also, the domestic water supply system works best when the water level in Fawn Lake is held at a nearly constant level. These factors, together with avoiding spills or extreme draw down in Ketchikan Lakes, present complex management criteria for the power plant operators. The rate at which water moves from Ketchikan Lakes to Fawn Lake is limited by the capacity of the pipeline/tunnel and the water level in Fawn Lake. Average capacity is about 120 cfs at low water conditions. The system operators have been able to obtain nearly total utilization of all the inflow to Ketchikan Lakes, by conveyance to Fawn Lake. This is evidenced by the avoidance of spills from Ketchikan Lakes. The flow from the Granite Basin diversion combines with the flows from Ketchikan Lakes at Fawn Lake. The flow through the powerhouse less the flow removed for municipal use, is the sum of the flow from Ketchikan Lakes plus Granite Basin. For the most part, all of the flow from Ketchikan Lakes and Granite Basin is routed through the power tunnel to the powerhouse and the municipal water supply. There are occasional spills from the system at Ketchikan Lake and at the Granite Basin diversion. There are records of these spills, which allows adding these flows to the hydrologic record created from the power generation and municipal water use data. Ketchikan Creek - bypassed reach. The bypassed reach of Ketchikan Creek consists of 1.34 miles of stream above the powerhouse tailrace up to Ketchikan Lakes dam, and 0.45 miles of Granite Basin Creek up to the Granite Basin diversion. Flows in the bypassed reach are not gaged but are minimal because as much water as possible is diverted for generation and domestic water supply. Flow in the bypassed reach is direct runoff from precipitation below the project diversions, seepage from Ketchikan Lakes dam, and leakage around Granite Basin diversion. The monthly average flow is estimated to be about 10 cfs. Based on a daily flow duration curve using precipitation data collected between January 1994 and November 1997 (KPU 1998b), daily flows exceed 3.6 cfs about 99 percent of the time and 4.8 cfs about 50 percent of the time. A representative channel located midway between the tailrace and the embankment of Lower Ketchikan Lake in Reach K4, has a slope of 2 percent, a bank channel width of 67.5 feet, an average depth of 3.26 feet and a maximum depth of 4.1 feet. The channel substrate consists of 74.5 percent cobbles greater than 128 millimeters (mm), and 25.5 percent medium to very coarse gravel (Greystone 1997). 30 Ketchikan Creek - below the powerhouse. Ketchikan Creek flows 0.75 mile downstream from the tailrace to its inlet in Tongass Narrows. This reach is 75 percent of the Ketchikan Creek reach available for anadromous fish migration, due to migration barriers upstream. The average annual daily flow below the powerhouse was measured at the USGS site 15064000 as 205 cfs based on eight years of data (1910 - 1911, 1915 - 1919 and 1964 - 1967). This gage includes flow from the 1.1-square-mile watershed of Schoenbar Creek. Schoenbar Creek is 8.1 percent of the contributing watershed for this gage. Adjusting for Shoenbar Creek, the average daily flow below the powerhouse is about 191 cfs. The minimum instantaneous flow below the powerhouse is 35 cfs as required by the current FERC license. Of this, 2.5 cfs is piped to the adjacent fish hatchery and 32.5 cfs or more returns to the creek through the tailrace. Discharge from the fish hatchery and the City Park rejoin Ketchikan Creek 684 feet downstream of the tailrace. Including a minimum flow of about 3.6 cfs in the bypassed reach results in a minimum of 36.1 cfs around City Park, and 38.6 cfs below the fish hatchery outfall. The 0.26-mile-long reach between the tailrace and Schoenbar Creek is a riffle reach with a rectangular shape and dominated by a small cobble substrate (KPU 1998a). The reach has a fairly constant width of 86 feet. Using the Manning equation, with a 2.4 percent channel grade and a Manning’s ‘n’ of 0.040 gives the water depths shown in table 5 for a range of stream flows. Table 5. Estimated flow depths (feet) in Ketchikan Creek below the tailrace. (Source: KPU, 1998) Flow (cfs) Rectangular Channel 59" Bottom Width 86' 36.1 0.26 0.21 50 0.32 0.25 100 0.48 0.38 125 0.55 0.44 150 0.62 = 0.49 175 0.68 0.54 200 0.73 0.58 250 0.84 0.67 300 0.94 0.74 500 1.28 1.01 31 The minimum flows through the tailrace of 32.5 cfs, plus the 3.6 cfs minimum flow from the Ketchikan Creek bypassed reach provide 2 inches of water in the 86-foot- wide channel. Approximately 500 cfs is required to raise the depth of an ideal rectangular channel to one foot. The presence of gravel bars and a developed thalweg or a decrease in slope would modify the channel depths in this reach. Domestic water supply. The domestic water supply is taken from the penstock just before the water enters the powerhouse. The flow rate into the domestic water system is not metered. Based upon the daily consumption, the flow of domestic water is estimated to vary from 4 to 10 cfs. Monthly water flow, observed in the chlorination process, in August, 1994 averaged 8.45 cfs, while flow in January, 1995 was 6.33 cfs (KPU 1995). This flow is not controlled by the powerhouse operation. The domestic water supply, drawn from the penstock near the powerhouse elevation, is boosted under penstock pressure up to the water supply storage tank. The elevation of the storage tank is sufficient to provide distribution pressure in the municipal system. Chlorine is injected in the domestic water supply pipeline just after the water is drawn from the penstock. Mixing and exposure occurs in the 6,000 foot transmission line up to the storage tank. Additional contact time occurs in the storage tank. Maintaining a relatively constant reservoir level in Fawn Lake, and thereby a fairly constant pressure at the tap point of the domestic water supply, is significant to operation of the domestic water system. No other water treatment is required for the water supply because KPU, as a condition of their ADEQ permit PWS #120232 for the drinking water system, has agreed to limit human access to the water source (Ketchikan Lakes and Fawn Lake). The domestic water use has been estimated to range from a minimum of 2.5 million gallons to a maximum of 6.5 million gallons per day (4 to 10 cfs). Absent an alternative domestic water supply, this flow is considered an absolute necessity. It is assumed that this amount will increase with population growth. If this flow were not diverted for domestic use, it would be available for hydroelectric power generation. The unavailability of domestic water for power generation is considered unavoidable. Tailrace and Deer Mountain Fish Hatchery. The tailrace is that part of a hydroelectric project between the point where water is discharged from the turbine and where it is returned to a natural channel. Water in the tailrace at the Ketchikan powerhouse is divided before it is returned to Ketchikan Creek. In a diversion box beneath the powerhouse, 2.5 cfs is diverted to the fish hatchery located just southwest of the powerhouse. Part of the flow to the fish hatchery is discharged to open channels flowing through the City Park. Depending on hatchery needs, part of this flow returns to Ketchikan Creek about 200 feet downstream of the Fair Street bridge. The balance of the flow returns to Ketchikan Creek after flowing through the hatchery, about 600 feet 32 downstream from the Fair Street bridge. The amount of flow to the hatchery is relatively constant, and is fixed by weirs at the powerhouse. The amount of flow directed to the hatchery is controlled by the hatchery personnel. Minimum flow. The discharge from the powerhouse is maintained at or above the minimum flow requirement of 35 cfs required by the present FERC license. There is a bypass valve on the penstock which automatically releases 35 cfs directly from the penstock to the tailrace chamber in the event that the turbines are shutdown. Unregulated flow data for 1993, 1994 and 1995 for Ketchikan Creek downstream from the powerhouse indicates that 35 cfs may be about the highest minimum flow that can be sustained over the summer months (table 6). Table 6. Computed average unregulated monthly flows for Ketchikan Creek below powerhouse (1993 - 1995). (Source: KPU, 1998) Estimated Unregulated Flows (cfs) MONTH 1993 1994 1995 January 109 ye) 54 February 257 28 115 March 103 162 111 April 108 131 147 May 166 193 137 June 58 149 102 July 39 94 63 August 29 35) 15 September 39 274 79 October 171 214 : 297 November 210 106 192 December 237 85 191 Average 127 137 130 Water rights. Water rights for this project were assigned by the State of Alaska Certificate of Appropriation No. 537 for 81,395,500 gallons per day (gpd) (126 cfs) for electric power generation and for 6,725,100 gpd (10.4 cfs) for the public water supply. Bo) The point of diversion is the Lower Ketchikan Lake rockfill dam and water intake structures located in the protracted SE 1/4 of SW 1/4 of Section 17, T75S, R91E, Copper River Meridian. The Deer Mountain Fish Hatchery has an appropriation of 1,615,790 gpd (2.5 cfs) from the KPU tailrace below the powerhouse (NE 1/4 NE 1/4 of Section 30, T75S, R91E, Copper River Meridian) through the State of Alaska Certificate of Appropriation No. 472 amended. Article 33 of the present FERC license for the project requires a continuous minimum flow of 35 cfs below the powerhouse. This 35 cfs flow requirement is not a serious impediment to operation of the powerhouse. This flow does pass through the powerhouse before being discharged and generates about 800 kW of electricity on an annual basis which is used in the system. Downstream of the project area, ADF&G filed for a minimum flow of 5 cfs through the fish ladder. This filing has a priority date of 12/31/64 and was certified by the Alaska Department of State Lands on 7/23/70. ADF&G Instream Flow Reservation Request. In July 1988, the ADF&G applied to the State of Alaska Department of Natural Resources, for an instream flow reservation (IFR) on Ketchikan Creek (table 7). Table 7. | ADF&G's instream flow reservation request. (Source: KPU, 1998) Month ADF&G Request Month ADF&G Request (cfs) (cfs) January 74 July 170 February 70 August 134 March 67 September 134 April 122 October 219 May 200 November 200 June 200 December 105 [ Average = 141 cfs Instream flow reservations are a rate, or volume of flow in a river required by the Alaska Department of State Lands for one of the following uses: (1) protection of fish and wildlife habitat; (2) migration and propagation; (3) recreation and parks purposes; (4) navigation and transportation purposes; or (5) sanitary and water quality purposes. The objective of this filing was to promote the fishery. The application is for flow from the outlet of Ketchikan Lakes to the confluence with Tongass Narrows. 34 The Ketchikan Creek instream flow reservation is currently pending before the Alaska Department of State Lands. A pending IFR application does not challenge an existing water right unless the existing water right is no longer in use, in whole or in part, and is thus subject to revocation for abandonment or forfeiture. The filing of the IFR application results in a priority order being established for future allocation of any water that might become unappropriated (Alaska DNR 1998). KPU plans to continue using all of their water rights for municipal water supply and hydro power generation. Water quality. The water derived from Ketchikan Lakes is a calcium bicarbonate water of low hardness (5.7-42.7 milligrams per liter (mg/L) CaCO,) and low salinity (25 umhos/cm). The mean pH for the lakes was 6.0 Standard Units (S.U.) in testing done approximately 15 times per year from 1993 - 1994 (KPU, 1996b). This is considered to be slightly acidic, but within the range of EPA recommended pH levels for freshwater drinking supplies. The results showed maximum daily turbidity values in August of 1993, 1994 and 1995 ranged from 0.59 nephelometric turbidity units (NTU) to 0.88 NTU. Turbidity of the water supply increases when water levels within the Fawn Lake forebay are depressed. KPU is aware of the problem and operates the project to minimize it. A minimum of 14 total and fecal coliform samples were taken from Ketchikan Lakes during the 1993-1995 studies (KPU, 1996b). All samples met EPA’s surface water treatment guidelines of less than 100 total coliforms per 100 milliliters. Nutrient values are low. Nitrate-nitrogen has been at detection limit in sampling performed between 2/20/90 and 2/1/94, ranging from <0.03 - <0.5 mg/L. Nitrites were also at detection limit with values of <0.1 mg/L. Total phosphorus was typically at the detection limit but ranged from <0.03 to 0.38 mg/L. Sampling and analysis for heavy metals has been performed periodically at the site between 2/20/90 and 2/1/94. Based on Alaska’s use-based water quality standards (18 AAC 70, ADEC, 1996), the water may have the potential to pose limitations for sensitive salmonids with regard to copper and zinc concentrations, which exceeded the standards in samples collected in June of 1990. Additionally, the detection limits for the method of analysis used to measure cadmium, mercury and total cyanide were higher than water quality criteria for aquatic organisms, so whether these parameters may pose limitations cannot be determined from the existing data. Testing of volatile organics in water supply samples collected in 1989, 1993 and 1995 show most compounds at levels below detection limits, and those that do register are lower than recommended water quality criteria (KPU, 1998). Monthly temperatures have been acquired at the Deer Mountain Hatchery over a nineteen-year period which show a range from 1.1 degrees Celsius (°C) to 16.15°C. 35 Monthly temperatures average 7.34°C with the monthly average range over the period ranging from 3.16°C to 13.93°C (Denton, 1996). Water from Ketchikan Lakes is delivered to Fawn Lake through a pipe located in the lower levels of Lower Ketchikan Lake, which is a shallow lake. Water temperatures are strongly influenced by seasonal air temperatures. Ground water. There is no information on any wells within the study area. Environmental Impacts and Recommendations Operations of the project facilities affect the natural hydrologic regime of Ketchikan Lakes, the Ketchikan Creek bypassed reach, Ketchikan Creek below the powerhouse tailrace, and Granite Basin Creek below the diversion. Water resources impacts that affect aquatic resources are discussed in the aquatics resources section. Impacts related to water quality are discussed below. Lake turbidity and sedimentation Water surface fluctuations in project reservoirs can adversely impact water quality by increasing sedimentation and water turbidity. Water levels in Ketchikan Lakes and Fawn Lake fluctuate in direct response to precipitation and power releases. Water levels are managed in conjunction with other hydroelectric facilities in the KPU grid and water quality considerations for Fawn Lake. Although seasonal water surface elevations vary in the Ketchikan Lakes up to 20 feet (figure 5), KPU limits hourly fluctuations to protect the water quality of the municipal water supply. KPU proposes to continue to manage the project to protect water quality by operating Fawn Lake to minimize water turbidity. To improve the existing conditions, KPU proposes to install remote water level monitoring equipment at Fawn Lake to better anticipate the turbine intake flows. This would help decrease the rate of change in the reservoir elevation and further reduce water turbidity. The FS requires that KPU continue to manage the watershed to protect water quality and continue to operate Fawn Lake to minimize turbidity to protect water quality (FS condition 114). The FS also requires KPU to file with the Commission a plan approved by the FS to control erosion, stream sedimentation, dust, and soil mass movement consistent with the standards and guidelines of the Tongass Land Management Plan (FS condition 117). The plan should be filed at least 90 days prior to starting any activities the FS determines to be of a land-clearing or land-disturbing nature on National Forest System land. Upon Commission approval, KPU would implement the plan. 36 Staff Analysis The water quality within the project lakes reflects the headwater conditions of a mountainous coastal old-growth forest of western hemlock, Sitka spruce, and cedar. KPU's water supply objective is to maintain constant supply pressure and good water quality. This objective is achieved by maintaining a stable water level at Fawn Lake. In addition, human access to project reservoirs is limited to help protect quality of the municipal water supply. By managing the lakes to protect water quality, turbidity and sedimentation in Ketchikan and Fawn lakes is significantly reduced. KPU's proposed lake-monitoring measures would further reduce sedimentation and turbidity. Staff recommends that KPU continue to operate the project to protect the water quality of the domestic water supply. If KPU plans to conduct any land-disturbing activities during the license period, the FS requires that they file a plan with the Commission to control erosion, stream sedimentation, dust, and soil mass movement consistent with the standards and guidelines of the Tongass Land Management Plan. Water Quality Protection Measures FWS recommends that KPU collect, treat, and remove all condensate and leakage from the project turbines and other equipment. The FS requires that KPU continue to operate an existing oily water separator and maintain plumbing refits in the powerhouse to remove all oil from the water before it is discharged into the project tailrace (FS condition 114). If KPU plans to conduct any land-disturbing activities during the license period, the FS requires that they file an Oil and Hazardous Substances Storage and Spill Prevention and Cleanup Plan with the Commission (FS condition 127) and a Solid Waste and Waste Water Plan (FS condition 126). These plans should be filed at least 90 days before starting any activities the FS determines to be of a land-disturbing nature on National Forest System land. Upon Commission approval, KPU would implement the plans. Staff agrees with these recommendations and requirements, and recommends that KPU develop a wastes and hazardous substances contingency plan for the handling of all such project-related materials. ° Unavoidable Adverse Impacts: KPU manages the project to protect the water quality of the domestic water supply. Project operations and routine maintenance can result in unavoidable spills of hazardous substances into project waters. Developing a contingency plan for the handling of all such project-related materials would help reduce the number and magnitude of these events. 37 4. Aquatic Resources Affected Environment Information for the fisheries resource was acquired from the following sources: (1) resource management agencies; (2) published and unpublished literature; and (3) field stream inventories. The resource management agencies provided information on the status, occurrence, and use of habitats for fish in the project area. Literature included general scientific information on the key fish species and reports on site-specific surveys conducted in the project area. During August 1997, Greystone Consultants conducted an aquatic habitat survey of the Ketchikan Creek system, and in August 1997, September 1997, and April 1998 fish surveys were conducted. Ketchikan and Granite Basin creeks were divided into approximately /-mile-long reaches (see figure 6). The reaches were delineated based on significant hydrologic or physical aquatic habitat changes. Attributes of selected reaches were collected using the Draft Fish Habitat Monitoring Protocol for the Tongass National Forest (USFS 1997a). Additional detail on methods, collected data, and analysis are provided in the Aquatic Resources Study for the Ketchikan Lakes Hydroelectric Project (KPU, 1998a). The fisheries resource of the project area includes both anadromous and resident species of the Ketchikan Creek system or watershed. Significant aquatic habitats within this system consist of Ketchikan Creek, Granite Basin Creek, Schoenbar Creek, Scout Creek, and a small unnamed tributary to Granite Basin Creek. Fish species present in the Ketchikan Creek system are listed in table 8. None of the species of fish occurring in Ketchikan Creek system are listed by the state or U.S. Fish and Wildlife Service (FWS) as threatened or endangered species. Based on the accessibility of anadromous fish and physical stream characteristics, the aquatic habitat was divided into four groups of stream reaches or lakes. The groupings of aquatic habitat are: (1) the anadromous section of Ketchikan Creek (K1, K2, K3); (2) the non-anadromous section of Ketchikan Creek (K4, K5, K6); (3) Granite Basin Creek (G1, G2, GT1); and, (4) Ketchikan Lakes. A five-foot high falls at the upstream end of the canyon area of Ketchikan Creek separates the anadromous (K1 and K2) and resident-fish reaches (all other reaches). The height of the falls creates a barrier to the migratory movement of anadromous fish past this point in Ketchikan Creek. 38 — Abovs or below project operations —— Bypamaed Reaches Notes ® = Surveyed etream reaches Figure 6. Aquatic resources map. (Source: KPU, 1998) 39 Table 8. Species list and codes for fish occurring within the Ketchikan Creek Table 9. Salmon escapement surveys (1978 - 1995). (Source: ADF&G, 1996) watershed. (Source: KPU, 1998) Species Species Year Date Chinook | Coho | _ Sockeye Pink Chum Common Name Code Scientific Name 1978 9/15/97 21 850 Chinook salmon (= king salmon) KS Oncorhynchus tshawytscha 1329) an = Coho salmon (= silver salmon) co Oncorhynchus kisutch 1987 13000 Sockeye salmon (= red salmon) RS Oncorhynchus nerka | 10/4/97 | 60 Pink salmon (= humpback salmon) PK Oncorhynchus gorbuscha 11/5/97 130 Chum salmon (= dog salmon) CH Oncorhynchus keta 1980 SN0/97 I wy a a287 A = 1982 8/17/97 15 936 Steelhead, rainbow trout SH Oncorhynchus mykiss Ta aise 0 Dolly Varden char DV Salvelinus malma 9723/97 2 6 9272 1 Cutthroat trout CT Oncorhynchus clarki 1983 9/2/97 1353 Eastern brook trout BT Salvelinus fontinalis 9/23/97 1400 Stickleback SB Gasterosteus aculatus eee ! ae Z 13250 : ~ mn 4 1984 7/25/97 500 | Sculpin sc Comespr = 1197 3 9/27/97 11187 1 Anadromous section - Ketchikan Creek 1073097 6880 6 The anadromous section of Ketchikan Creek (approximately one mile in length) 1985) oT, 58 supports a variety of salmonid fish species. Coho salmon, chinook salmon, sockeye 1985 8/27/97 2076 3 salmon, pink salmon, chum salmon, Dolly Varden char, cutthroat trout, steelhead trout, 9/12/97 130 7830 rainbow trout, and brook trout all use portions of Ketchikan Creek below the barrier falls 1989 8/5/97 300 for spawning and rearing (ADF&G 1987; Greystone 1997). Chinook salmon and the 9/7/97 | 7 1 27600 summer coho run are not native to the system, but are maintained by the Deer Mountain 1990 w2197 160 1000 11500 Hatchery. Brook trout are also not native to the system. The remaining species a A000 f (including the fall run coho) are native, with supplemental stocking of some species. = B27197. | 6 2 1994 9/8/97 40 : 22960 ADF&G’s escapement surveys conducted from 1978 to 1995 document significant 1995 9/6/97 7 25 2 19250 salmon uses of Ketchikan Creek (table 9). The ADF&G times these escapement surveys Total 2560 3239 94 216410 13 to detect peak pink salmon escapement and, while other species are noted and counted, Average 213 294 10 11390 their run timing differs and the numbers should not be considered representative of total Mal 1353 1400 3 "0000 ; populations in the system. The surveys indicate that there is a substantial amount of wild a pink salmon production in Ketchikan Creek, with maximum yearly counts ranging from 850 to 40,000. Total numbers of salmon produced in Ketchikan Creek are large enough for Ketchikan Creek to be a regionally important commercial and sport salmon fisheries. 40 41 Chinook, coho, and sockeye salmon rear year-round in this segment of Ketchikan Creek and the other species of salmon rear for short durations of the year following emergence (table 10). Steelhead/rainbow trout and Dolly Varden char also use this stream segment for spawning, incubation and rearing year-round. Table 10. Ketchikan Creek fish species periodicity chart. (Source: ADF&G, 1998) | Jan | Feb | Mar | Apr | May | Jun | Jul | Aug| Sep | Oct | Nov | Dec Chinook Salmon Passage XXX] KKK | KKK | XXXX | XX Spawning XXXK | XXX | KKK Incubation XOX soxxx | 10008 XXXX XXX] XXX XK] KKK | OOK |_ XXX Rearing 2000 | 2000. | 2800 | 200eK | 280K | Wo0 | 2000 | 00K] 200K | 2000 | 200Kx | 200K Coho Salmon Passage 2000x | 2000 | 9000 | 2000 Spawning xx Xx] 2000x | 2000 | 20x | HEX Incubation 2000 | 000 | 000K | 2000 Xx} xxx | 2x0 | KX | XIE Rearing XXXX_ | XXXX | XXXX | XXXX | XXXX = XXXX | XXX] XXXX | XXXX | XXXX | XXXX) Pink Salmon Passage | XXX] XXX | HKX Spawning Xx] xxx | 2000 Incubation 20x | 200 | 2000 | 2000 xx] 2000] 2000x | 200Kx | 20eKX | OKA L Xx] 0x | 900K Sockeye Salmon Passage XX] XXXX | XXX | XXXX Spawning Xxxx | 200 | xxXX | 20000 Incubation xxxx } 2000 | 2000 | XK | KX | HC | KK] _XKKK | HCA Rearing 2000 | 000. | 000K _ | 000K | 2000 | 000K | 200Kx | 900K | 200Kx | KKK Chum Salmon Passage 1 | XXXX | XXXX Spawning XXX] XXXX Incubation xxx | 2000 | 000 | xX | XXXK | XHKK | XXX | KXNX|_XXKX Rearing = 00x | xxxx 42 Jan [Feb Mar | Apr | May | Jun | Jul | Aug| Sep | Oct | Nov | Dec Dolly Varden Passage Spawning XXXx | XXXX] XXX] XXX Incubation XxxX | xxxx | xxXX | xXXX 2000 | 3000x |200x | 2000x | 000K | 30KX | OXX’ Rearing 2000x | 200K | 2000 | 2000 | .900C | 2000] .000c| 2000] 200ex | 900x | 2200} 00x Rainbow Trout Passage Spawning xx] 2000 | 20x | xxx Incubation xx] 2000 | 2000 | 20xxx_[ s000x | 20x Rearing 2000. | 2000K | 2000. | 2900C | 2006 | 200K | 2000 | 280K | 2000 | 20xNX | HEX J HEX Steelhead Trout Passage Xx] xxxx | xxxx | 200K | xxx | XXXX Spawning Xx] XxxX | xXxXX | xxXX Incubation xox} 200xx | 2000 | 900K [OGG | x2EKK | ERX’ Rearing 2000X_[9000K [000 [000K [KX | XXX | KKK XK | KWOK | AK [KK | AXXX. Notes: 1. Each ‘X’ represents a quarter of the month. 2. Periodicity based upon professional judgment of ADF&G biologists. 3. Incubation life phase includes egg deposition to fry emergence. In addition to the salmon in Ketchikan Creek, there are wild populations of steelhead, rainbow, cutthroat, and brook trout, and Dolly Varden char. An average of 541 anglers were recorded for the years 1990 to 1994 indicates that Ketchikan Creek is an important recreational fishery (table 11). Because of this stream’s importance as a fishery, the ADF&G has specified it for protection under AS16.05.870(a) as important to anadromous fish and is an ADF&G cataloged anadromous fish stream (stream #101-47- 10250) (ADF&G, 1987). The Deer Mountain Fish Hatchery is located next to Ketchikan Creek in reach K2 (figure 6). ADF&G began operation of the hatchery in the mid-1970s and the Ketchikan Indian Corporation is the current operator (Denton, 1996). Chinook salmon culture (Unuk River ancestral stock) began with the 1977 brood. Annual smolt releases into Ketchikan Creek have been around 100,000 for most years. Native-strain Ketchikan Creek coho stock was cultured until 1982, however, from 1986 to present a non-native strain Reflection Lake summer coho stock has been cultured and released into Ketchikan Creek. Enhancement of the Ketchikan Creek steelhead stock has been intermittent, with small numbers released in some years. 43 Table 11. Sport fish harvested by species in Ketchikan Creek (1990 to 1994). (Source: ADF&G, 1996) 1990 | 1991 | 1992 | 1993 | 1994 | Avg. | Min. | Max. Anglers 926 | 239 436 352 qsl 541 239 | 926 Trips 2187 | 529 835 1091 | 1936 1316 529 | 2187 Days Fished 1978 | 579 | 1014 | 1212} 2625 1482 0 2625 Species: 197 0 0 0 oT 51 13 197 Chinook Coho 292 13 16 82 831 247 8 831 Sockeye 10 28 8 9 52 21 0 52 Pink 470 0 82 9. 74 127 0 470 Chum 11 32 0 0 0 9 0 32 Dolly 479 139 0 214 134 193 0 479 Steelhead 96 135 93 0 0 65 0 135 Rainbow 80 | 84 0 0 28 38 0 84 Cutthroat 16 0 0 0 0 3 0 16 Brook 16 0 0 0 26 8 0 26 The hatchery is supplied with water from KPU’s diversion just prior to the tailrace outlet. The hatchery’s water temperature records indicate that the monthly average water temperatures supplied to the hatchery range from 1.1°C to 16.1°C, with maximum temperatures sometimes reaching 18.0°C, especially in August (Denton 1996). This maximum water temperature is considered the upper limit for chinook salmon culture (Denton 1996). Alderdice and Velsen (1978) determined that the upper limit for 50 percent egg, mortality of chinook salmon was 16°C when incubation temperature was constant. The water supplied to the hatchery is not a constant temperature and is much cooler during the winter and spring salmon egg incubation period; however, Denton (1996) has observed 44 detrimental effects on gamete viability at the hatchery, resulting in lowered survival of fertilized eggs. The hatchery staff believe that the occasionally high water temperatures are a consequence of Ketchikan Lake's intake pipe being located near the bottom of the lake in relatively shallow water (Denton 1996). It is not possible to access cooler water in the summer from lower Ketchikan Lake; therefore, the hatchery staff has learned to work around the high temperatures by using refrigeration techniques (Denton 1996). Because the hatchery was constructed after the hydro project was constructed, its operations have been designed around the existing water temperature conditions. Although the hatchery and 1997 temperature data indicate water temperatures are occasionally higher than those preferred by salmonids, lack of suitable rearing habitat is considered the most likely limiting factor to natural fish production (Denton 1996; Greystone 1997). Anadromous section - reach-specific information Reaches K1, K2, and K3 comprise the anadromous section of Ketchikan Creek. Reach K1. This reach extends from the mouth of Ketchikan Creek (the Stedman street bridge) upstream to the confluence with Schoenbar Creek (figure 6). This reach is 2,659 feet long. This reach was not surveyed for fish during KPU’s 1997 and 1998 field effort. However, ADF&G surveys (table 9) document the presence of all five species of salmon and adult steelhead throughout this reach. Additionally, Greystone incidentally observed one adult steelhead in this reach on April 19, 1998. This reach was not surveyed for habitat during KPU’s 1997 field effort. However, general observations of spawning activities and substrate composition indicate that a portion of this reach is an important salmon spawning area for the Ketchikan Creek fishery. Additionally, the spawning and migration activities in this reach are important for the city of Ketchikan’s tourism; providing an important part of the city’s tours. Historically, there was a substantial pink salmon fishery that spawned in the estuarine gravels at the mouth of Ketchikan Creek. Numbers probably exceeded 100,000 adults. However, removal of these gravels for roads and to deepen the harbor has eliminated this fishery. Additionally, the Ketchikan Creek fishery was subjected to extensive overharvesting in the early 1900s from the now illegal fish trapping at the mouth of Ketchikan Creek. 45 A fishway was built in 1957 near the upper end of this reach to assist salmon escapement past a falls/cascade (figure 6) for hatchery purposes. It is maintained by both the ADF&G and Ketchikan Indian Corporation, (the current operators of the Deer Mountain Hatchery). Although no documentation exists, it is thought that the fishway has greatly improved the pink salmon fishery above the fishway. The ADF&G has filed for a 5 cfs instream flow reservation at the fishway to maintain fish migration ability through the fishway. The top of the fishway is 1,355 feet downstream from Schoenbar Creek. This reach ends at the confluence with Schoenbar Creek, which was historically an important salmon spawning area. However, communications with local residents indicate that alteration of habitat in upper areas of the creek have reduced its capabilities. Additionally, KPU’s 1997 survey crew observed a significant pooling of salmon at the mouth of Schoenbar Creek, which were unable to migrate past a poorly installed culvert at its mouth. Although heavy rains later made this passable, the culvert may significantly delay and disrupt or block fish movement. During worst-case conditions the culvert is perched, but even during best case conditions the length of the culvert creates difficult passage. Snorkel observations by KPU in August and September of 1997 recorded adults of all five salmon species. Pink salmon was the most abundant adult salmon, while coho was the most abundant juvenile salmon (table 12). The trapping and snorkeling surveys documented the presence of juvenile chinook, coho, Dolly Varden, steelhead/rainbow, and cutthroat in the reach. Snorkel observations in April of 1998 found no adult steelhead; however, ADF&G Snorkel surveys in April and May of 1997 and 1998 documented the occurrence of adult steelhead in this reach. Reach K2. The Deer Mountain Hatchery is located 663 feet upstream from the start of this reach (figure 6). This hatchery diverts migrating salmon into the hatchery by installing a diversion (bar screen) across Ketchikan Creek during the coho and chinook * spawning period in the fall. While installed, this barrier appears to almost completely restrict all but smaller-bodied pink salmon from migrating further upstream to spawn. It is not known what affect this passage restriction has on the anadromous fishery above the hatchery. 46 Table 12. Summary of snorkeling and fish trapping results in the Ketchikan Creek system August and September 1997 and April 1998. (Source: KPU, 1998) ] Snorkel Data (fish/acre) Reach ae rool creat for € Ta) ID Species 300mm | >300mm <300 mm 3300 mm <300 mm K2 | _Chinook Salmon 6 18 = = 6 Coho salmon 931 30 - 4 ‘Sockeye salmon 0 18 = 0 Pink salmon 2283 - 0 c Chum salmon 24 0 Dolly Varden 12 0 Steethead/rainbow 0 24 Cutthroat trout 0 = 1 TOTAL 2385 = - 46 K3 Chinook salmon 0 42 (0)' 0 6(1)' Coho salmon 0 354 (0) 7 28 (1) ‘Sockeye salmon 0 0(0) 35 0(0) Pink salmon 2083 00) 4243 0(0) ‘Chum salmon 0 0(0) 7 0(0) Dolly Varden 0 389 (35) 7 0(0) Steelhead/rainbow: 0 636 (813) 0 34 (5) Cutthroat trout 0 0) 0 6(0) Brook trout 0 24 (0) 0 0(0) TOTAL 2083 1445 (848) 4490 74 (7) Ka Steelhead/rainbow* 0 0 82 0 19 Cutthroat trout” 0 0 37 0 22 Brook trout 0 0 74 0 1 TOTAL 0 0 193 0 42 Gla’ Brook trout 34 0 453 0 46 Gib? [Brook trout 0 0 0 0 0 Gilt Brook trout - - - - 48 Gr no fish s 0 0 0 Ks Brook Trout = 7 0 = Kot Brook trout - 3 0 2 1 Numbers in parentheses indicate snorkel and trap data collected on April 19, 1998. Additionally, a snorkel survey for adult steelhead was conducted in K2 and K4. No adult steelhead were found during the survey; however, one >36-inch steelhead was incidentally observed in reach K1. 2 Because most, if not all, of these two species showed evidence of hybridization, identification was based on dominant phenotype. 3 To more accurately describe the fisheries in this reach, the reach was split into two sections, Gla is below the migration barrier and G1b is upstream. 4 Although not part of the survey, data was obtained to provide additional information. K5 was sampled just below confluence with Gi, and K6 was sampled just above G1. This was qualitative data only, no estimate of fish/acre or fish/trap should be assumed. 47 Reach K3. This reach extends from the tailrace to an anadromous fish migration barrier located 1,284 feet upstream of the tailrace (figure 6). Observations in April, August, and September 1997 and April 1998, indicate that a falls at the upstream end of the canyon area of Ketchikan Creek creates a migration barrier to anadromous species. This barrier consists of a cascade that hits a bedrock wall, angles 90 degrees, and then drops approximately 5 feet. Additionally, there is not an adequate takeoff pool to allow salmon to maneuver the falls. The barrier may best be described as semi-permanent. It is not quite permanent because it is partially created by a fallen old growth tree that will, after many years, deteriorate. However, it is essentially permanent because it does not appear to be a typical large woody debris barrier that could be washed out by a high flow event. There is anecdotal evidence that steelhead migrated past this point many years ago. This reach is significantly different from the rest of Ketchikan Creek for the following reasons: (1) it has extremely steep bedrock walls, and has a relatively narrow channel (20 ft compared with 73 ft for K2 and 36 ft for K4) and complete lack of floodplain; (2) it has relatively steep gradient (approximately 5 percent) with primarily bedrock substrates (table 13); and (3) it is located above the tailrace. Flows taken from Ketchikan Lakes and Granite Basin diversion bypassed this reach; therefore, it has significantly less flow than the downstream reaches. Unlike reaches K1, K2, and K4, spawning habitat in this reach is extremely limited, primarily due to the bedrock-dominated substrate. The lower instream flows may also reduce available spawning habitat in this reach, but increasing flows in this reach would only slightly increase its spawning habitat. The bedrock substrate in this reach limits its spawning habitat potential to such a degree that even historic flow levels would not appreciably increase habitat. Furthermore, the narrow channel width, complete lack of floodplain, and field observations indicate that high flows in this reach may reduce available habitat, not increase it. Adult pink, sockeye, chum, and coho salmon were all found up to the migration barrier at the end of this reach with pink salmon most abundant. Additionally, juvenile chinook and coho were recorded, especially near the downstream end of the reach. During a reconnaissance survey in April 1997, an adult steelhead trout was observed trying to jump the migration barrier falls, documenting its presence up to the migration barrier. Also, steelhead/rainbow juveniles were found throughout reach K3 during the snorkeling and trapping surveys in August and September 1997 and April 1998. No steelhead were seen past the migration barrier at the end of K3 during ocular observations in April of 1997 or during the adult steelhead survey conducted in April 1998. Resident species recorded during the survey included rainbow, brook trout, and Dolly Varden. This was the farthest upstream reach where Dolly Varden char were found. 48 Table 13. Summary of key aquatic habitat parameters in the Ketchikan Creek system August and September 1997. (Source: KPU, 1998) 1 | Reach Parameter K2 K3* Kae Gi Avg. Channel Type LCI MC3 MC2 MCI e Length (ft) 1,378 1,284 1,855 2,400 1,729 Approx. Gradient 1% 5% 2% 2% 3% Pool/FW Number Ratio 0 08 1 nD 0.7 Pool/FW Length Ratio 0 0.5 0.5 0.3 0.3 Dominant Substrate sc BR Lc BR - Fastwater: Avg. Length (ft) 689 172 183 170 303 Avg. Width (ft) B 20 36 17 36 Avg. Depth (ft) [22 09 06 0.5 1 Pool: Avg. Length (ft) : 7 82 53 69 Avg.Res.Depth (ft) - 1.2 12 | 14 13 Dominant Vegetation Type NFA CFC NFA NFA - NHO LWD (#/mile) 23 350 413 290 269 Notes: Reach Channel Type determinations were made using (Paustian 1992); MC1 = Moderate gradient, narrow shallow contained channel; MC2=Moderate gradient, moderate width and incision, contained channel; MC3=Moderate gradient, deeply incised, contained channel; LC1=Low gradient, contained channel. : 2,659 feet total length of K1 (from Stedman Street bridge to Schoenbar Creek); upstream end of fishway to end of K1 (Schoenbar Creek) is 1,355 feet; 1,980 feet from start of estuarine influence to Schoenbar Creek. * Flows in the bypassed reaches were higher than typical because no water was being diverted at Granite Basin diversion so flow-related parameters should be viewed accordingly. 49 Non-anadromous section - Ketchikan Creek Reaches K4, K5, and K6 comprise the non-anadromous section of Ketchikan Creek. - ion - -specific in, ion Reach K4. This reach extends from the 5-foot falls at the upstream end of the canyon to a 35-foot falls (Rainbow Falls). This reach is much different from K3. It has a much broader flood plain and wider stream channel than K3. The 2 percent gradient is much more gradual than the 5 percent found in K3. Additionally, the substrates are comprised primarily of large cobbles instead of bedrock. Because of these differences, this reach has much better spawning and rearing habitat. The bypassed of flows in this reach appears to reduce its available aquatic habitat. More flow in this reach would increase the aquatic habitat, especially spawning habitat. However, field surveys in 1997 indicate that this reach cannot be accessed by anadromous fish. As a result, it is only inhabited by a small population of resident trout) This reach probably had much better resident, and possibly anadromous, fish habitat when natural instream flows were present. The snorkel and trapping surveys indicate that resident rainbow, cutthroat, and brook trout are the only fish species occurring in this reach. The data collected indicate that the fish populations within reach K4, while not abundant, are reproducing successfully. Snorkel observations and trapping in the reach document that fish sizes are very small. This could be caused by: (1) slow growth caused by marginal food availability due to the extremely unproductive, oligotrophic water; (2) fishing pressure; or, (3) a combination of the two. Fishing pressure on the small fish population found in this reach could remove the larger fish. Survey crews during 1997 observed active fishing and camping within this reach of Ketchikan Creek. Most rainbow and cutthroat showed evidence of hybridization with each other. This is not surprising given the limited population sizes in this reach and the tendency of these two species to readily hybridize. Scout Creek enters Ketchikan Creek 334 feet upstream from the start of this reach. This creek is important because it contributes more than half of the flows to the bypassed reach during low-flow periods. A qualitative fish snorkel survey in April 1998 found 50 cutthroat/rainbow hybrids in Scout Creek and what appeared to be pure cutthroat in Scout Lake and upper portions of the stream. This finding suggests that this is the recruitment source for the cutthroat remaining in Ketchikan Creek. There are unconfirmed reports from local fisherman that historically (possibly 35 years ago or more) steelhead made it upstream to Rainbow Falls. This was likely before the old growth timber created the migration barrier at the top of the canyon. Rainbow Falls is located 3,139 feet upstream from the tailrace, and is the end of Reach K4. Rainbow Falls has a vertical drop of approximately 35 feet. It is definitely a migration barrier to all fish species. Reach KS. This reach extends from Rainbow Falls to the confluence with Granite Basin Creek. There is a second 35-foot falls located near the upper end of this reach, very similar to Rainbow Falls. This falls is a permanent migration barrier. No aquatic habitat and no formal fisheries data were collected in this reach during KPU’s 1997 survey. However, qualitative fisheries data was collected at the upper end of the reach between the second 35-foot falls and Granite Basin Creek. The data was obtained by snorkeling and trapping optimum habitats. Both snorkeling and trapping found only eastern brook trout. Although not sampled, the section of the reach between Rainbow Falls and the second 35-foot falls likely contains brook trout and possibly rainbow and cutthroat as found in K4. Reach K6. This reach extends from Granite Basin Creek to the outlet of Ketchikan Lakes. This reach was not formally surveyed; however, qualitative snorkeling and trapping were conducted in optimum habitats to determine species occurrence. As was noted for the upper K5 reach, only brook trout were found. Granite Basin Creek Reaches G1 and G2 comprise the Granite Basin Creek segment that was surveyed. Also included in the Granite Basin Creek segment is GT1, which is a tributary to Granite Basin Creek. ranite Basin - reach-specific information Reach G1. This reach starts at the mouth of Granite Basin Creek and ends at KPU’s Granite Basin diversion. This is the reach where flows from upstream are bypassed to Fawn Lake. 51 This reach has relatively good aquatic habitat with the exception of its reduced flows as explained below. It had the best pool-to-fastwater ratio of any of the reaches and, although dominated by bedrock, had several sections with suitable spawning substrates. It also has a relatively low gradient (2 percent). The only species of fish found in Granite Basin Creek was the non-native eastern brook trout. They were only found up to a migration barrier in reach G1 (1,352 feet upstream). Therefore, for fisheries discussions, reach G1 is divided into two sections. Gla is the fish-bearing section, below the migration barrier, and G1b in the remaining section. During low flow periods, reach G1 -- the bypassed reach of Granite Basin -- has some sections of stream flowing subsurface, beneath the substrate. These sections have a few permanent pools that provide some habitat to support the limited brook trout population. Reach G2. This reach extends from KPU’s Granite Basin diversion to the first lake on Granite Basin Creek. This reach was not formally surveyed. However, trapping and qualitative snorkeling of optimum habitat was conducted to provide information on presence absence of fish species above the diversion. No fish were found in this reach Reach GT1. This reach consists of a small tributary stream just upstream of where the penstocks cross Granite Basin Creek. This reach was not surveyed for aquatic habitat. However, fish traps were set to document the large numbers of brook trout fry observed. Its size is limited (<0.5 cfs flow, <0.1 ft average depth, and <3 ft. average width during the 1997 survey). Despite its limited size, hundreds of fry were seen throughout this tributary, indicating its importance as a spawning tributary and probable recruitment source for lower Granite Basin Creek (Gla). Two fish older than a year were recorded in this reach. Ketchikan Lakes According to an ADF&G survey of Ketchikan Lakes, fish species within Ketchikan Lakes include cutthroat trout, sticklebacks, cottids, and non-native eastern brook trout (ADF&G 1995). ADF&G records show that the brook trout population originated from a US. Forest Service stocking of 5,000 fingerlings in 1931 from Yes Bay Hatchery. The ADF&G survey reports that the Lakes’ substrates generally consist of bedrock and talus, with some muck in the depths. However, there are good spawning grounds at 52 the primary inlet to the Lakes. The Lakes are approximately 640 acres in size with an estimated maximum depth of 200+ feet in the upper lake. The Lakes are oligotrophic, probably resulting in a fishery with slow growth rates. All of Ketchikan Lakes water, except infrequent spills, is diverted from its historic course of Ketchikan Creek. The intake pipe for this diversion is located in the lower levels of Lower Ketchikan Lake. Because this is a shallow lake, water temperatures are strongly influenced by seasonal air temperatures. Fish were observed rising in Fawn Lake during the 1997 survey. Conversations with KPU staff indicated that the fish migrate to and from Ketchikan Lakes via the penstock. Fawn Lake is a manmade lake created for this project to route water to the powerhouse. Environmental Impacts and Recommendations Water Temperature To study the project-related impacts on the water temperatures in Ketchikan Creek below the tailrace, KPU installed hourly continuous temperature monitors above and just below the tailrace on July 25, 1997. A heavy flow event, occurring sometime between August 20 and October 4, washed out the data loggers. They were both retrieved downstream of the tailrace on October 5, 1997. For this reason, only limited temperature data above and below the tailrace was collected. KPU indicated that they are collecting more water temperature data above and below the tailrace, which would be reported after a full year of measurements are collected (letter from Larry Keith, Project Manager, Greystone Environmental Planners, Scientists, and Engineers, Greenwood Village, CO., January 14, 1999). During KPU’s limited water temperature collections, Ketchikan Creek reached a maximum temperature of 19.4°C and an average of 13.1°C below the tailrace. The average stream temperature was at least 1.3°C higher downstream of the tailrace than upstream of the tailrace. The maximum temperature was at least 3.4°C higher downstream of the tailrace compared to upstream. The higher temperatures below the tailrace show that the normally, much higher project flows were warmer during the sampling period than the relatively smaller flows in the bypassed reach. The agencies are concerned about water temperature because of possible adverse effects on the Deer Mountain Fish Hatchery, which gets its flow from the project tailrace, and also, on fish habitat in Ketchikan Creek downstream of the tailrace. 53 KPU proposes to monitor the water temperature of project leakage flows to establish a temperature baseline for it to maintain, if improvements to the project dams designed to reduce leakage are scheduled during the next licensing period. KPU would monitor the temperature of leakage flows for one year prior to making any such improvements. To ensure that the existing water temperatures below the project dams are not increased if KPU repairs the dams during the next license period, ADF&G recommends that KPU establish the existing baseline water temperatures by continuously measuring water temperatures of dam seepage for a period of 5 years. NMFS recommends that the water temperatures measured in the project tailrace not exceed 16°C over an 8-hour period. Recurrent incidents of prolonged temperatures exceeding 16°C would require corrective measures, which may include deepening Fawn Lake, shading the surface waters of Fawn Lake, and/or selecting project flows from the coolest water bodies (Granite Basin Creek or Ketchikan Lakes) or depths during critical temperature periods. FS requires that KPU develop and implement a plan to monitor water temperatures of dam seepage flows in the bypassed reaches of Ketchikan and Granite Basin Creeks downstream of the project dams (FS condition 113). KPU should design the monitoring study with ADF&G and the FS, and implementation should start within 1 year of license issuance. Staff Analysis The project has altered the flow regime in Ketchikan Creek downstream of the Ketchikan Lakes and in Granite Basin Creek downstream from the project diversion dam. These altered flow conditions have undoubtedly changed water temperatures compared to pre-project conditions. Some of the changes would tend to increase water temperatures and others would tend to decrease water temperatures in the project-affected stream reaches. Table 14 lists some of the ways the project may affect water temperature. Based on the project effects listed in table 14, we find no basis to conclude whether the water temperatures in the bypassed reach and downstream from the project tailrace have increased or decreased as a result of project facilities and operations. The water temperature in the bypassed reach of Ketchikan Creek just upstream of the project tailrace, does not represent pre-project water temperatures and should not be used as a baseline for establishing temperature criteria for project waters or Ketchikan Creek below the project tailrace. The flow in the bypassed reach is normally small compared to project flows and, except for direct runoff during rainfall events, derives from seeps, springs and leakage at the Granite Basin Creek diversion dam. We would expect 54 these sources to be cooler than the water coming from the Ketchikan Lakes and, probably, cooler than the pre-project stream temperatures that would have resulted from the mixing of the cooler Granite Basin Creek waters with the warmer and higher volume, surface waters coming from Ketchikan Lakes. Table 14. | How the Ketchikan Lakes Project affects water temperatures. (Source: Staff) How project facilities and operations may increase water temperature: How project facilities and operations may decrease water temperature: == Damming the outlet of Ketchikan Lakes increased the lake surface area exposed to solar radiation. (Because the canyon walls are steep, the increase in area is fairly small.) The outlet from Ketchikan Lakes is at elevation 310, fifteen feet below the surface when the lake is at maximum drawdown elevation of 325; under pre- project conditions, water spilled to the creek from the warmer surface waters of the lake. The water conveyance system from Ketchikan Lakes to Fawn Lake includes an 1,800-foot-long above ground pipeline that may contribute to higher water temperatures on sunny days. The project tunnels and pipelines shield the water from the sun, decrease the travel time and may, also, cool the water under some flow and atmospheric conditions. Fawn Lake increases the surface area and exposure time to solar radiation. Because the Granite Basin Creek diversion has no storage, the project is operated to make maximum use of the Granite Basin Creek flows, which are cooler than Ketchikan Lakes; under some conditions, this probably results in a higher proportion of the flow below the project coming from Granite Basin Creek. The ADF&G and FS recommendations for monitoring the water temperature of leakage flows from the Ketchikan Lakes dam and the Granite Basin Creek diversion are intended to establish a baseline water temperature for project leakage flows to serve as a temperature criteria for KPU to adhere to if it ever takes steps to reduce or eliminate the leakage and make up the loss to the bypassed reaches by other means, such as dedicated minimum flow release devices. We agree that future operation of the project should maintain existing flows in the project bypassed reaches, and that the temperature of those 55 flows should be maintained at comparable levels to existing conditions, if the licensee changes the means for providing these flows. Dam leakage water temperatures are normally fairly constant. Because of the difficulties of monitoring in remote locations and under severe weather conditions, we agree with the FS requirement for KPU to consult with the agencies and develop a plan for monitoring water temperature (along with leakage flow) for a period of up to 5 years. ADF&G says that the natural spawning/incubation of king salmon is hampered by water temperatures in excess of 12°C (letter to Ed Fleming, Greystone Consultants, from Ruth M. Lewis, Assistant Area Habitat Biologist, Alaska Department of Fish and Game, Ketchikan, Alaska, August 12, 1997). ADF&G reports that the Deer Mountain Hatchery must contend with excessive water temperatures from August through October, and currently the hatchery uses refrigeration to cool the water to reduce early pre-emergence of fry. We find no basis to support NMFS’ recommended tailrace maximum water temperature criteria of 16°C. There is no evidence that water temperatures in the lower Ketchikan Creek (below the tailrace) are higher than they would be without the project, nor is there any evidence of any adverse effects on the stream fishery caused by water temperatures. The hatchery has already provided protection against water temperature related losses by the installation of refrigeration equipment to maintain proper water temperatures in the hatchery tanks. In conclusion, we recommend that KPU consult with NMFS, FWS, FS, and ADF&G to develop and implement a plan to monitor existing leakage flows from the Granite Basin Creek diversion dam and The Ketchikan Lakes dam. This information would be used to establish baseline water temperatures of leakage flows for use in the event that KPU decides to take any action to reduce or eliminate leakage. If KPU repairs the leakage from the dams, it would maintain equivalent flows and the water temperatures of those flows by other means. Instream Flows and Stream Flow Gaging Starting at zero flow conditions, fish habitat for most life stages increases to maximum levels with increases in flows. Flows greater than those needed to produce the maximum habitat levels can reduce habitat, depending on physical stream channel conditions and species and life stages of interest. KPU proposes to maintain the existing minimum instream flow release at the project tailrace of 35 cfs, which includes 4.5 cfs to the Deer Mountain Hatchery. The 4.5 cfs flow to the hatchery is more than the state's 2.5 cfs water right. KPU would also install 56 flow-measuring weirs below the Ketchikan Lakes dam and Granite Basin diversion dam to monitor the existing leakages. The leakage flows that are measured during the first two years of monitoring would be maintained throughout the next license period. To better determine the seasonal pattern of flows in the bypassed reach of Ketchikan Creek, KPU proposes to monitor the flow immediately upstream of the tailrace for five years (June 10, 1999 letter to the Commission from Karl R. Amylon, General Manager, KPU). ADF&G and NMFS recommend that KPU release a minimum flow of 47 cfs into Ketchikan Creek below the tailrace and provide 4.5 cfs to the Deer Mountain Fish Hatchery. KPU says that it has historically discharged more than the required 35 cfs minimum flow (Greystone, 1998c). The project's normal minimum generation level is 600 kW, which relates to a discharge of 45 cfs. The agencies' 47 cfs recommendation is based on their goal of maintaining at least the historic amount of habitat in Ketchikan Creek below the project tailrace. During a project Operation Inspection conducted on June 28- 29, 1999, KPU indicated that it has historically released at least 47 cfs below the tailrace (letter from Clayton Hawkes, Alaska Department of Fish and Game, Douglas, Alaska, July 14, 1999). KPU says that, while they do not object to operating at 47 cfs under normal conditions, they oppose increasing the minimum flow required by the license because they have already made capital improvements to ensure the 35-cfs flow requirement would be met in the event of an upset causing the plant to go off line (August 13, 1999, letter to the Commission from Karl R. Amylon, General Manager, KPU). ADF&G and FWS recommend and FS requires that KPU maintain the existing long-term average dam leakage flows below the project dams (FS condition 113). ADF&G and FWS recommend that this flow be equal to or greater than the actual amount of the leakage flows measured during the first five years of leakage monitoring. To guarantee that the minimim flows are always provided, ADF&G recommends that KPU: (1) maintain continuous flow recording devices to monitor the flows in Ketchikan Creek below the tailrace; (2) measure the instantaneous dam leakages for a period of 5 years; (3) report monitored flows and lake levels to the state on a quarterly basis; and (4) hold annual project review meetings with the resource agencies. The FS requires that KPU develop, within 1 year following the date of issuing the license, a monitoring study plan for the project bypassed reaches. The purpose of the study plan is to monitor water seepage quantity and temperatures in the bypassed reaches 57 below the project dams (FS condition 113). The study would determine the relationship between lake levels and down stream seepage flows. A correlation would be made for the range of lake levels between the spillway and 327 feet, or the lake levels which occur during the first 5 years following issuance of the license, whichever requires the shorter time. The plan would be a joint effort of the FS, KPU and ADF&G. Ata minimum, the study plan would require KPU to monitor the dam seepage flows below both the Ketchikan Lakes dam and the Granite Basin diversion dam. Staff Analysis Bypassed reaches: The project bypasses flows from 1.34 miles of Ketchikan Creek (Ketchikan Creek bypassed reach) between the Ketchikan Lakes dam and the project tailrace, and 0.45 miles of Granite Basin Creek (Granite Basin Creek bypassed reach) below the Granite Basin Creek diversion dam. The existing license does not require minimum stream flow releases in either of these bypassed reaches, and none are proposed by KPU. Due to a migration barrier, the lowest 0.25 mile of the Ketchikan Creek bypassed reach is the only section of Ketchikan Creek accessible to anadromous fish. Accretion flows to the bypassed reach average 10 cfs and a minimum low flow of 3.6 cfs has been measured upstream of the tailrace. These natural accretion flows are less than the flows that would be available in this reach without the project and reflect a contributing watershed of less than two square miles, compared to Ketchikan Creek's 13.5 square mile watershed size. However, the existing hydrograph for this reach parallels a natural hydrograph in an area that receives an average of 155.22 inches of precipitation per year; higher flows are observed from September through May, and lower flows are observed from June through August. The project also diverts water from Granite Basin Creek, an upper tributary of Ketchikan Creek, to Fawn Lake. Because the diversion tunnel’s capacity is 160 cfs, compared to Granite Basin Creek’s mean annual flow of 32 cfs, the diversion dam rarely spills. The Granite Basin Creek bypassed reach is about 2,400 feet (0.45 miles) in length, and receives flows from a 146-acre watershed. Flows are reduced in this reach by about ninety percent compared to natural conditions. This bypassed reach supports subsurface flows during periods of low precipitation, but does not have sustained surface flows. The reach does support a small year-round fishery in the lower half of the reach. KPU proposes to divert all of the flow -- except leakage -- in the Ketchikan Creek and Granite Basin Creek bypassed reaches. Due to an impassable, 5-foot-high falls located 1,284 feet (0.25 mile) upstream of the tailrace, reduction of flows in the Ketchikan Creek bypassed reach primarily affects resident fish. This reach has poor spawning habitat; good potential spawning habitat only exists upstream of the falls. The Granite 58 Basin Creek bypassed reach contains only resident fish. Although no quantitative estimates are available, diverting the flows from the project’s bypassed reaches reduces their aquatic resources productivity. The staff believes that the leakage flows below the Ketchikan Lakes dam is related to the upstream lake elevations. Once the relationship between lake elevation and leakage flow is established, historic lake elevations could be used to help estimate the current baseline leakage flow. KPU should be able to determine this baseline leakage flow in one field season. Ketchikan Creek below the tailrace: The flow regime below the powerhouse is affected by KPU’s use of project flows for power and municipal water supply. The flow in this reach may be higher or lower than natural, pre-project flows, depending on the time of year. However, there are no gaged records of pre-project flows and KPU considered it impossible to simulate them. Therefore, it is not known how much the project affects the stream flows in this reach. From a review of all the available data on lake elevations, precipitation, and generation, the following general statements can be made about the influence of the project on this reach: iB Minimum monthly flows are greater than the dry period natural flows; 2 Average monthly flow is frequently reduced, compared to the high natural flows; and 8: Average daily flows are not greatly affected. The operation of the hydroelectric project modulates flows in the reach below the tailrace, decreasing the peak flows and increasing the low flows. KPU’s operations provide higher average summer flows below the tailrace, which would benefit the stream’s fishery. The moderate reductions in flows during the high precipitation periods would have little effect on the fishery. While the effect on the habitat of the existing 35-cfs minimum flow requirement has not been quantified, a self-sustaining pink salmon fishery exists in Ketchikan Creek below the tailrace. Pre- -project low flows were measured as pee as 3.6 cfs before KPU implemented the 35-cfs minimum flow requirement. The project started operating in 1903 and no data on the unregulated flows in the area exists. The ADF&G’s instream flow study (ADF&G 1988) indicates that the seasonal flow request they have made to the state would improve the fishery over the current regulated flows. Because these requested flows would only be considered by the state if and when the project is no longer in operation, and are not considered an ADF&G section 10(j) recommendation, we do not analyze them in this EA. 59 We agree with the objective of ensuring that the existing minimum flows continue to be provided during the term of a new license. Since existing flows include occasions when the flow through the project reduces to the 35 cfs provided by existing automated flow continuation devices, we recommend requiring a minimum flow of 47-cfs except when the plant is tripped off-line by an emergency or when flow and storage conditions necessitate reducing the flow through the turbines to 35 cfs to avoid drawing the reservoir down too low. In addition, we recommend that KPU continue to provide 4.5 cfs to the Deer Mountain Fish Hatchery and develop a plan to monitor project flows, in consultation with NMFS, FWS, FS, and ADF&G. Ketchikan Lakes fishery Project-related drawdowns and fish entrainment from the Ketchikan Lakes could reduce the lakes’ fisheries potential. The Ketchikan Lakes are inhabited primarily by non- native brook trout. Fishing is currently prohibited to help maintain the water quality of the Ketchikan domestic water supply. KPU proposes to continue to restrict fishing in the project lakes until a need to install a filtration system for the domestic water supply is determined. At that time, fishing access to Ketchikan Lakes may be allowed. KPU proposes to conduct a lake fishery study at that time. If and when recreational access is allowed to Ketchikan Lakes, FWS and ADF&G recommend that KPU conduct a study to evaluate: (1) the status of the lakes’ fishery; (2) the impacts of the project on these populations; and (3) measures to improve the fishery. If and when recreational access is allowed to Ketchikan Lakes, the FS would require (FS condition 111) that KPU evaluate: (1) the status of the fisheries habitat in the tributary streams to Ketchikan Lakes; (2) the impacts of the project, specifically the lake level fluctuations and temperatures, on these populations; and (3) measures to manage the fishery to meet the Forest's goals and other agencies' resource management plans. Until the Lake Habitat study is completed, the FS requires that the lake levels not be drawn down lower that the lowest level recorded during the period between 1990 and 1995 (327 feet), unless otherwise agreed to by the FS, and ADF&G for emergency operations . Staff Analysis The existing brook trout population was established after the project was constructed and operating, and has sustained itself under the lakes’ existing fluctuation conditions. KPU minimizes the lake level fluctuations in Fawn Lake to reduce turbidity in the municipal water supply. The project’s water intake at Ketchikan Lakes is located away from the shoreline fisheries habitat area. Surveys conducted in 1997 found no fish near the entrance to the 60 Granite Basin diversion tunnel. Therefore, there is little potential for fish entrainment at the project. The staff recommends that if the lakes are opened to recreational fishing in the future, KPU conduct a study of the lakes’ fishery and develop a lake fishery management plan. The study would identify the status of the existing fishery and mitigation needs, and the plan would provide future management strategies. The plan would be developed in consultation with ADF&G and FWS, and be filed with the Commission for approval. Ramping Rates and Gaging Ramping rates are controlled changes in the flow rates over periods of minutes, hours, or days. Rapid flow changes in a stream can be immediately lethal or have indirect delayed biological effects (Hunter 1992). KPU proposes to install remote water level monitoring equipment at Fawn Lake (SCADA system) to better anticipate the turbine intake flows. This would help KPU to minimize the project’s ramping rates. Impacts of project ramping rates are reduced during high flow periods, when higher flows in the upstream bypassed reach dampen the effects of the project tailrace flows. To determine how much these bypassed reach flows help to dampen the effects of the tailrace ramping rates, KPU proposes to monitor the stream flows in Ketchikan Creek upstream of the tailrace for a period of five years. ADF&G recommends ramping rates which are based on criteria developed by the Washington Department of Fish and Wildlife (WDFW)(Hunter 1992), but modified to meet the local fisheries timing needs (table 15). Table 15. | Ramping rates recommended by ADF&G. (Source: Staff) September 15 (0.083 feet/hour) Season Daylight Rates! ight Rates February 16 to No Ramping 2 inches/hour May 31 (0.167 feet/hour) rh June | to 1 inch/hour 1 inch/hour (0.083 feet/hour) September 16 to February 15 2 inches/hour (0.167 feet/hour) 2 inches/hour (0.167 feet/hour) Daylight is defined as 1 hour before sunrise to | hour after sunset. The February 16 to May 31 period rates are designed to protect emergent pink, chum, and coho salmon fry. The June 1 to September 15 period is designed to protect 61 emergent steelhead and rainbow trout fry. The 2 inches/hour maximum rate during the remainder of the year is designed to protect rearing juvenile coho salmon and steelhead trout and resident fishes. These species rear in freshwater for a year or more before migrating to the marine environment. FWS requires that KPU limit the project ramping rates to 30 cfs/hour, and ensure that this rate is not exceeded in the event of a load rejection or other circumstances that may abruptly reduce the flow from the project tailrace. To guarantee that the ramping rates are not exceeded, ADF&G recommends that KPU: (1) maintain continuous flow recording devices to monitor the flows in Ketchikan Creek below the tailrace; (2) report monitored flows and lake levels to the state on a quarterly basis; and (4) hold annual project review meetings with the resource agencies. The FS requires that KPU install and maintain gages and stream-gaging stations for the purpose of determining the stage and flow of the stream or streams on which the project is located (FS condition 112). The number, character, and location of gages, meters, or other measuring devices, and the method of operation shall at all times be satisfactory to the Commission... Staff Analysis In response to power demands, KPU operates the project with hourly fluctuations in flows below the powerhouse. Hourly generation records acquired for fifteen days in 1995 show a maximum normal ramping rate of 900 kW in thirty minutes -- equivalent to a change in flow of 50 cfs (Greystone 1997). Within a 24-hour period under current operations, it is not unusual for the tailrace flow to increase from 125-175 cfs, decrease to 35 - 40 cfs, and then increase again to 125 - 175 cfs. Larger project ramping rates occur (two to six times per year) for short periods of time when a turbine and generator are tripped off-line, but this is not a routine operating condition. ADF&G reports that project downrampings have resulted in high mortality to rearing juvenile fish in Ketchikan Creek downstream of the tailrace (Denton 1996; and letter from Clayton Hawkes, Hydro-review Coordinator, Alaska Department of Fish and Game, Douglas, AK, December 4, 1998). Quantitative estimates of these reports are not available. In response to agency concerns, KPU conducted a study to calibrate the turbines’ flows (cfs) to power outputs (kW) and calculate historic project hourly ramping rates (cfs) in the tailrace (Greystone 1998). The study showed that the project doesn’t routinely ramp up and down to follow daily load changes. Most of KPU’s system load following is done from their Swan Lake Project, but the Ketchikan Lakes Project can be used during the loss 62 of transmission or a unit at the Swan Lake Project. During this type of situation, it may be necessary to ramp Ketchikan Lakes more than they usually would. KPU tries to operate the Ketchikan Lakes Project to maintain a constant penstock pressure while avoiding the lake level fluctuations which would create turbidity in the domestic water supply. KPU showed that under normal conditions the project is ramped at rates of 30 cfs/hour (500 kW/hour) or less. However, it is not unusual for the ramping to continue for two hours or more to meet system requirements. During the fall of 1998 the maximum ramping rates appeared to be less than 1 cfs/minute (letter from Larry Keith, Project Manager, Greystone Environmental Planners, Scientists, and Engineers, Greenwood Village, CO., January 14, 1999). KPU analyzed the project’s ramping rates during three consecutive days during the months of January, June, August, and December, 1995, and an additional four intervals of ten days each in 1998. The time periods studied in 1995 were considered representative of daily load and generation patterns throughout the year. Uprampings and downrampings exceeding 30 cfs occurred once per 19 hours and once per 44 hours, respectively, for the days analyzed in 1998. Sixty cfs/hour was exceeded 13 times in 960 hours (5 downrampings and 8 uprampings) for the days analyzed in 1998. KPU says that 96 percent of the time the project operates within five of the six Hunter (1992) criteria (30-50 cfs/hour). They also indicate that they need some ramping flexibility during ADF&G’s recommended "no ramping" daylight period to maintain pressure in the municipal water supply system and to provide power when needed (letter from Larry Keith, Project Manager, Greystone Environmental Planners, Scientists, and Engineers, Greenwood Village, CO., January 14, 1999). Using what KPU considers their current average ramping rate (30 cfs/hour) and the channel depths measured at various flows in Ketchikan Creek below the tailrace (see table 4), staff calculated a maximum ramping depth between measured stream flows of 0.103 feet/hour -- calculated for flow changes between 36.1 and 100 cfs in the 0.02-mile-long, 59-foot wide section of Ketchikan Creek below the tailrace (table 16). The ramping depths of all other flow changes analyzed (100 to 200, 200 to 300, and 300 to 500 cfs), for both channel sections, were 0.075 feet (0.9 inches) or less. Except for the no ramping criteria during the February 16 - May 31 daylight period, KPU would be able to meet ADF&G’s recommended ramping rates. 63 Table 16. _ Estimated change in depths with a ramping rate of 30 cfs/hour for two stream channels in Ketchikan Creek below the tailrace. (Source: KPU) 59-foot wide section of Ketchikan Creek below tailrace Flow (cfs) Ramped Average ramping depth change per 30 cfs flow change (ft) 86-foot wide section of Ketchikan Creek below tailrace Flow (cfs) Channel depth Ramped depth Average ramping depth change per 30 cfs flow change (ft) 200 0.58 0.2 0.06 300 0.74 0.16 0.48 500 1.01 0.27 0.41 Staff recommends that KPU not exceed ADF&G’s ramping rates during the period June 1 to February 15. For the February 16 - May 31 daylight period, staff recommends that KPU limit project ramping for the sole purpose of maintaining the water quality of the municipal water supply, and not exceed | inch (0.083 feet) per hour. KPU is currently operating with average ramping rates similar to FWS’s required 30 cfs per hour (1 inch per hour); only ramping between flows of 36 and 100 cfs might exceed | inch per hour (0.103 feet per hour -- see table 16). We believe that ADF&G’s recommended ramping rates provide adequate protection for the critical periods when juvenile fish may be impacted. We also believe that our | inch per hour recommended ramping rate during the February 16 - May 31 daylight period would allow KPU to maintain its water quality standards while providing only slightly less protection for incubating eggs and juvenile fish. Fisheries Habitat Enhancements KPU proposes to provide funding of $15,000 for the agencies to implement whatever stream habitat enhancement measures they choose. To provide mitigation for project-impacted salmonid populations, NMFS and FWS recommend that KPU prepare a habitat restoration/enhancement plan for Ketchikan Creek below the tailrace. The plan is to include specific measures for: (1) developing at least 2,000 square feet of rearing and holding cover; (2) improving shrubby perennial growth along the streambanks, and (3) other measures as recommended by fishery consultants and agency biologists. NMFS recommends a schedule for implementing these measures. ADF&G recommends that KPU modify the existing Ketchikan Creek fish ladder located below the project tailrace. ADF&G also recommends that KPU hold annual meetings with the resource agencies to review project-related study results and identify actions based on the results. In order to ensure passage from Ketchikan Creek into Schoenbar Creek, where a perched culvert carrying the entire flow of Shoenbar Creek restricts access during certain flows, NMFS and ADF&G recommend and FWS requires! that KPU develop and implement fish access and passage improvements at the mouth of Schoenbar Creek. Improvements would include a fish ladder or other structural modifications to ensure fish access into the existing culvert at all water levels. The licensee would measure or model water velocities inside the culvert to determine the benefit of including rocks or baffles within the culvert to reduce water velocities and provide resting spots for up-migrating fish. Since the Shoenbar Creek culvert is not a project facility and any obstruction placed within the culvert would reduce the flow capacity of the culvert and increase the risk of upstream flooding, we question the feasibility of and applicant responsibility for any measures beyond those that improve access to the culvert at its discharge point in Ketchikan Creek. Improving the access to the culvert may help to mitigate for project- related fish habitat effects by increasing the use of the Shoenbar Creek habitat. However, we do not believe KPU should be required to study measures that would clearly compromise non-project highway drainage structures. Staff recommends KPU limit its Under authority granted by section 18 of the FPA, federal fish and wildlife management agencies may prescribe facilities to provide for fish passage; such facilities are mandatory in Commission licenses. 65 investigation to improving culvert access, when flow conditions do not submerge the culvert invert where it enters Ketchikan Creek. ADF&G recommends and NMFS and FWS require that KPU prepare a report on the feasibility of removing the 5-foot-high anadromous fish barrier on Ketchikan Creek at the upstream end of the reach above the tailrace (reach K3). Staff recommends that KPU develop a project fisheries habitat enhancement plan to include the detailed design and feasibility of all of the structural habitat measures recommended and required by the agencies. The plan would be developed in consultation with ADF&G, FWS, and NMFS, and be filed with the Commission for approval. Unavoidable Adverse Impacts: Project operations affect the resident and anadromous fisheries potentials of Granite Basin and Ketchikan Creeks. Staff recommended measures would enhance existing conditions and mitigate project impacts. 5. Terrestrial Resources Affected Environment The Ketchikan Creek watershed is mostly covered by upland forest. The vegetation communities have been mapped by the Forest Service (FS) in the project area and in the surrounding watershed. Non-forested community descriptions have been developed from the Alaska Vegetation Classification (Viereck et al. 1992) and Identification, i i lineati Wetlands Using Soils and Vegetation Data (DeMeo et al. 1989). The forest is classified as a coastal old-growth rain forest. The dominant forest types in the project area are cedar, spruce, hemlock, hemlock-spruce, red alder, alder brush, and wetlands. Table 17 is a brief description of the mapped communities. Wetland communities are common in the project area, and reflect the abundance of surface and groundwater within the region. Project wetlands are defined as either being Lacustrine systems (associated with Ketchikan, Scout and Fawn Lakes) or Palustrine systems (supporting forested, emergent or shrubby vegetation) according to definitions by Cowardin et al. (1979). Table 18 lists the five major wetland types found in the project area and mapped on the National Wetland Inventory maps. Muskeg communities contain a variety of bog related plant life, such as sphagnum moss, bog cranberry, sedge, and marsh violet. Shore pine, lodgepole pine, and yellow cedar are common trees of the forested wetlands, while burrweed, pondweed and aquatic buttercup are found along the shores of unconsolidated palustrine areas, lakes and ponds. 66 The diverse wildlife in the project area is distributed based on habitat, altitude, food availability, and proximity to water. Important species that characterize the area include the Alexander Archipelago wolf, black bear, bald eagle, Sitka black-tailed deer, river otter, beaver, ducks, swans, gulls, and ptarmigan. Table 17. | Dominant Vegetated Communities in the Project Vicinity. (Source: KPU, 1998) Type Habitat Project Area Cedar below 800' elevation single stand SE of Ketchikan dam Sitka spruce disturbed sites on alluvial not in project area floodplains Hemlock mountain hemlock above 200' | slopes to the east of Ketchikan elevation; western hemlock Lake below 200' elevation Western understory has Devil’s club, dominates slopes around Upper Hemlock-Sitka blueberry, salmonberry, skunk Ketchikan Lake, and on uplands Spruce cabbage in southern part of project area Red Alder represents the only broad- occupies less steep valley and leaved community; occupies alluvial bottoms in southern part moist and disturbed sites; of project area canopy cover is mostly closed Alder Brush common on steep slopes, not in project area floodplains, streambanks Wetlands -see Table 18- 67 Table 18. | Wetland Types Within the Project Vicinity. (Source: KPU, 1998) Wetland Type as defined by Cowardin et | Wetland Type as defined by DeMeo al. (1979) et al. (1989) Palustrine Scrub/Shrub (PSS4B, PSS1) Scrub-Shrub Evergreen/Muskeg Palustrine Emergent (PEM1B) Emergent Short and Tall Sedge Muskeg, Palustrine Forested (PFO4, PFO4, PFOSH) Forested Wetland Palustrine Unconsolidated (PUSC, PUBh, | Not Listed PUBH) Lacustrine Lakes and Ponds Environmental Impacts and Recommendations Continued operation of the project facilities would result in minimal impacts to forest and wetland vegetation types. Repairs or maintenance of existing facilities could result in the incidental, minor disturbance or localized removal of vegetation. When repairs and maintenance activities are completed, KPU plans to replace soil materials and minimize vegetation disturbance. Natural re-establishment of native vegetation is expected to occur. Because no new construction is planned, there would be no additional remos al of trees or other vegetation, and no changes to existing wildlife habitat would be expected In addition, no alteration to project wetlands would be expected because KPU plans no alterations to the project's water management or hydrology. Transmission Line Effects on Wildlife Scoping Document 2 identified that the powerline extending from the powerhouse to the city of Ketchikan could cause bird mortality due to potential collisions. We've determined that this line is non-jurisdictional to the relicensing of this project and that the Commission has no regulatory authority/control on the powerline. We therefore are not including this issue in this DEA. Unavoidable Adverse Impacts: None 68 6. Endangered, Threatened, and Sensitive Species Affected Environment Fe reat d End: The U.S. Fish and Wildlife Service (FWS) has not identified any threatened or endangered plant or animal species occurring within the project area (letter from John Lindell, Endangered Species Biologist, U.S. Fish and Wildlife Service, Juneau, Alaska to Cathy Begej, Greystone, Englewood, Colorado, June 17, 1996; Letter from Nevin D. Holmberg, Field Supervisor, U.S. Fish and Wildlife Service, Juneau, Alaska to Larry Keith, Project Manager, Greystone, Englewood, Colorado, December 5, 1996). However, it is possible that the federally endangered American peregrine falcon and federally delisted Arctic peregrine” could each occur in the area as seasonal migrants. American Peregrine Falcon: The American peregrine falcon breeds and raises its young in interior portions of Alaska but may pass through the Prince of Wales area during, seasonal migration. It is highly migratory and may winter as far south as Argentina. The American peregrine seems to have recovered in numbers as a result of restrictions on organochloride pesticide use (causes eggshell thinning and poor reproductive success) and because of successful reintroduction of captive-bred individuals. No organochloride pesticides are authorized for use on the Tongass National Forest. Because American peregrine populations in Alaska are increasing (Ambrose et al. 1988), the FWS has proposed removal of this species from the threatened and endangered wildlife list and the critical habitat designation (Federal Register Vol. 63, No. 165, August 20, 1998). Over 300 nesting pairs are known in Alaska (ADFG et al. 1994). Its principal prey are shorebirds and waterfowl, but it also consumes songbirds (ADFG et al. 1994). There is no designated critical habitat for the American peregrine in the project area and no individuals of this species have been observed in the project area. Arctic Peregrine Falcon: Like the American peregrine, the Arctic peregrine falcon populations declined after World War II as a result of organochlorine pesticides use. After over 20 years of restriction on the use of these chemicals, reproductive rates of arctic peregrines have steadily increased, and populations continue to rise. About 250 known pairs nest in Alaska and thousands nest throughout Arctic North America. Although the Arctic peregrine falcon was removed from the list of threatened and endangered species in November 1994, and is no longer protected under the ESA, the FWS must monitor this species for five years following its delisting. 69 Arctic peregrines nest in treeless tundra regions of Alaska, Canada, and Greenland and migrate through mid North American latitudes and winter in Latin America. This species occurs in southeast Alaska only during the migration periods (FS 1991). In Alaska, this subspecies nests mostly along rivers in the northern and western parts of the state. Nests are positioned on cliffs or bluffs usually near rivers or lakes that provide habitat for shorebirds, waterfowl, and songbirds on which the falcons prey. There has been no reported observation of the Arctic peregrine falcon in the project vicinity. Species of Concern The FWS maintains a list of plants and animals that could, at a future time, be listed as either a candidate, threatened or endangered species. Table 19 lists the species of concern that could be in the project area. Because data on the distribution, biology, population viability, and threats on these species is limited, the FWS is concerned with impacts on these species. No surveys were conducted by KPU for these species because no new structures are proposed and no changes to current project operations are planned. Table 19. Species of Concern that Could Occur in the Project Area. (Source: KPU) Potential Common Name Occurrence Preferred Habitat in Project Area Marbled Murrelet common marine near-shore waters for feeding; old-aged forested communities for nesting Queen Charlotte moderate select closed, multi-storied canopy nest goshawk sites; productive old-growth coniferous forests Harlequin duck remote along fast moving streams, creeks, and rivers for nesting Olive-sided possible open coniferous forest and forest edges flycatcher and clearings along lakes common correlates largely with black-tailed deer ES Sensitive Species ) There are 22 plant species that are listed as sensitive by the FS for the Alaska Region, but only two of these, goose grass sedge and bog orchid, are known to occur 70 within the Ketchikan area. Nine others are suspected to occur within the project area, based on presence of associated vegetation communities for each species. Table 20 lists the eleven FS plant and six animal Sensitive species that may occur in the project area. There are no identified unique or critical communities for Sensitive species within the project area. No surveys were conducted by KPU for these species because no new structures are proposed and no changes to current project operations are planned. Environmental Impacts and Recommendations Threatened/Endangered Species We find that the project would have no effect on the endangered American peregrine falcon and delisted Arctic peregrine falcon because: (1) these species have not been observed in the project area, (2) these species are only transient in the project vicinity and any use would be incidental and short-lived, (3) there are no critical falcon habitats identified in the project area, and (4) there would be no alteration or disturbance to the landscape. Therefore, this concludes our responsibilities for listed species under the Endangered Species Act. Species of Con Sensitiv We find that the project would cause no adverse impacts to the species of concern and FS Sensitive Species because: (1) no changes to project operations or maintenance is planned, (2) no new construction is proposed, (3) no landscape disturbance or alteration would be expected from this project, (4) none of these species have been observed in the project area, (5) no critical habitats for any of these species are known in the project area, and (6) some of these species have a low probability of occurrence in the Ketchikan Creek Basin. Development of a sensitive plant and habitat plan [FS 4(e) condition No. 121] would further ensure that these resources are protected in the event of any future land disturbing activity on project lands. Unavoidable Adverse Impacts: None 71 Table 20. U.S. Forest Service Sensitive Species That Could Occur in the Project Area. (Source: KPU, 1998) Potential Common Name Occurrence in Preferred Habitat Project Area lake margins, heath, wet meadows, kn 8 Goose grass sedge ove alpine/subalpine and open forest. 3 i d meadows, forest edges, along glacial Edible thistle suspectes een shallow freshwater, stream and lake Davy mannagras suspected margins grows in dense, humid coastal forests near Wright filmy fern suspected saltwater. Shaded cliff faces, bases of 4 if trees, decaying wood, rootwads. Truncate quillwort suspected shallow freshwater pools or ponds Al alpine-subalpine meadows, boggy slopes Calder lovage suspectet and rocky areas 5 heaths, muskegs, mossy upper beach Choris bog orchid suspected aes Bog orchid known wet meadows, expected in muskeg ed moist lowland forests, upper beach Loose-flowered bluegrass suspect manors Straight-beak buttercup suspected wet meadows alpine-subalpine meadows, shady wet Queen Charlotte butterweed suspected boggy areas, boggy/rocky slopes, open rocky heaths or grassy areas I moist and wet tundra habitats; only known Montague Island tundra vole low from Montaque Island nests in marshes, lakes, oxbows, in norther Tremoeter swan ow part of the Tongass nests close to lakes, streams, rivers in the Dusky Canadian goose low Copper River Delta region of south central Alaska nests in hemlock/spruce forests near Oetrey ee stream or coastal beach a 4 associated with large sea bird colonies on Roalo’s peregrine faloon! by outer coasts or nearby islands Queen Charlotte goshawk see Table 19 72 7. Aesthetics Affected Environment The Ketchikan Creek watershed provides the major vertical visual backdrop to the City of Ketchikan. Forest-covered Minerva Mountain at 2,602 feet rises north of town. The southern peak of the Deer Mountains is directly east of Ketchikan. The 3,001-foot peak summits above timberline. The tundra-covered ridge line runs north, paralleling the Ketchikan Lakes, with Roy Jones Mountain, Northbird Peak, and John Mountain all peaking at elevations above 3,000 feet. Small, high elevation alpine lakes, including Granite Basin, lie in cirques in the subalpine zone. Dude, Brown and Diana Mountains delineate the northern border of the Ketchikan Lakes watershed. They range in elevation from 2,848 feet to 3,014 feet and are all above timberline. The northern peaks are not visible from Ketchikan, but may be seen from the waterways surrounding Ketchikan. Principle locations from which a significant number of people would view project facilities are from the City of Ketchikan and from the Deer Mountain Trail. The facilities that are visible from the City include the powerhouse and substation at the south end of the penstocks within city limits. No other facilities are visible from the City. The penstocks are obscured from view by heavy vegetation. All other facilities are screened by the rugged topography and vegetation. Ketchikan Creek flows through the western half of the City of Ketchikan. The creek provides a scenic landscape that enhances the visual quality of the city's setting. The Deer Mountain summit is a popular destination hike for area residents and visitors. The trail switchbacks up the southern slope of Deer Mountain southeast of the Project’s power facilities, and provides scenic views overlooking Ketchikan, Tongass Narrows, and Ketchikan Lakes. The Ketchikan Lakes add visual variety to the uniformly forested and mountainous landscape for hikers who have attained the ridgeline on the Deer Mountain Trail. Project pipelines and penstocks are screened by vegetation, topography, and distance to views from the trail. The other facilities attract little viewer attention and do not dominate the landscape as viewed from the trail. Tongass National Forest Visual Resource Management. The Tongass NF has developed management directives for visual resources in enacted municipal watersheds. The visual resources of the Ketchikan District of the Tongass National Forest have been assessed and inventoried by the FS using the Visual Management System (VMS) guidelines (Forest Service, 1974). Visual Quality Objectives (VQOs) have been established for the area and are based on the management activities authorized in the watershed. VQOs are designed to provide objectives for visual management of the land and define the acceptable level of change that an action may introduce into the landscape. 73 The Ketchikan Lakes watershed has been inventoried by the FS and two VQOs have been assigned in this area: Retention (R) and Partial Retention (PR). Retention is the predominate VQO on FS lands within the Ketchikan Creek watershed. Upper Ketchikan Lake and surrounding slopes and slopes above the eastern shore of Lower Ketchikan Lake are a PR VQO area. Use of Ketchikan Lakes as part of the project did not change the pre- project character of the water, as it is a modification of a natural lake. Environmental Impacts and Recommendations Impacts to visual resources from the continued operation of the project facilities would be minimal and limited to short-term effects caused by clearing of vegetation above buried conduits needing repair or maintenance. Significant contrasts in color and texture would be addressed by the re-establishment of vegetative cover shortly after the completion of repair/maintenance activities. The development of a visual protection plan [FS 4(e) condition No. 118] would mitigate any impacts. Unavoidable Adverse Impacts: None. 8. Cultural Resources Affected Environment A cultural resource inventory and literature review was completed by Campbell (1997). A brief summary of the findings of that report is presented here The project is located on Revillagigedo Island in the State of Alaska within traditional territory of the Tlingit. Few archaeological investigations have been conducted previously in the project vicinity, but prehistoric and historic sites are known to exist in the area. Prehistoric and Native American sites that have been documented in the area include villages, camps, fish weirs, rock art, middens, culturally modified trees, totem poles and burial sites. The terrain around the project area is rugged, and most substantial settlements were probably located along narrow coastal strips or at the mouths of inlets. Improvements to the water supply system and power plant began in the early 1900s. Notable improvements included a water tunnel in 1903, a flume in 1906, a dam and a tramway in 1911, anew powerhouse in 1912, four dams in the early 1920s, and a vehicle road in 1957. Cultural resource surveys were conducted of the road, and of the tramway corridor following Ketchikan Creek. Five cultural features were identified and recorded by these surveys (KET-519 through KET-523). The first four are related to the Ketchikan water control and power facilities. The fifth feature (KET-523) is a stone fish trap of unknown age across Ketchikan Creek. The historic features were the ruins of the tramway 74 (KET-519), the abandoned power lines (KET-520), a wooden stave penstock (KET-521), and a storage alcove blasted out of the bedrock (KET-522). Environmental Impacts and Recommendations The documented sites retain poor physical integrity, and do not have the potential to yield information important in history. However, the project area exhibits the potential to contain buried cultural deposits that may not be visible to surface inspection. The currently proposed relicensing would not involve any ground disturbance, and would not affect any significant historic properties. If future developments involve ground disturbance, intensive surveys of these areas of potential effect should be completed to insure that no undocumented cultural resources are impacted. Development of the water and power supply systems for Ketchikan began in 1902, and improvements have continued periodically over the intervening years. The principal dam at Ketchikan Lake built in 1911 retains its log core, but is superficially a fairly typical earth and rubble structure. The rock-filled crib dams at the south of Ketchikan Lake are also comparatively nondescript. The fact that the combined capacity of the hydroelectric generation was among the largest in the region in the 1920s does not make these features historically significant. Little remains of the tramway but traces of its location. The powerhouse has been upgraded and replaced several times and does not retain any historic character. Similarly, the penstocks have been upgraded and replaced over the years and do not retain historic character. These features have played an important role in local history, and retain an integrity and continuity of function within the community. However, no unique or outstanding historic or engineering features remain, and the system as a whole retains little of the character of earlier episodes of historic importance. No aspect or feature of the water and power systems stands out as a property that should be considered for listing on the National Register, and improvements to the current and historic uses would be consistent with the integrity and continuity of function of these facilities. The State Historic Preservation Officer concurs that there would be no affect on any historic properties if there is no change in project facilities and operation (Letter from Judith E. Bittner, State Historic Preservation Officer, Alaska Department of Natural Resources, Office of History and Archeology, Anchorage, Alaska, June 29, 1998). However, a condition should be placed on any license issued that would require the appropriate measures should any cultural resources be disturbed during future operations and maintenance at the project. Unavoidable Adverse Impacts: None 75 9. Recreational Resources Affected Environment Outdoor recreation opportunities in the Ketchikan area and occur on public and private lands. State-owned lands surround the coastal City of Ketchikan and separate the city from the FS land located further inland. Traditional recreational uses of the local area have included hunting, hiking and fishing. Ketchikan is a popular vacation destination in southeast Alaska. In 1995, over 600 cruise ships docked at Ketchikan, bringing over 300,000 annual passengers. Sport fishing is a popular activity in southeast Alaska. Charter fishing sales have grown at the rate of 29 percent annually since 1988 in the Ketchikan Borough. The Project's study area for recreation resources includes the Ketchikan Creek watershed, which surrounds the project area. Most of the watershed and the project facilities are in the Ketchikan District of the Tongass National Forest. Although recreation Topportunities on FS-administered lands typically include hunting, fishing, hiking, backpacking, wildlife viewing, kayaking and boating; the project area, including Ketchikan Lakes and Fawn Lake, are closed to public access due to their use as the Ketchikan municipal water supply. By an Act of Congress dated July 27, 1939, the municipal water supply is protected jointly by the City of Ketchikan and the FS. The Act states that this land is ... reserved from all forms of location, entry, or appropriation, under the mineral or nonmineral land laws of the United States, and set aside as municipal water-supply reserves for the use and benefit of the people of the city of Ketchikan, a municipal corporation of the Territory of Alaska... Section 3 of this Act states that The Secretary of the Interior and the Secretary of Agriculture are hereby authorized to prescribe and enforce such regulations as may be found necessary to carry out the purpose of this Act, including the right to forbid persons other than those authorized by them and the municipal authorities of said municipal corporation from entering or otherwise trespassing upon these lands... The Tongass National Forest has developed objectives for recreation resources under the Municipal Watershed (MW) Land Use Designation. Under the MW land use, recreation uses can be authorized by the FS, in consultation with the municipality and will be limited to those uses that will protect water quality and flow. Developed Recreation. The Deer Mountain Trail is a National Recreation Trail in Tongass National Forest. The trail begins at the junction of Granite Basin and Ketchikan Dump roads, near the south end of the aqueduct. The trail switchbacks up the southern slope of Deer Mountain southeast of the project facilities, and provides scenic views 76 overlooking Ketchikan and Tongass Narrows. The Deer Mountain summit and the nearby Deer Mountain Cabin are popular destinations for locals and visitors. North of the summit, the trail is on public lands in the Tongass National Forest and for short segments, crosses portions of the Ketchikan Creek watershed. There are no other developed recreation sites within the watershed area. The Deer Mountain Cabin, which is maintained by the FS, is located on the eastern boundary of the watershed between the Deer Mountain summit and the next summit to the northeast. At one time several years ago, a tramway connected the city with a boat ramp, lodging and camping facilities at the south end of Lower Ketchikan Lake. The tramway and the facilities have been removed, and are no longer available for public recreational uses. The proposed Carlanna Lake Recreation Area is about 1.25 miles west of Minerva Mountain on the western watershed boundary. Carlanna Lake was operated by KPU as part of the city water system until 1982. Currently, KPU owns a one acre parcel occupied by the dam, and the surrounding watershed is managed by the Bureau of Land Management (BLM). The lake provides fishing and boating opportunities. Wilderness. There are several wilderness areas in southeast Alaska. The area nearest to the Ketchikan Lakes Project is the Misty Fiords National Monument Wilderness, located about eighteen miles to the east. Recreation Activities. Hikers occasionally trespass on the road between town and the lakes, and FS trails traverse the watershed. Fishing use along Ketchikan Creek below the fish hatchery increased between 1991 and 1994, with use of the creek ranging from 8 to 25 percent of the freshwater fishing in the Ketchikan area (an area including tributaries into waters stretching between Portland Canal and Emest Sound, including drainages on Duke, Annette and Gravina Islands). Ketchikan Creek is a hatchery and wild freshwater fishery. The creek provides fishing for several varieties of salmon and trout. The Deer Mountain Hatchery is located downstream of the hydroelectric plant, and is currently operated by the Ketchikan Indian Corporation. The project area is within State Game Management Unit 1. Various species of big game, fur animals, and small game and migratory birds are hunted in the unit. Big game includes black bear, brown bear, deer, goat, moose, and wolf. Most recreation opportunities in the region consist of activities in remote areas which are accessible primarily by boat or plane. The FS and the Alaska Division of Parks 77 and Outdoor Recreation currently provide some limited opportunities for roaded recreation. Recreation Opportunity Spectrum. National Forest lands are inventoried and mapped by Recreation Opportunity Spectrum (ROS) class to identify the type of recreation opportunities available on public lands. The ROS system categorizes Forest lands in six classes, each of which is defined by its setting and by the possible recreation experiences and activities it affords. Tongass National Forest lands in the Ketchikan Lakes watershed have been inventoried and mapped with three ROS classes; Roaded Natural, Semi- Primitive Non-Motorized and Primitive (USDA Forest Service 1996). The Roaded Natural (RN) class is characterized by a predominantly natural- appearing environment with evidence of moderate permanent resource alteration and utilization. Evidence of the sights and sounds of people is moderate, but in harmony with the natural environment. Opportunities exist for both social interaction and moderate isolation from the sights and sounds of people. Lands of this ROS class include the penstock corridor, most of Fawn Lake, and southern third of the lower Ketchikan Lake northeast of the coastal, urban lands of the City of Ketchikan. Semi-Primitive Non-Motorized (SPNM) class is characterized by few or subtle changes by people, with a high probability of isolation from the sights and sounds of people. Lands of this ROS class include portions of the project area east of Fawn Lake and areas east and west of the northern two-thirds of the lower Ketchikan Lake. The Primitive (P1) class is characterized by an essentially unmodified environment, where trails may be present but structures are rare, and where probability of isolation from the sights and sounds of people are extremely high. The upper Ketchikan Lake is surrounded by lands with the P1 ROS classification. Environmental Impacts and Recommendations The Ketchikan Gateway Borough - Parks and Recreation Plan surveyed the demand for recreation and identified the need for roaded recreation opportunities, and the need for additional sites for hiking, walking, bicycling, fishing, picnicking, and winter activities such as cross country skiing. Most survey participants indicated that they would be willing to drive up to 10 miles to reach a community recreation site. The Ketchikan Lakes watershed has the location and the resources to provide the focus for all of these activities. However, there is a direct trade-off between protecting the municipal water supply and providing public access. While the FS may authorize some limited activities in the watershed in consultation with the municipality, it must do so without compromising water quality. Additionally, the access road is controlled by KPU 78 to prevent unauthorized access to the watershed. KPU is concerned that should the water quality standards fall below the EPA standards, a water treatment facility would be required at an estimated cost of $20 million. KPU anticipates that a water treatment facility may be required at some time in the future as Ketchikan continues to grow. In this event, recreation opportunities could be made available for the public within the watershed. Meanwhile, recreation opportunities in the project area and surrounding watershed would remain unchanged under the proposed action. The use of upper reaches of the watershed by hikers using existing FS trails would also continue. Any license issued for the project should be conditioned to require KPU to notify FERC and the FS when a water treatment facility is authorized, and, at that time, require KPU to prepare a recreational development plan in consultation with the FS for Commission approval. Condition 119 of the FS' preliminary 4(e) conditions provides for such a plan and recreational development by the licensee in the event that water treatment facilities are found to necessary. Unavoidable Adverse Impacts: The continued restriction of recreational use of the Ketchikan Lakes is attributable to the water supply purpose of the project and cannot be avoided. Staff recommended conditions would mitigate this effect when, and if, KPU decides to add water treatment facilities. 10. Land Use Affected Environment Physical and environmental factors have played a significant role in affecting the course of land use development in the region. The mountainous terrain has effectively restricted settlement in Ketchikan to the narrow strip of land about 30 miles long bordering the Tongass Narrows. Residential, community, and industrial development extend less than one mile inland from the coast. Ketchikan's commercial and- industrial land uses are concentrated within the borough limits, as are the majority of residents. Land ownership within and adjacent to the project area consists of federal lands in the Tongass National Forest, state lands, and municipal lands within the Borough of Ketchikan. The project area consists of Ketchikan Lakes, Fawn Lake, and narrow corridors surrounding the tunnels and the access road. There are a total of about 863 acres within the project area, of which about 778 are managed by the Tongass National Forest, 50 are controlled by the Alaska State Mental Health Trust, 32 acres are within the Borough of Ketchikan, and 5 acres are private (see table 1). 79 More than 90 percent of the land adjoining Ketchikan is under the jurisdiction of the Tongass National Forest. Despite the predominance of federal lands, a shift in land ownership has occurred in and around the borough over the last 25 years. Federal lands have changed to state ownership as a consequence of the Alaska Statehood Act and to Native ownership pursuant to the Alaska Native Claims Settlement Act (Public Law 92- 203, 92nd Congress, H.R. 10367, December 18, 1971). Public lands surrounding the city were designated as State Mental Health Land by the U.S. Congress in 1956. Currently, the status and management of Mental Health Trust lands is being investigated to determine future management and uses. The Ketchikan Borough lies within the coastal zone of southeast Alaska. Land and water uses have been identified by the ACMP, and standards were developed for each use or activity. The nine major uses or activities are coastal development, geophysical hazards (developments in such areas), recreation, energy facilities, transportation and utilities, fish and seafood processing, timber harvest and processing, mining and mineral processing, and subsistence. Federal lands in Alaska are excluded from the coastal zone, pursuant to sec. 304(1) of the Coastal Zone Management Act of 1972. About 10 percent of the Project area is located within the coastal zone on non- federal lands. The only land use in the Project area is the operation of the existing project, which is a major energy facility under ACMP guidelines. Both the FS and the Native American Corporations actively harvest timber on their lands. Fishing and hiking comprise most recreational use in the area; motorized transportation is limited mostly to water craft, snowmobiles, and aircraft. There are few roads in the area. Subsistence uses consist of hunting, fishing and the use of other resources. Access to the Ketchikan Lakes and to much of the Ketchikan Creek watershed is restricted for recreational use due to minimum water quality requirements placed on KPU by the EPA as part of the recertification of the municipal water supply system. Tongass National Forest Land Management. The Ketchikan Lakes Municipal Watershed is reserved as a municipal water-supply by the Ketchikan Townsite Exclusion Act of July 27, 1939. The Tongass National Forest designates municipal watersheds with the land use designation MW (Enacted Municipal Watersheds). The Forest provides management directives for municipal watersheds. For the primary land uses within the watershed area, the land use designation standards and guidelines are: Facilities A. Construct no Forest Service Administrative facilities. Facilities such as dams, reservoirs, and pipelines are consistent with Land Use Designation objectives. 80 Fish A. Plan the construction and maintenance of fish improvement projects only if they are compatible with the municipal watershed objectives. 1s Restrict fish habitat improvements which result in reduced water quality for a municipality using the water from the affected stream. 2; When planning fish habitat improvement projects, consider the effects of anticipated municipal water withdrawals. Recreation A. Provide only for those activities and recreation use levels that can be accommodated without detriment to water quality and flow. B. _ Issue appropriate orders for regulating public use within the watershed, in cooperation with the municipality. Subsistence A. Permit subsistence activities in accordance with the federal, state, and local laws. Timber A. _ Forested land is classified as unsuitable for timber production. B. —_No timber harvest is scheduled. Salvage may be considered on a case-by-case basis in consultation with the municipality. Gs Personal use wood and Christmas tree cutting activities are usually incompatible with Land Use Designation objectives. Environmental Impacts and Recommendations Continued operation of the project facilities would not cause any change in land use in the project area. As no change in operations is proposed, no changes in adjoining land use due to the project are anticipated. Unavoidable Adverse Impacts: None. 11. Socioeconomics Affected Environment The Ketchikan Gateway Borough had a population of 14,728 in 1996, an increase of 6.5 percent from the 1990 population of 13,828. In the City of Ketchikan, there were 8,729 people in 1996, an increase of 6.6 percent from the 1990 population of 8,263 (State of Alaska 1996c). Ketchikan's per capita household income was $16,920 in 1990. The average household income for Ketchikan Gateway Borough was $46,114 in 1990, compared to $45,160 for the State of Alaska. The southeastern Alaska economy is based primarily on forestry, fishing, tourism and government services. Ketchikan is a major port of entry in southeast Alaska. The primary industries are timber and wood products manufacturing, fishing and tourism. Harvests of Western hemlock and Sitka spruce from southeastern Alaska yielded 810 million board feet in 1992 (Cheshire, 1993). The annual timber harvest includes 430 million board feet derived from the Ketchikan Gateway Borough and Prince of Wales Island. Timber is derived from the Tongass National Forest, whose southern portions surround the Borough of Ketchikan, and from private land managed by Native American Corporations. The lumber and wood products industry employed between 1,000 to 1,200 workers in the Ketchikan Gateway Borough during 1990, with total earnings amounting to $12 million (KPU, 1992). In 1991, timber industry employment accounted for 15.2 percent of the area's total employment and 18.6 percent of the wages earned in the area (Cheshire, 1993) The Ketchikan commercial fishery is based on salmon and halibut Pink salmon ts the major product, but runs of chum, king, coho and sockeye salmon are alye harvested Cod, dungeness crab and shrimp are also caught commercially There are twe cannenes in Ketchikan. The value of the Ketchikan fishery is more than $90 millon annually while providing more than 1,500 full time jobs (KPU, 1992). The average annual fishery salary in 1992 was $17,332. Active marketing of southeastern Alaska as a vacation destination has resulted in substantial increases in tourists. Cruise ship activity tripled between 1982 and 1992, resulting in an estimated 236,700 passengers in 1992. By 1995, over 600 cruise ships docked at Ketchikan, bringing over 300,000 annual passengers. Charter fishing sales have grown at the rate of 29 percent annually since 1988. Gross annual hotel/lodge business sales in 1992 was $5,176,713 (Cheshire, 1993). Retail and hotel and lodging employed 1,295 people in 1992 with average annual wages of $15,910. Federal, state and local government services supported about 1,860 employees in 1992, with an average annual income of $35,508. The federal government employed between 293 and 350 workers in the Ketchikan Borough depending on the season in 1992, predominantly in the FS, the U.S. Coast Guard and the U.S. Post Office. The State Government employed between 521 and 612 individuals and the local government employed 817 to 1,046 workers in 1992 (Cheshire, 1993). 82 Future economic growth in the borough is expected to occur in the tourism, construction and mining industries, U.S. Borax is currently evaluating the feasibility of developing a molybdenum mine at Quartz Hill. Most commercial construction is tied to the tourism industry. Current Projects include the Spruce Mill Development, a retail/office/lodging complex that will be completed by 2000. The timber and seafood processing industries face uncertain futures in Ketchikan (Tromble, 1996). Water is piped to businesses and residences in Ketchikan by KPU from Ketchikan Lakes and Fawn Lake. Power is provided by three hydroelectric plants owned by KPU (Ketchikan Lakes, Beaver Falls, and Silvis Lake), the state-owned Swan Lake Hydro Facility, and KPU’s diesel-fueled Bailey power plant. Currently, all of the water available in Ketchikan Lakes and at the Granite Basin diversion is utilized for municipal water supply and electric generation. The domestic water supply in Ketchikan currently ranges from a minimum of 2.5 million gallons to a maximum of 6.5 million gallons per day. This is equivalent to an average flow of 4 to 10 cfs. The water supply is taken from the penstock from Fawn Lake just before the water enters the powerhouse. The city landfill has recently been improved with a bale fill system, recycling and resource reuse. Refuse is also shipped out-of-state. There are seven public schools in Ketchikan Gateway Borough. Medical services are provided by Ketchikan General Hospital, Ketchikan Medical Clinic and the Southeast Surgical Clinic (State of Alaska; 1996a, 1996b). Environmental Impacts and Recommendations As operations of the project would continue unchanged, the project would continue to provide electricity to the KPU system and its customers. Services to residents of the Ketchikan area would remain mostly unchanged. Unavoidable Adverse Impacts: None D. _No Action Alternative Under the No Action Alternative, KPU would continue to operate the project as a source of both electricity and drinking water supply within the limits of its facilities and regulatory requirements. No changes in current use and management would occur and the recommended environmental measures would not be implemented. 83 VI. DEVELOPMENTAL ANALYSIS In this section, we analyze the project's use of the available water resources to generate hydropower, estimate the economic benefits of the project, and estimate the cost of various environmental enhancement measures and the effects of these measures on project operation. KPU is not proposing any modifications to project facilities. A. Power and Economic Benefits of the Project Based on the historical average for the last ten years, the project generates an average of 19,400 MWh annually. We use this average annual generation as the basis for our analysis of project economic benefits. We base the value of project power benefits on the current cost of replacement, assuming the power would be replaced by a diesel generation plant. KPU obtains electrical energy from five generation sources. Four of the generation plants are hydroelectric sites (Swan Lake, Silvis Lake, Beaver Falls, and Ketchikan Lakes). The fifth, Bailey, is a diesel generation plant. Other than hydropower, the only other source of electric energy is from diesel generation at Bailey, since the area served by KPU is not connected to any other utilities’ system. In 1995, KPU's diesel generation plants provided about 23 percent of its system energy needs while hydro generation accounted for the remaining 77 percent. The cost of diesel generation, therefore, is a reasonable proxy of project value for the purposes of our economic studies, which is to provide a basis for measuring the economic benefits of continued project operation. Our analysis is based on current costs, with no assumptions concerning future escalation or de-escalation of the various cost components included in the cost of project power or alternative power.> Although we do not explicitly account for the effects inflation may have on the future cost of electricity, the fact that hydropower generation is relatively insensitive to inflation compared to fossil-fueled generators is an important economic consideration for power producers and the consumers they serve. This is one reason project economics is only one of the many public interest factors the Commission considers in determining whether or not, and under what conditions, to issue a license. The current cost economic analysis is not entirely a first-year analysis in that certain costs, such as major capital investments, would not be expended in a single year. The maximum period we use to annualize such costs is 30 years. Also, some future expenses, such as tax depreciation expenses, are known and measurable, and are, therefore, incorporated in our cost analysis. 84 We base our analysis of the project's net benefits on the following economic information and parameters common to all the licensing alternatives: Net investment $4,216,0004 Annual costs Annual (O&M) $ 196,0005 Discount rate 8 percent Cost of money 8 percent Period of analysis 30 years Term of financing 20 years Power value Alternative power value 75.00 mills/kWh® Based on this information, the existing project (without any new environmental enhancements) annually generates an average of 19,400 MWh of electricity; has an annual power value, based on the current cost of the alternative power source, of $1,455,000; and costs $561,000, annually to operate, resulting in a positive annual net benefit of about $894,000 (or 46.1 mills/kWh). As described below, KPU's proposed enhancement measures would not change the amount of generation, but would increase the cost of operation (and, therefore, decrease the net benefits) by about $23,900’, annually, producing a positive net annual power benefit of about $870,100 (or 44.9 mills/k Wh). The additional enhancements recommended by staff would increase the cost of operation by $10,200, annually, reducing the total annual net benefits to $859,900 (or 44.3 mills/k Wh). Total capital investment as of December 31, 1995, rounded (Final Application for Hydropower License, at pg. D-1, June 30, 1998). 5 Id. Ketchikan Lakes Hydro Machine Calibration and Ramping Rates, Greystone, November 1998. Estimate includes costs associated with restoration of public access to Ketchikan Lakes. 85 B. Cost of Environmental Enhancement Measures Most of the measures proposed or recommended by the applicant, agencies, and staff would affect project economics by requiring capital outlays for construction, equipment and studies, as well as annual operation and maintenance (O&M) costs. The following is a brief discussion and the estimated costs for the environmental measures we consider in this EA. Water Quality Measures The estimated capital costs and levelized annual costs for the recommended water quality enhancement measures are presented below in Table 21. Most of these measures are related to water temperature -- to establish a baseline of temperature data for leakage flows in the event that KPU makes any repairs to reduce leakage from project dams. Instream Flows and Gaging The current license conditions require a year round minimum continuous flow of 35 cfs through the project. KPU proposes to continue this minimum flow which provides a minimum flow in Ketchikan Creek below the project of the 35-cfs project flow plus any flow in the bypassed reach. Flow in the bypassed reach consists of leakage flows from the Granite Basin Creek diversion dam and the Ketchkan | akes dam, and any incremental flow additions from the drainage area between the dams and the point where the Lulrace returns the project flows to Ketchikan Creek. Currently, none of these Hows are gaged The 35-cfs project flow is ensured by controls placed on the wicket gate valve arm of one of the turbines. Based on a review of its operating records KPU reported that, most of the time, the actual minimum flow has been 45 cfs®. Based on this information, ADF&G and NMFS are recommending a minimum flow of 47 cfs to ensure that existing minimum flows in Ketchikan Creek downstream of the tailrace will be maintained over the term of a new license. (We don't know why the agencies want 47 cfs instead of 45 cfs.) KPU says that, while they do not object to operating at 47 cfs under normal conditions, they oppose increasing the minimum flow required by the license because they have already made capital improvements to ensure the 35-cfs flow requirement would be met in the event of an upset causing the plant to go off line (August 13, 1999, letter to the Commission from Karl R. Amylon, General Manager, KPU). 5 ik: ro Machin jibration and Rampin, s, report by Greystone for Ketchikan Public Utilities, November 1998. 86 Table 21. Estimated capital costs and levelized annual costs of alternative water quality enhancement/mitigation measures. (Source: KPU, STAFF) Item Recommending | Cost Estimate Levelized Entity Annual Cost Treat condensate and leakage | FWS see note? see note® from project turbines and ADF&G other equipment prior to KPU discharge FS Monitor water temperature of | KPU Capital: $500 project leakage flows for one $3,800 year prior to any proposed improvements to Ketchikan O&M: Lakes dam during the next $1,400/yr license period Monitor temperature of ADF&G Capital: $800 leakage flows below Frs'° $3,800 Ketchikan Lakes dam and STAFF Granite Basin diversion dam O&M: for five years $1,400/yr Take corrective measures if Nmrs!! $3.1 to $5.0 $284,500 to tailrace water temperatures million"? $460,000 exceed 16° C This measure was completed in 1997; staff assumed that the O&M cost associated with this measure is included in the overall plant O&M cost. te FS requires and Staff recommends monitoring for 5 years, or less, if a relationship is found between leakage flow and the surface elevation of Ketchikan Lakes. " Corrective measures suggested by NMFS in their final terms and conditions include: deepening Fawn Lake, shading the surface waters of Fawn Lake, and/or selecting project flows from the coolest water bodies (Granite Basin Creek or Ketchikan Lakes) or depths during critical temperature periods. Cost estimated by KPU based on lowering the Ketchikan Lakes intake, which would require relocation in deeper water towards the middle of the lake, and replacing the above ground penstocks with buried conduit. 87 For our analysis we assume that there would be no additional cost for KPU to meet either the 35-cfs minimum flow currently required or, under normal operating conditions, the 47-cfs minimum flow recommended by the agencies. For KPU to ensure the continuation of a different minimum flow, including during project shut down, would require changes that could be costly and would be unnecessary, if the objective is to maintain existing minimum flows. The staff-recommended alternative would require a minimum flow of 47-cfs except when the plant is tripped off-line by an emergency or when flow and storage conditions necessitate reducing the flow through the turbines to 35 cfs to avoid drawing the reservoir down too low. We assume the staff alternative would impose no additional costs or loss of power benefits. Our analysis considers several alternatives proposed by KPU, the agencies and staff for monitoring flows. Table 22 lists the alternatives and their estimated cost. Ramping Rates A detailed description of the ramping criteria recommended by the ADF&G and FWS is presented in the aquatic resources section of this document. Based on the information on ramping project flows provided by KPU and Greystone, flow changes under normal conditions are within the agency-recommended limits except for ADF&G's zero ramping recommendation for daylight hours during the period February 16 to May 31. KPU could not meet this requirement because of the need to adjust flows to maintain water supply pressures and avoid drawing down Fawn Lake too low, which results in sediment in the water supply. Complying with a zero ramping rate requirement could require the construction of new water treatment facilities, which KPU says would cost about $20 million. The staff-recommended ramping rates are the same as the agencies’ but would allow KPU to ramp at a rate of | inch per hour in daylight hours from February 16 to May 31 and would not affect total project generation or have an appreciable impact on power value. To improve its ability to meet ramping rate limits and avoid water supply pressure and sediment problems, KPU proposes to add water level monitoring at Fawn Lake with remote readout at the operations control center to help the operators avoid water supply problems and abrupt changes in flow. ADF&G and staff both recommend this measure, which would cost about $8,300 (see table 22). 88 Table 22. _ Estimated capital costs and levelized annual costs of stream flow gaging alternatives. (Source: KPU, STAFF) Ttem Recommending Cost Levelized Entity Estimate Annual Cost Monitor flow for five years KPU Capital: $3,000 immediately upstream of Staff $15,000 tailrace (not according to USGS specifications) O&M: $4,500 Monitor leakage flow below | ADF&G Capital: $3,300 Ketchikan Lakes and Granite | FS $21,000 Basin diversion dam for five | Staff years O&M: $3,900 Install and maintain KPU Capital: $11,300 continuously recording ADF&G $25,000 devices which meet USGS FS specifications to monitor Staff O&M: flows within the anadromous $9,000/yr fish reaches in Ketchikan Creek Install and maintain remote KPU $8,300 $800 water level monitoring ADF&G equipment at Fawn Lake Staff Develop a project flow Staff $5,000 $500 gaging and reservoir stage monitoring plan Fish Habitat Enhancements The fishery agencies identified four structural fish habitat enhancement measures: (1) removing or modifying the 5-foot falls located about 1,300 feet upstream from the tailrace to allow fish passage and use of habitat above the falls; (2) improving access to Shoenbar Creek habitat which is restricted under some flow conditions by a non-project perched culvert through which the lower 300 feet of the Creek flows before entering Ketchikan Creek; (3) providing 2,000 ft? of structurally enhanced fish rearing habitat 89 downstream of the project tailrace; and (4) extending the existing fish ladder further upstream to reduce fallback potential. Staff added a fifth measure: requiring KPU to conduct a study in consultation with the agencies to develop the conceptual design, estimated cost and feasibility for each of the agency-recommended measures and to submit the study to the Commission for approval prior to the implementation of any measures the Commission determines would be best adapted to a comprehensive plan for development of the Ketchikan Creek watershed. Without the results of a study such as that recommended by staff, there is little basis for estimating the cost or determining the feasibility of most of the agency-recommended habitat enhancement measures. We estimate the study could be completed at a cost of $10,000. The following is a discussion of our preliminary cost estimates for the four measures recommended by the agencies. Removing the 5-foot falls For our economic analysis, we estimate that the 5-foot-falls, which is located in a narrow rock gorge and created by a fallen tree behind which some large boulders have lodged, could be removed for $5,000. Access to Schoenbar Creek The lower 300 feet of Schoenbar Creek flows through a six-foot diameter corrugated metal pipe culvert beneath a city street and parking lot. The invert elevation of the culvert where it discharges into Ketchikan Creek is higher than the water surface elevation of Ketchikan Creek under some streamflow conditions. Under such conditions, fish access to upstream habitat would be difficult, if not impossible. Suggested solutions to this problem include providing access to the culvert mouth under low flow conditions, providing baffles in the pipe invert throughout its length to make the flow deeper during low flow conditions in Schoenbar Creek, and removing or replacing all or parts of the culvert with a bridge. Modifications to improve fish access to and passage through the culvert, as recommended by the agencies, could range from replacing the culvert with a bridge to placing obstructions in the culvert invert. KPU estimates these measures would cost in the range of $125,000 to $140,000. For reasons given in the aquatics resources section, we do not agree with requiring KPU to study modifications within the existing culvert to aid fish passage, as recommended by ADF&G and required by FWS. KPU should not be required to investigate changes to the culvert that would reduce its flow capacity and increase the probability and magnitude of flooding in Shoenbar Creek. 90 The staff-recommended alternative is limited to improving the culvert entrance for fish access by constructing a grouted stone or concrete baffle in Ketchikan Creek at the entrance to the culvert to submerge the pipe invert enough to allow fish to enter the pipe. Fish access to the pool created by this baffle would be designed into the baffle. We estimate this would cost about $10,000. Fish rearing habitat Our estimate of $10,000 for providing 2,000 ft of rearing habitat is based on anchoring boulders or heavy timber at selected sites in the stream channel. We assumed a total of 10 sites, providing 200 ft’ per site and costing $1,000 per site. Extend Fish ladder The existing fish ladder located near the mouth of Ketchikan Creek was constructed to help fish pass a steep cascade located at the head of the tidal portion of Ketchikan Creek. The fish ladder was reportedly built prior to 1960. The need for extending the ladder, as recommended by ADF&G, was not discussed or brought up by any of the agencies during NEPA scoping. Our estimate of $25,000 is based on extending the existing reinforced concrete fish ladder an assumed distance of 50 feet along the right bank. Table 23 summarizes the estimated capital costs and levelized annual costs of the structural fish habitat enhancement measures considered in this DEA. 91 Table 23. _ Estimated capital costs and levelized annual costs of alternative fish habitat Public Access to the Ketchikan Lakes enhancements. (Source: KPU, STAFF) KPU proposes to continue to restrict access to Ketchikan Lakes. However, if KPU installs a filtration system for the domestic water supply, public access to the lakes could Item Recommending Estimate Levelized be restored. The costs of Ketchikan Lakes fishery enhancement and recreation measures Entity Cost Annual Cost shown in table 24 would be incurred only if public access to Ketchikan Lakes is restored. Modify/remove "5-Foot Falls" | FWS $5,000 $500 NMFS ADF&G Table 24. —_ Estimated capital costs and levelized annual costs of alternative Ketchikan STAFF Lakes enhancement measures. (Source: KPU, STAFF) EE tod | STAFE $10,000 $900 Item Recommending, Cost Levelized Entity Estimate Annual Cost Improve fish access to and FWS $125,000 $9,000 = 7 passage through Shoenbar NMFS to to acetal pe Ee oreo $45,000 $4,100 Creek culvert ADF&G $140,000 $10,000 Lakes, conduct a study of | FS Extend existing Ketchikan ADF&G $25,000 $1,800 the lakes’ fishery and STAFF Creek fish ladder STAFF develop a lake fishery management plan Improve 2,000 ft? salmonid FWS $5,000 $500 rearing habitat below the NMFS Reopen Ketchikan Lakes KPU $31,000 $2,800 tailrace STAFF to public recreation if STAFF ; water treatment facility is | Hold annual project review ADF&G $1,000 $1,000 constructed meetings with resources STAFF agencies If KPU decides to add FS unknown unknown . , water treatment, allowing | STAFF Provide $15,000 for removing | KPU $15,000 $1,400 public access to Ketchikan 5-foot falls, improving fish Lakes, it must conduct a rearing habitat in Ketchikan study, develop and Creek, and/or habitat/passage implement a plan for improvement in Schoenbar recreational use of the Creek Ketchikan Lakes Develop a plan for the STAFF $10,000 $900 conceptual design, estimated cost, and feasibility of iG Pollution Abatement Benefits removing 5-foot falls, passage to Shoenbar Creek, extension Continuing operation of the Ketchikan Lakes Project would benefit air quality and of fish ladder, and creating the environment because the need for fossil-fueled generation and the resulting pollutants 2,000 ft? rearing habitat and contribution to global warming would be avoided or minimized. 92 93 VII. COMPREHENSIVE DEVELOPMENT AND RECOMMENDED ALTERNATIVE Sections 4(e) and 10(a)(1) of the FPA require the Commission to give equal consideration to all uses of the waterway on which a project is located. When we review a proposed project, we equally consider the environmental, recreational, fish and wildlife, and other non-developmental values of the project, as well as power and developmental values. Accordingly, any license issued shall be best adapted to a comprehensive plan for improving or developing a waterway or waterways for all beneficial public uses. Based on our independent review of agency and public comments filed on this project and our review of the environmental and economic effects of the proposed project and its alternatives, we selected the proposed project, with staff-recommended modifications, as the preferred option. We recommend this option because: (1) issuance of a new hydropower license by the Commission would allow KPU to operate the project as an economically beneficial and dependable source of electrical energy for its customers; (2) the 4.2-MW project would eliminate the need for an equivalent amount of fossil-fuel derived energy and capacity, which helps conserve these nonrenewable resources and limits atmospheric pollution; (3) the public benefits of this alternative would exceed those of the no-action alternative, and (4) the recommended mitigation and enhancement measures would protect and enhance fish and wildlife resources; and would provide improved recreation opportunities at the project when the water supply protection restrictions are no longer required. The following summarizes the environmental enhancement measures we recommend be included in any license the Commission issues for the Ketchikan Lakes Project: * Measures proposed by KPU . Continue to operate and maintain the oily water separator installed in the powerhouse in 1997 to remove all oil from water before it is discharged into the project tailrace. . KPU would continue to manage the watershed to protect the water quality and would continue to operate Fawn Lake to minimize turbidity to protect the water . quality. . KPU would install remote water level monitoring equipment at Fawn Lake to allow greater lead times for making flow ramping decisions which would in turn enable a decrease in ramping rates. 94 . KPU would continue to provide 4.5-cfs flow to the Deer Mountain Fish Hatchery. . Use of the Deer Mountain Trail within the Ketchikan Lakes watershed would continue. . KPU would install weirs below both the Ketchikan Lakes dam and the Granite Basin diversion to monitor the seepage that currently occurs from the Ketchikan Lakes dam and the Granite Creek diversion and, if future repairs would reduce seepage, commits to maintain through some other means an amount of flow equal to the amount of the seepage flows measured during the first two years of seepage monitoring. . KPU would conduct flow monitoring for five years just upstream of the tailrace to measure seasonal variability of flows in the bypassed reach of Ketchikan Creek." The gaging would not be conducted to USGS specifications, but would obtain similar results. . If public recreation access is opened to Ketchikan Lakes, KPU would consult with ADF&G about conducting fish studies in Ketchikan Lakes. . If KPU constructs a water treatment facility, KPU would consult with the FS about reopening the Ketchikan Lakes watershed to public recreation. Additional Measures Recommended by Staff . Monitor the temperature of leakage flows from project dams for a period of up to five years. . Maintain a continuous minium flow through the project of 47 cfs, except in the event of a plant power trip or for the purpose of protecting the water supply purposes of the project, when the flow may be reduced to 35 cfs. . Limit ramping rates to obtain the following maximum stage changes in Ketchikan Creek downstream from the project tailrace: February 16 to May 31 1 inch per hour during daylight hours; 2 inches per hour maximum at night Le June 10, 1999, letter to David P. Boergers from Karl R. Amylon, General Manager, Ketchikan Public Utilities. 95 June 1 to September 15 1 inch per hour maximum September 16 to February 15 2 inches per hour maximum . Develop and implement a plan to monitor project flows and ramping rates, in consultation with NMFS, FWS, FS, and ADF&G. . Develop and implement a fisheries habitat enhancement plan showing the detailed design and feasibility of: (1) removing the five-foot barrier on Ketchkan Creek, (2) improving access to (but not passage through) the Shoenbar Creek culvert, (3) enhancing 2,000 square feet of salmonid rearing habitat, and (4) extending the existing fish ladder on Ketchikan Creek. The plan shall be developed , in consultation with NMFS, FWS, FS, and ADF&G. . Adopt appropriate measures if any cultural resources are disturbed during future project operation and maintenance activities. Additional Staff-Recommended Environmental Measures . The following is a discussion of the basis for the additional staff-recommended environmental mitigation and enhancement measures. Temperature Monitoring Water temperature is important to the Ketchikan Creek fishery below the project as well as to the fish hatchery, which is supplied water by KPU from the project tailrace. The project has altered the flow and temperature regime in Ketchikan Creek downstream of the Ketchikan Lakes and in Granite Basin Creek downstream from the project diversion dam. Some of the changes would tend to increase water temperatures and others would tend to decrease water temperatures in the project-affected stream reaches. We find no basis to conclude whether the water temperatures downstream from the project tailrace have increased or decreased as a result of project facilities and operations. One cannot conclude that water temperatures have been elevated by the project based on the observed lower temperatures in the bypassed reach just upstream from the tailrace. This relatively small flow is not representative of pre-project flows which would have been predominantly from surface waters coming out of Ketchikan Lakes. Under the existing conditions, the bypassed reach flow is mostly from springs and leakage from the Granite Basin Creek dam -- sources we would expect to be cooler than surface overflow from Ketchikan Lakes. We find no basis to support NMFS’ recommended tailrace maximum water temperature criteria of 16°C. There is no evidence that water temperatures in the lower Ketchikan Creek (below the tailrace) are higher than they would be without the project, 96 nor is there any evidence of any adverse effects on the stream fishery caused by water temperatures. The hatchery uses refrigeration equipment to maintain proper water temperatures in the hatchery tanks and to protect against water temperature related losses. Under NMFS' recommendation, recurrent incidents of prolonged temperatures exceeding 16°C would require corrective measures, such as: deepening Fawn Lake, shading the surface waters of Fawn Lake, covering the above-ground penstocks, and/or selecting project flows from the coolest water bodies (Granite Basin Creek or Ketchikan Lakes) or depths during critical temperature periods. We do not believe the high cost of such measures is justified, given the lack of evidence that the project has increased water temperatures or that water temperature is having a negative effect on the fishery of Ketchikan Creek below the project. Although there is no evidence that water temperatures are causing any problems for the stream fishery, or that the project is causing water temperatures to be elevated, we agree with the ADF&G recommendation and the FS' section 4(e) requirement for KPU to maintain the existing leakage flow and water temperature if it decides to repair the leaks . The FS requires KPU to develop a plan for monitoring water seepage flows and temperatures in the bypassed reaches for a period of five years, or less, if a correlation is found between lake levels and flow. We recommend that KPU consult with NMFS, FWS, FS, and ADF&G to develop and implement a plan to monitor existing leakage flows from the Granite Basin Creek diversion dam and the Ketchikan Lakes dam. This information would be used to establish baseline water temperatures of leakage flows for use in the event that KPU decides to take any action to reduce or eliminate leakage. If KPU repairs the leakage from the dams, it would maintain equivalent flows and the water temperatures of those flows by other means. Although we have no estimate for the cost of maintaining existing leakage flows and temperatures using alternative methods, such a measure would be suitable mitigation for the effects of reducing or eliminating dam leakage on aquatic resources. Minimum Flow The staff-recommended minimum flow of 47 cfs in Ketchikan Creek downstream from the project tailrace with a minimum of 35 cfs during plant outages or if needed to protect the water supply purposes of the project, is designed to ensure that the current minimum flow regime is maintained. Under current conditions, relative to minimum flow through the project, KPU strives to operate the project at a minimum flow of 47 cfs (even though the existing license only requires 35 cfs) because at lower flows the operating efficiency of the project turbines falls off. Allowing a minimum flow of 35 cfs during project outages and for the protection of water supply, would avoid the necessity of modifying the power plant's minimum flow turbine bypass system, and allow KPU to reduce the flows, as they do now, when needed to ensure an adequate and high quality 97 water supply. Although our recommendation is intended to maintain the existing minimum flow, and not as an enhancement of existing conditions, it would ensure that KPU does not change its operations to reduce the flows to 35 cfs on a regular basis. Ramping Rates The staff-recommended ramping rates are the same as the ramping rates ADF&G recommends except for the February 16 through May 31 (day time) period, when ADF&G recommends no ramping and we recommend allowing KPU to ramp the flows up to a rate of 1 inch per hour, if needed for water supply quality control purposes. Eliminating KPU's ability to ramp project flows for municipal water supply quality control purposes could put KPU in the position of having to choose between violating a license condition, risking public health or constructing a water filtration plant at a cost of about $20,000,000. FWS recommends downramping not exceed the rate of 30 cfs per hour, which is equivalent to an instream rate of about | inch per hour. The operating data KPU provided indicates that most of the time the project operates within this criteria, however, we don’t believe there is a biological need to restrict ramping rates to less than ADF&G’s recommended 2 inches per hour February 16 to May 31 (nights), 1 inch per hour June 1 to September 15, 2 inches per hour September 16 to February 15, and our recommended 1 inch per hour February 16 to May 31 (days). Our recommended ramping rates provide adequate protection for the critical periods when juvenile fish may be impacted. low: i it Ina June 10, 1999, letter commenting on agency recommendations for terms and conditions to include in a new license for the Ketchikan Lakes Project, KPU agreed to install a stream gaging station to USGS standards on Ketchikan Creek downstream of the project tailrace and to monitor Ketchikan Creek flows upstream of the tailrace for a period of 5 years. KPU is currently monitoring seepage flows from Ketchikan Lakes at several locations and has agreed to additional flow monitoring to establish a baseline for leakage from the Granite Basin Creek diversion. The agencies' flow monitoring recommendations include specific requirements that may differ somewhat from what KPU is proposing and other agencies are recommending. We are, therefore, recommending that KPU develop a plan, in consultation with ADF&G, FS, FWS and NMFS, for monitoring project flows and reservoir water surface elevations for approval by the Commission prior to implementation. We estimate the plan would cost KPU $5,000 or, about $500 per year over the 30-year period of analysis. The potential savings from a well designed monitoring plan is worth this cost. 98 Fisheries Habitat Enhancement The staff recommends that KPU consult with the agencies and develop a plan for implementing stream habitat enhancements. We recommend that KPU include, at a minimum, the following measures in the plan: 1) remove the 5-foot-high barrier on Ketchikan Creek; 2) modify the existing fish ladder on Ketchikan Creek; 3) improve 2,000 sq ft of salmonid rearing habitat in Ketchikan Creek below the tailrace; and 4) improve fish access to the culvert at the mouth of Schoenbar Creek. KPU proposes to provide funding of $15,000 for the agencies to implement whatever stream habitat enhancement measures they choose. Based on our economic analysis, these four measures would cost about $45,000, however, the exact cost cannot be determined until KPU develops final plans and feasibility studies. We do not recommend including the replacement of the Shoenbar Creek culvert with a new culvert or bridge, or measures that would involve placing structures within the existing culvert. We recommend that KPU prepare the plan, in consultation with ADF&G, FWS, NMFS and FS, and give the resource agencies the opportunity to comment on the plan before filing it with the Commission for final approval. Our estimated cost for preparing the fish habitat improvement plan is $10,000, or about $900 per year over the 30-year period of analysis. Cultural Resource Protection KPU is not proposing nor are we recommending any changes to project facilities. However, we recommend any new license contain provisions requiring KPU to take appropriate measures should any cultural resources be discovered or disturbed during future operations and maintenance at the project. In conclusion, from our evaluation of the environmental effects and public benefits of the project, we find that licensing the Ketchikan Lakes Project with our recommended environmental protection measures would best adapt the project to a comprehensive plan for the Ketchikan Creek drainage basin. Forest Service Requirem inder section 4(e The FS' preliminary conditions are included as Appendix A. According to section 4(e) of the FPA, any final conditions filed by the FS must be included in any license the Commission issues. VIII. CONSISTENCY WITH COMPREHENSIVE PLANS Section 10(j)(2) of the Federal Power Act requires the Commission to consider the extent to which a project is a consistent with federal and state comprehensive plans for 99 improving, developing, and conserving waterways affected by the project. Twenty-two plans are currently on the Commission list of comprehensive plans for the state of Alaska. Three of these plans address resources relevant to this project, and are discussed below. A. — Tongass National Forest Land and Resource Management Plan (LRMP) The LRMP divides the Tongass National Forest into management areas through Land Use Designations (LUDs) and it provides direction for managing activities in those areas. About 90 percent of the project area occupies National Forest system lands. The LUD for the Ketchikan Creek watershed, which includes 90 percent of the project area, is designated as Municipal Watershed (MW). Goals for this MW are to maintain the watershed as municipal water supply reserves, in a manner that meets State of Alaska Drinking Water Regulations and Water Quality Standards for water supply. Objectives to meet the goals for this LUD are to: 1. Limit-most management activities to the protection and maintenance of natural resources; fish habitat enhancements, and watershed and wildlife improvements, may occur if they are compatible with the municipality's watershed management objectives. 2. Classify forested land as unsuitable for timber production; salvage logging will only occur after consultation with the municipality. 3. Recreation uses will be authorized by the FS officer with delegated authority, in consultation with the municipality, and will be limited to those uses that will protect water quality and flow. The setting should generally be natural; however, facilities or structures to provide municipal water supplies may be present. Based on the analysis presented in this EA, the continued operation of the hydroelectric generation facilities and the diversion facilities for the municipal water supply would be consistent with the goals and objectives of the LRMP. Changes in water management and recreational access and use are not proposed. No new construction or facilities with accompanying disturbance are proposed. Use would be consistent with the Municipal Watershed LUD. B. North American Waterfowl Management Plan (NAWMP) The NAWMP sets goals for conserving North American waterfowl through cooperative planning and management. The plan provides the framework for a waterfowl 100 conservation effort by describing population and habitat goals and suggesting recommendations to resolve problems of international concern through the year 2000. The plan’s intent is to set the stage for the development of national, flyway, provincial, territorial, and state plans that contain specific management measures for waterfowl conservation in the United States and Canada. The plan recognizes that habitat loss and degradation is the major waterfowl problem in North America and sets habitat conservation as a top priority. Anticipated minimal impacts from the continued operation of the project would be limited to the temporary displacement of waterfowl from the Project’s lakes due to the other human activity involved in project maintenance. Due to the limited and minimal impacts likely to result from continued operations, the project would be consistent with the NAWMP. GCG: Alaska Outdoor Recreation Plan (AORP) Based on a survey of 2,865 residents, the AORP identifies citizen preferences and suggested actions to address outdoor recreation issues in the state. The plan identified the following issues: . The state needs to maintain its recreational land base. . The outdoor recreation needs of urban Alaskans must be met with sites near people’s homes. . Cooperation among agencies is essential to successfully meet state recreation needs. . Preserving and protecting Alaska’s culture and history is critical in maintaining the state’s distinct identity. . High quality outdoor recreation experiences must be perpetuated and enhanced. The project would have minimal affect on outdoor recreation. The relicensing of the project and the continuation of operations with no changes, including the continued restrictions for recreational use of the watershed along with continued use of existing recreational trails would result in no change to outdoor recreational opportunities in the Ketchikan area. Known and yet undiscovered cultural resources in the project area and surrounding watershed would likely remain undisturbed due to the limitations on access and activity posed by the federal designation of the watershed as a protected, municipal watershed. IX. RECOMMENDATIONS OF FISH AND WILDLIFE AGENCIES Under the provisions of Section 10(j) of the FPA, as amended by the Electric Consumers Protection Act of 1986, each hydroelectric license issued by the Commission shall include conditions based on recommendations provided by federal and state fish and 101 wildlife agencies for the protection, mitigation, and enhancement of such resources affected by the project, where those conditions are not inconsistent with the purposes and requirements of the FPA or other applicable law. Section 10(j0) states that whenever the Commission finds that any fish and wildlife agency recommendation is inconsistent with the purposes and requirements of the FPA or other applicable law, the Commission shall attempt to resolve any such inconsistency, giving due weight to the agency's recommendations, expertise, and statutory responsibilities. We are making a preliminary determination that all but three of our recommendations contained in this DEA are consistent with those filed by the agencies. The following is a discussion of our reasons for the recommendations we do not adopt because we find them to be inconsistent with the purposes and requirements of the FPA. We did not adopt NMFS or ADF&G's recommendations for minimum flows downstream from the project tailrace because requiring KPU to maintain an instantaneous release of 47 cfs instead of 35 cfs during unplanned shutdown events or certain low-water periods could jeopardize KPU's water supply, another project purpose, requiring them to provide water filtration or an alternative water supply source. The existing facilities are designed to release 35 cfs during project shutdowns. In addition, during certain low-water periods, KPU needs to limit its reservoir releases to avoid the addition of sediments into the domestic water supply; KPU estimates that water filtration would cost $20 million. As an alternative to an instantaneous minimum flow of 47 cfs all the time, we recommend a minimum flow of 47 cfs, except when: (1) a plant power trip activates the existing 35-cfs continuous flow bypass system, or (2) operating at a flow between 35 cfs and 47 cfs is needed to protect the water supply purposes of the project. We did not adopt FWS' recommended ramping rate requiring that flow reductions not exceed 30 cfs per hour, or ADF&G's requirement for zero flow ramping during daylight hours in the period February 16 through May 31. We believe these ramping rates are too restrictive and could jeopardize KPU's water supply, requiring them to provide water filtration or an alternative water supply source. KPU estimates water filtration would cost $20 million. We believe that our recommendation to restrict project tailrace fluctuations for the periods: (1) February 16 to May 31 to | inch per hour (day) and 2 inches per hour (night); (2) June 1 to September 15 to 1 inch per hour (day and night); and (3) September 16 to February 15 to 2 inches per hour (day and night) provides adequate protection to the aquatic resources in Ketchikan Creek while allowing KPU to maintain the water quality for their domestic water supply. We did not adopt NMFS recommendation to limit tailrace water temperatures to a maximum of 16°C over an 8-hour period because we believe this recommendation may be inconsistent with the substantial evidence standard of section 313(b). There is no evidence 102 that water temperatures in the lower Ketchikan Creek (below the tailrace) are higher than they would be without the project, nor is there any evidence of any adverse effects on the stream fishery caused by water temperatures. In addition, the hatchery has already provided protection against water temperature-related losses by the installation of refrigeration equipment to maintain proper water temperatures in the hatchery tanks. Table 25 summarizes the fish and wildlife agency recommendations received by the Commission and the conclusions reached in this DEA relative to these recommendations. We found two recommendations to be outside the scope of section 10(j). Recommendations that we consider to be outside the scope of Section 10(j) have been considered under Section 10(a) of the FPA and are addressed in the specific resource section of this document. Table 25. — Analysis of fish and wildlife agencies' recommendations. (Source: Staff) RECOMMENDATION AGENCY WITHIN ANNUAL CONCLUSION SCOPE cost OF SECTION 10() Maintain instream ADF&G, Yes sf Not adopted. flow of 47 cfs below NMFS Although we the tailrace. recommend a minimum flow of 47 cfs, we would allow 35 cfs for plant trips, emergencies, and to protect the water quality of the domestic water supply. Measure and FWS Yes $3,300 - Adopt maintain dam ADF&G leakage flows. i Agency recommended minimum flows and ramping rates could jeopardize the domestic water supply, requiring KPU to provide water filtration or an alternative water supply source; KPU estimates water filtration would cost $20 million. 103 RECOMMENDATION AGENCY WITHIN ANNUAL CONCLUSION SCOPE cost OF SECTION 10(j) Provide a minimum ADF&G Yes $0 Adopted. flow of 4.5 cfs to the Deer Mountain Hatchery. Limit tailrace ADF&G Yes $' Not adopted. We ramping rates to: recommend the 2/16 to 5/31, no following ramping (day) and 2 modification: 2/16 in/hr (night); 6/1 to to 5/31, 1 in/hr 9/15, 1 in/hr; and (day). 9/16 to 2/15 2 in/hr. Limit tailrace FWS Yes $! Not adopted. We downramping rates to recommend the 30 cfs/hr. ramping rates recommended by ADL A&G, modified by staf (see above) Install and maintain ADF&G Yes $R00 Adopted remote water level monitoring equipment at Fawn Lake. Maintain and record ADF&G Yes $11,300 Adopted flow monitoring devices below the tailrace. 104 RECOMMENDATION AGENCY WITHIN ANNUAL CONCLUSION SCOPE cost OF SECTION 10G) Maintain a tailrace NMFS Yes $285,000 Notadopted. We water temperature of to find no basis to 16°C or less. $460,000 support a tailrace maximum water temperature. There is no evidence that water temperatures are higher than they would be without the project or any evidence of adverse effects on the stream fishery caused by water temperatures. Conduct a lake FWS, Yes $4,100 Adopted. fisheries study and ADF&G develop a lake management plan if lake access is opened in the future. Conduct a feasibility NMFS, Yes $500 Adopted. The cost study of removing FWSs, for this measure the 5-foot-high ADF&G includes removing barrier on Ketchikan the barrier. Creek. Modify existing fish ADF&G Yes $1,800 ~ Adopted. ladder on Ketchikan Creek. 105 turbines and other equipment prior to discharge. RECOMMENDATION AGENCY WITHIN ANNUAL CONCLUSION SCOPE cost OF SECTION 10(j) ADF&G personnel ADF&G No $0 Not adopted. For shall have free security and public unrestricted access to health reasons the projects lands and licensee needs to works. control access to project facilities. Upon request, KPU would allow ADF&G access to project lands and works, Treat condensate and Fws, Yes o's Adopted. leakage from the ADF&G RECOMMENDATION AGENCY WITHIN ANNUAL CONCLUSION SCOPE Cost OF SECTION 10G) Develop and Fws, Yes $500 Adopted. implement a plan to NMFS improve 2,000 sq ft of salmonid rearing habitat in Ketchikan Creek below the tailrace. Prepare a plan to NMFS, No $125,000 Not adopted. improve fish access Fws, to Because the culvert to and through the ADF&G $140,000 is not a project culvert at the mouth facility, we did not of Schoenbar Creek. consider this recommendation to be within the scope of section L0G), our reasons for not adopting the recommendation and our recommended alternative, are discussed in the comprehensive development section. Hold annual ADF&G Yes $1,000 Adopted. Any meetings with the measures identified resource agencies to would need review project- Commission related study results approval prior to and identify actions implementation. based on these results. 106 X. FINDING OF NO SIGNIFICANT IMPACT This DEA for the Ketchikan Lakes Project has been prepared in accordance with the National Environmental Policy Act of 1969. The Proposed Action includes enhancements and some unavoidable impacts. Unavoidable impacts are those associated with the continued flow modifications associated with the project. The 1.34-mile-long reach of Ketchikan Creek downstream from the Ketchikan Lakes dam to the project tailrace would continue to experience depleted flows caused by the project diversion of water from Ketchikan Lakes for power and water supply purposes. One measure included in the new license would open an additional 0.35 mile of this bypassed reach for anadromous fish use by removing a 5-foot- Is 107 Since this measure was implemented in 1997, we assume the cost is included in the existing project cost. high falls caused by a tree that has fallen across the channel. The remainder of the bypassed reach is blocked to upstream fish migration by a 35-foot-high waterfall. The streamflow in Ketchikan Creek downstream from the project tailrace would, also, continue to be modified by project operations. Too rapid changes in flow can dewater spawning beds and trap fish. The negative effects on fish of rapid changes in flow would be reduced, however, by new operating limitations and improved control mechanisms that would be implemented under a new license containing staff- recommended environmental enhancement measures. Under some conditions, project operations may result in higher water temperature than would occur under natural flow conditions. If such is the case, the major effect is in the operation of the existing Ketchikan Fish Hatchery, which is equipped to cool the Ketchikan Creek water it obtains from an intake in the project tailrace. On the basis of this independent environmental analysis, issuance of a license for the project with our recommended environmental measures would not constitute a major federal action significantly affecting the quality of the human environment. Therefore, an environmental impact statement is not required. XI. LITERATURE CITED Alaska Department of Environmental Conservation (ADEC). 1996. Alaska water Quality Standards, 18 AAC 70, effective March 16, 1996. Juneau, AK. Alaska Department of Fish and Game (ADF&G). 1987. Catalog of waters important for spawning, rearing, or migration of anadromous fishes. Alaska Department of Fish and Game, Habitat Division. Juneau, Alaska. Alaska Department of Fish and Game (ADF&G). 1988. Alaska Department of Fish and Game instream flow reservation request for river miles 0.0 to 2.1 of Ketchikan Creek. (Includes habitat study using Tennant Method for rational). (LAS 1196) July 14, 1988. Alaska Department of Fish and Game (ADF&G). 1995. Alaska Department of Fish and Game Survey of Ketchikan Lakes. Undated. Submitted to Greystone in 1995. Alaska Department of Natural Resources (ADNR). 1998. Division of Mining and Water Management. Memorandum to Lorraine Marshall, DGC PRC. Dated 29 May ‘98. 108 Alderdice, D.F., and F.P.J. Velsen. 1978. Relationship between temperature and incubation time for eggs of chinook salmon (Onchorhynchus tshawytscha ). J. Fish. Res. Board Can, 35:69-75. Berg, H.C., J.E. Decker & B.S. Abramson. 1981. Metallic Mineral Deposits of Southeastern Alaska. U.S. Geol. Surv. OFR 81-122. Berg, H.C., R.L. Elliott & R.D. Koch. 1988. Geologic Map of the Ketchikan and Prince Rupert Quadrangles, Southeastern Alaska. U.S. Geol. Surv. Map I-1807. Buntzen, T.K., G.R. Elkins & C.N. Conwell. 1982. Review of Alaska's Mineral Resources. AK Dept. of Nat. Res., Div. of Geol. & Geophys. Surveys AR 1981-2. Buntzen, T.K., R.C. Swainbank, A.H. Clough, M.W. Henning & K.M. Charlie. 1996. Alaska's Mineral Industry, 1995. AK Dept. of Nat. Res., Div. of Geol. & Geophys. Surveys SR-50. Campbell, C.R., 1997. An Archaeological Survey of Ketchikan Creek and the Ketchikan Lake Area, Ketchikan, Alaska for the Federal Energy Regulatory Commission Relicensing, Project No. 420. CRC Cultural Resource Consultant. Ketchikan, Alaska. Prepared for Greystone, Englewood, Colorado. CH,M Hill. 1993. Ketchikan Watershed Mammal Monitoring Program. Technical Memorandum. Prepared by Iliff, K. for John Kleinegger, Ketchikan Public Utilities, Water Division. Anchorage, AK. CH,M Hill. 1994. Ketchikan Watershed Mammal Monitoring Program. Technical Memorandum. Prepared by Keegan, D., and M. Castleberry for John Kleinegger, Ketchikan Public Utilities, Water Division. Anchorage, AK. CH,M Hill. 1995. Ketchikan Watershed Mammal Monitoring Program. Technical Memorandum, prepared by Dawn Keegan and Marjorie Castleberry for John Kleinegger, Ketchikan Public Utilities, Water Division, Anchorage, AK. Cheshire, C.L. 1993. Ketchikan Gateway Borough Economic Indicators. Economic Development Center, University of Alaska Southeast. City of Ketchikan. 1989. City of Ketchikan Beaver Falls Hydroelectric Project, FERC Project No. 1922 Information Package. Ketchikan, AK. Cowardin, L. 1979. Classification of Wetlands and Deep-Water Habitats of the United States. USFWS-USDI. 109 DeMeo, T and W. Loggy. 1989. Identification, Classification, and Delineation of Wetlands Using Soils and Vegetation Data. Ketchikan Area, Tongass National Forest. USDA Forest Service, Alaska. DeMeo, T. J. Martin & R. West. 1992. Forest Plant Association Management Guide. Ketchikan Area, Tongass National Forest. USDA Forest Service, Alaska. Denton, Carol. 1996. Letter from Carol Denton (ADF&G) to Greystone pertaining to Water and Fish Resource Data for the Deer Mountain Hatchery, Ketchikan Creek, and Ketchikan Lakes, May 31, 1996. Ketchikan, AK. Denton, Carol. 1996. Personal Communication about Water and Fish Resource Data for the Deer Mountain Hatchery, Ketchikan Creek, and Ketchikan Lakes, May 31, 1996. Ketchikan, AK. Federal Power Commission and the USDA Forest Service. 1947. Water Powers of Southeast Alaska. Washington, D.C. Federal Energy Regulatory Commission (FERC). 1995. Impacts of hydroelectric plant tailraces on fish passage. Office of Hydropower Licensing. Washington, DC. Paper No. DPR-9. June 1995. FWS. 1997. Queen Charlotte Goshawk Status Review. U.S. Fish and Wildlife Service. Greystone. 1997. Stream Inventory of Ketchikan Creek conducted by Greystone, 1997. Greystone. 1998. Ketchikan Lakes Hydro Machine Calibration and Ramping Rates, prepared for Ketchikan Public Utilities, November, 1998. Groot, C. And L. Margolis, editors. 1991. Pacific salmon life histories. UBC Press, Vancouver, British Columbia, Canada. Ketchikan Public Utilities (KPU). 1992. Application for New License for the Beaver Falls Hydroelectric Project. Ketchikan, AK. KPU. 1995. Water Utilization Study Report, January 1995 and August 1994. Ketchikan, AK. 2pps. KPU. 1996a. Six Lotus 4.01 Spreadsheets documenting KPU Generation, Demand, Distribution, Lake Water Levels, Precipitation and Temperature 1933-1999. 110 KPU. 1996b. Water Quality Analytical Results from 5/24/89 through 2/13/95. Ketchikan, AK. 80 pp. KPU. 1998a. Aquatic Resources Study for the Ketchikan Lakes Hydroelectric Project. FERC Project No. 420; State Review No. AK9608-09J. Prepared by Greystone for Ketchikan Public Utilities, February 1998, Ketchikan, Alaska. KPU. 1998b. Hydrology Analysis Ketchikan Lakes Hydroelectric Project, FERC Project No. 420. Prepared by Greystone for KPU, Ketchikan, Alaska. Lemke, Richard W. 1975. Reconnaissance Engineering Geology of the Ketchikan Area, Alaska, with Emphasis on Evaluation of Earthquake and Other Geologic Hazards. USGS OFR 75-250. R. & M. Engineering-Ketchikan Inc. 1995. Ketchikan Public Utilities: Ketchikan Lakes and Silvis Lakes Rockslide Potential and Slope Stability Geotechnical Review. Ketchikan: R&M Engr. State of Alaska. 1996a. DRCA Community Information Summary, Ketchikan. Alaska Department of Community and Regional Affairs, Research and Analysis Section. Available on the Internet. www.labor.state.ak.us/. State of Alaska. 1996b. DRCA Community Information Summary, Ketchikan Gateway Borough. Alaska Department of Community and Regional Affairs, Research and Analysis Section. Available on the Internet. www.labor.state.ak.us/. State of Alaska. 1996c. Population of Places by Borough and Census Area 1990 - 1996. From Alaska Population Overview: 1996 Estimates on the Internet. Alaska Department of Labor, Research and Analysis, Demographic Unit. Tennant, D.L. 1976. Instream flow regimens for fish, wildlife, recreation and related environmental resources. Fisheries 1(4):6-10. Tromble, K. 1996. Alaska Department of Labor, Research and Analysis. Available on the Internet. www.labor.state.ak.us/. USDA, Tongass National Forest. 1991. Tongass Land Management Plan Revision, Supplement to the Draft Environmental Impact Statement, Proposed Revised Forest Plan. R10-MB-146. 111 USDA, U.S. Forest Service (USFS). undated. Unpublished soils map and soils descriptions for Revillagigedo Island and the Cleveland Peninsula, southeast Alaska. Ketchikan, AK: Tongass Natl. For. Superv. Off. USDA, U.S. Forest Service. (unknown). Water Resources Atlas. USDA, USS. Forest Service (USFS). 1973. Unpublished aerial photography flown on 8/18/73 and 9/13/73. Ketchikan, AK: Tongass Natl. For. Superv. Off. USDA, U.S. Forest Service (USFS). Department of Agriculture. 1974. Vol. 2, Chapter I, National Forest Landscape Management. USDA, U.S. Forest Service. 1996. Tongass National Forest. Geographic Information System Database. Tongass National Forest, Ketchikan AK. USDA, U.S. Forest Service (USFS). 1997a. Draft Fish Habitat Monitoring Protocol for the Tongass National Forest. Tongass National Forest. USDA, U.S. Forest Service (USFS). 1997b. Tongass Land Management Plan Revision, Final Environmental Impact Statement. R10-MB-338B. USGS, Water Resources Division, 1996. Miscellaneous Flow data from USGS site 15064000, Ketchikan Creek at Ketchikan. Juneau, AK. 5 pp. Williams, H. 1958. Landscapes of Alaska. Berkeley, CA: University of California. XII. LIST OF PREPARERS Charles Hall -- EA Coordinator, Geology and Soils, Developmental Analysis (Civil Engineer; M.S., Civil Engineering; B.S., Geology) Mike Henry -- Water Resources and Aquatic Resources (Fisheries Biologist; B.S. Fisheries Biology) Carl Keller -- Vegetation and Riparian Resources, Wildlife Resources, and Threatened and Endangered Species (Wildlife Biologist; M.S., Wildlife Biology) Dave Snyder -- Developmental Analysis (Civil Engineer; M.S., Civil Engineering; B.S., Civil Engineering) Gordon Warren -- Cultural Resources, Recreation (Environmental Protection Specialist; B.S., Natural Resources Recreation Management; B.S., Natural Resources) 112 Appendix A Forest Service Section 4(e) Conditions Preliminary - August 18, 1999 113 United States Forest Alaska Region P.O. Box 21628 Department of Service Juneau, AK 99802-1628 Agriculture File Code: 2770 Date: August 18, 1999 Mr. David P. Boergers Secretary Federal Energy Regulatory Commission Office of Hydropower Licensing 888 First Street, N.E., Room 6H-10 Washington, D.C. 20426 Dear Mr. Boergers: This letter transmits the Alaska Region’s second revision to Preliminary 4(e) Conditions for Ketchikan Lakes Project No. 420-009. Conditions that the Secretary of Agriculture deems necessary for the adequate protection and utilization of the Tongass National Forest are enclosed with this letter as a revised Appendix A. The Forest Service 4(e) report containing Final Conditions for the license will be provided to Federal Energy Regulatory Commission (FERC) within 45 days of completing the environmental document. Based on previous conversation with your staff and on review of the FERC’s Draft Environmental Assessment for Internal Review dated July 1, 1999, we have refined the Conditions previously submitted to only those that pertained to concerns for management of aquatic resources within the National Forest boundaries. Since we have determined that the anadromous fish do not reach streams on the National Forest, we have deleted two Conditions from the previous version, and changed the wording of Condition #111 (previously numbered #112), and Condition #113 (previously #114). The other wording addition is on the Note for Exclusion of Article 37, where additional emphasis on the need for its deletion was added. Sincerely, IES A. CAPLAN uty Regional Forester for Natural Resources Enclosures: 1 Revised Appendix A - Preliminary 4(e) License Stipulations ce: Jerry Ingersoll, Ketchikan Ranger District Theresa Trulock, Ketchikan Ranger District John Magyar, Ketchikan Public Utilities & Caring for the Land and Serving People Prnted on Recycled Paper G6 LICENSE CONDITIONS NECESSARY FOR PROTECTION AND UTILIZATION OF THE TONGASS NATIONAL FOREST IN CONNECTION WITH THE APPLICATION FOR LICENSE PROJECT NO. 420-009 CITY OF KETCHIKAN, KETCHIKAN PUBLIC UTILITIES, KETCHIKAN, AK I. GENERAL License articles contained in the Commission’s Standard Form L-2 (revised October 1975) issued by Order No. 540, dated October 31, 1975, cover general requirements that the Secretary of Agriculture, acting by and through the Forest Service, considers necessary for adequate protection and utilization of the land and resources of the Tongass National Forest. For the purposes of section 4(e) of the Federal Power Act (16 U.S.C. 797(e)), the purposes for which National Forest System lands were created or acquired shall be the protection and utilization of those resources enumerated in the Organic Administration Act of 1897 (30 Stat. 11), the Multiple-Use Sustained Yield Act of 1960 (74 Stat. 215), the National Forest Management Act of 1976 (90 Stat. 2949), and any other law specifically establishing a unit of the National Forest System or prescribing the management thereof (such as the Wilderness Act or Wild and Scenic Rivers Act), as such laws may be amended from time to time, and as implemented by regulations and approved Forest Plans prepared in accordance with the National Forest Management Act. Therefore, pursuant to said section 4(e) of the Federal Power Act, the following conditions covering specific requirements for protection and utilization of National Forest System lands shall also be included in any license issued. Il. STANDARD FOREST SERVICE PROVISIONS ‘ondition No. 103 - ro f Changes After jal Construction Notwithstanding any Commission approval or license provisions to make changes to the project, the licensee shall get written approval from the Forest Service prior to making any changes in the location of any constructed project features or facilities, or in the uses of project lands and waters, or any departure from the requirements of any approved exhibits filed with the Commission. Following receipt of such approval from the Forest Service, and at least 60 days prior to initiating any such changes or departure, the Licensee shall file a report with the Commission describing the changes, the reasons for the changes, and showing the approval of the Forest Service for such changes. The licensee shall file an exact copy of this report with the Forest Service at the same time as it is filed with the Commission. This article does not relieve the Licensee from the amendment or other requirements of Article 2 or Article 3 of this License. Condition No. 104 - Consultation Each year during the 60 days preceding the anniversary date of the license, the Licensee shall consult with the Forest Service with regard to measures needed to ensure protection and development of the natural resource values of the project area. Within 60 days following such consultation, the Licensee shall file with the Commission evidence of the consultation with any recommendations made by the Forest Service. The Commission reserves the right, after notice and opportunity for hearing, to require changes in the project and its operation that may be necessary to accomplish natural resource protection. Page | dition - ut solution With respect to any plan required by this license to be approved by the Forest Service, if the ; Forest Service does not act within 60 days of submission of a proposed plan to the Forest Service by the Licensee, the proposed plan shall be deemed disapproved. The Licensee may request, in writing, the Regional Forester to review any plan that is c i disapproved or deemed disapproved by the Forest Service. If the Regional Forester fails to issue a determination regarding the request for review within 45 days of receiving the Licensee’s notice of request for review, the disapproval shall be deemed to have been sustained by the Regional Forester. If the Regional Forester sustains the disapproval, the Licensee may request, in writing, review of decision by the Chief, as though the disapproval was an original decision of the Regional Forester. Any orders or directions given during the operation of the project will be resolved using the appeal regulations applicable to holders of special-use authorizations from the Forest Service. III. OPTIONAL FOREST SERVICE PROVISIONS nm - Herita; urce Prot Prior to commencement of any construction, development, or modification/replacement of any project works or other facilities at the project, the Licensee shall consult and cooperate with the Forest Service and the State Historic Preservation Officer (SHPO) to determine the need for, and extent of, any archeological or historic resource surveys and any mitigative measures that may be necessary. The Licensee shall provide funds in a reasonable amount for such activity. If any previously unrecorded archeological or historic sites are discovered during the course of construction, activity in the vicinity shall be halted, a qualified archeologist shall be consulted to determine the significance of the sites, and the Licensee shall consult with the Forest Service and SHPO to develop a mitigation plan for the protection of significant archeological or historic resources. If the Licensee, Forest Service and SHPO cannot agree on the amount of money to be expended on archeological or historic work related to the project, the Commission reserves the right to require the Licensee to conduct, at its own expense, any such work found necessary. Condition No. 111 - Instream Flow Requirement (Delete entirely) Condition No. 111 - Lake Habitat Study (Previously numbered #112) Adaptive license management is a strategy of the future. If and when recreational access is allowed to Ketchikan Lake, the Licensee shall file, for Forest Service and Commission approval, a comprehensive study plan for aquatic habitat in the Ketchikan Lake watersheds on National Forest. This monitoring study plan shall be jointly designed by the Forest Service, KPU, and ADF&G. The primary purpose of this study is to establish a scientifically sound basis for managing fish populations and habitat in and above Ketchikan Lakes in order to ensure adequate protection of the resources affected by the hydropower project, under increased recreation pressures. Portions of this study will build upon existing, or available information and analysis, while other portions Page 2 may require collection of new data and additional analysis. This study plan must evaluate: (1) the status of the fisheries and habitat in Ketchikan Lakes, and tributary streams; (2) the impacts of the project, specifically of lake level fluctuations and temperatures, on these populations; and (3) measures to manage the fishery to meet goals of the Tongass Lands Management Plan, and other agency’s resource mangement plans. Within one year following approval of the study design, the Licensee shall begin making annual reports of the study plan implementation results to the Forest Service, ADFG and the Commission. If the currently licensed lake level fluctuations are inadquate to protect aquatic habitat, then the licensee shall submit to the Commission for approval, a Lake Level Management Plan to provide this protection. Until the Lake Habitat study is completed, the lake levels shall not be drawn down lower than recorded between 1990 and 1995 with the lowest recorded level being 327 feet elevation, unless otherwise agreed to by USFS, and ADFG for emergency operations. Condition No. 112 - Maintain Gages, and Stream-Gaging Stations (Previously #113) The Licensee shall install and, thereafter, maintain gages and stream-gaging stations for the purpose of determining the stage and flow of the stream or streams on which the project is located, the amount of water held in and withdrawn from storage, and the effective head on the turbines; shall provide for the required reading of such gages and for the adequate rating of such stations; and shall install and maintain standard meters adequate for the determination of the amount of electric energy generated by the project works. The number, character, and location of gages, meters, or other measuring devices, and the method of operation, thereof, shall at all times be satisfactory to the Commission or its authorized representative. The Commission reserves the right, after notice and opportunity for hearing, to require such alterations in the number, character, and location of gages, meters, or other measuring devices, and the method of operation, thereof, as are necessary to secure adequate determinations. The installation of gages, the rating of said stream or streams, and the determination of the flow thereof, shall be under the supervision of, or in cooperation with, the District Engineer of the United States Geological Survey having charge of the stream-gaging operations in the region of the project, and the Licensee shall advance to the United States Geological Survey the amount of funds estimated to be necessary for such supervision, or cooperation for such periods as may be mutually agreed upon. The Licensee shall keep accurate and sufficient records of the foregoing determinations to the satisfaction of the Commission, and shall make return of such records annually at such time and in such form as the Commission may prescribe. Condition No. 113 - Bypass Water Monitoring and Mitigation (Previously numbered #114) Within one year following the date of issuance of this license, the Licensee will develop a Monitoring Plan for the Bypass reaches. The purpose of the Monitoring Plan is to monitor water seepage quantity and temperatures in the bypass reaches below the Ketchikan Lake Dam and the Granite Creek Diversion. This monitoring study shall be jointly designed by the Forest Service, KPU, and ADF&G, prior to implementation. Page 3 The study will determine the relationship between the lake level and bypass flows. The correlation will be made for the range of lake levels between the spillway level and 327 ft elevation, or for the lake levels which occur during the five years following licensing, whichever requires the shorter time. Ata minimum, the Plan will require KPU to monitor bypass flows at new or existing weirs below both the Ketchikan Lakes Dam and the Granite Basin Diversion. In the event KPU plans to make repairs to either the dam or diversion structure that could result in a reduction of current seepage flows, KPU commits to maintain through some other means, an amount of flow in the by-pass reaches of Ketchikan and/or Granite Creeks equal to or greater than the actual amount of the seepage flows released historically. If bypass flows are shown to be related to lake levels, the Licensee will develop an analysis of the historic lake level fluctuations, and will propose a release quantity and frequency to the Forest SErvice, ADFG and the Commission for approval. Condition No. 114 - Water Quality (Previously numbered #115) The Licensee shall continue to manage the watershed to protect the water quality and will continue to operate Fawn Lake to minimize turbidity to protect water quality. The Licensee shall continue to operate an oily-water separator and maintain plumbing refits in the powerhouse to remove all oil from the water before it is discharged into the Project tailrace (moved from condition 116) Condition No. 115 - Licensee Development of Fish and Wildlife Facilities (Previously numbered #116) The Licensee shall, for the conservation and development of fish and wildlife resources, design, construct, maintain and operate, or arrange for the design, construction, maintenance, and operation of such reasonable modifications of the project structures and operation, as may be ordered by the Commission upon its own motion or upon the recommendation of the Secretary of Agriculture or the ADF&G, after notice and opportunity for hearing. di} - Forest Servi 01 velop Fish and W. acilities (previously numbered #117) Whenever the United States shall desire, in connection with the project, to construct fish and wildlife facilities or to improve the existing fish and wildlife facilities at its own expense, the Licensee shall permit the United States or its designated agency to use, free of cost, such of the Licensee's lands and interests in lands, reservoirs, waterways, and project works as may be reasonably required to complete such facilities or such improvements thereof. In addition, after notice and opportunity for hearing, the Licensee shall modify the project operation as may be reasonably prescribed by the Commission in order to permit the maintenance and operation of the fish and wildlife facilities constructed or improved by the United States under provisions of this article. This article shall not be interpreted to place any obligation on the United States to construct or improve fish and wildlife facilities or to relieve the Licensee of any obligation under this license. Condition No. 118 - Fishery Environmental Measures (Delete entirely) Page 4 Condition No. 117 - Erosion Control Plan (Previously numbered #119) At least 90 days prior to starting any activities, the Forest Service determines to be of a land clearing or land-disturbing nature on National Forest System land, the Licensee shall file with the Director, Office of Hydropower Licensing for Commission approval, a plan approved by the Forest Service to control erosion, stream sedimentation, dust, and soil-mass movement consistent with the standards and guidelines of the Tongass Land Management Plan. Upon Commission approval, the Licensee shall implement the plan. The plan shall be based on actual-site geological, soil and groundwater conditions and shall include: (1) a description of the actual site conditions, including any existing erosion or sedimentation problems from roads, stream crossings, trails, or other facilities; (2) detailed descriptions, design drawings, and specific topographic locations of all control measures; (3) measures to divert runoff away from disturbed land surfaces; (4) measures to collect and filter runoff over disturbed land surfaces, including sediment ponds at the diversion and powerhouse sites; (5) revegetating test-drive areas outside of the roadbed; (6) measures to dissipate energy and prevent erosion at the tailrace; (7) and a monitoring and maintenance schedule; (8) and any other measures the Forest Service, and the Licensee mutually identify as needing care to ensure resource protection. The Commission may require changes to the plan to ensure adequate protection of the environmental, scenic, and cultural values of the project area. The Licensee shall not commence activities the Forest Service determines to be affected by the plan until after 60 days following the filing date, unless the Director, Office of Hydropower Licensing, prescribes a different commencement schedule. Condition No. 118 - Visual Resource Protection (Previously numbered #120) At least 90 days before starting any activities, the Forest Service determines to be of a land clearing, land-disturbing or spoil-producing nature on National Forest System land, the Licensee shall file with the Director, Office of Hydropower Licensing, a plan approved by the Forest Service for design and construction of new facilities, or for design and modification of existing facilities in order to preserve or enhance its visual character consistent with the standards and guidelines for affected management areas in the Tongass Land Management Plan. The Commission may require changes to the plan to ensure adequate protection of the environmental, scenic, and cultural values of the project area. The plan must address facility configurations and alignments, architectural theme, building materials, color, conservation of vegetation, landscaping, signs, and screening. Project facilities to be covered by this plan include, among other things, clearings, diversion structures, penstocks, pipes, ditches, powerhouses, other buildings, transmission lines and corridors, recreation facilities, and access roads. In particular, the plan must at least include the following: (1) the powerhouse and associated facilities such as security fences, tailrace, equipment storage, access and parking, and communication equipment; (2) diversion structure and associated facilities such as access and parking, power sources for sensing and monitoring equipment, and inlet controls; (3) power transmission line; (4) pipelines and ditches; and (5) recreation facilities. Page 5 Mitigation measures shall include, but are not limited to: (1) surface treatments with colors that will be in harmony with the surrounding landscape; (2) use of non-specular conductors for the transmission lines; (3) use of native plant species to screen facilities from view; (4) reshaping and revegetating disturbed areas to blend with surrounding visual characteristics; and (5) locating transmission facilities to minimize visual impacts, etc. Condition No. 119 - Recreation Implementation Plan (Previously numbered #121) Per 18 CFR Section 2.7- Recreation development at Licensed Projects, at the time KPU decides to implement water treatment, KPU shall commence a Recreation Implementation Study that will be developed in collaboration with City, State, and Federal agencies and other public interest groups and approved by the Forest Service for implementing measures to mitigate project area related recreation and related lost opportunities, and provide for recreation needs over the life of the license, consistent with the standards and guidelines for affected areas in the Tongass Land Management Plan. These shall include, but not be limited to, public access roads, hiking, bicycling, launching ramps, interpretive signs, beaches, day use and overnight camping areas, sport fishing, sanitary facilities, and utilities. The final Recreation Implementation Plan shall be filed with the Commission within two years of the date when a decision is made to implement water treatment. Upon Commission approval, the licensee shall implement the plan. The Commission may require changes to the plan to ensure adequate protection of the environmental, scenic, and cultural values of the project area. If water treatment is implemented for the Ketchikan Municipal water supply during the life of the license, then the Licensee shall design, construct, maintain, and operate, or shall arrange for the design, construction, maintenance, and operation of such reasonable recreational facilities, including modifications thereto, such as access roads, wharves, launching ramps, interpretive signs, beaches, day use and overnight camping areas, sanitary facilities, and utilities, giving consideration to the needs of the physically handicapped, and shall comply with such reasonable modifications of the project, as may be prescribed hereafter by the Commission during the term of this license upon its own motion or upon the recommendation of the Secretary of Agriculture or other interested Federal or State agencies, after notice and opportunity for hearings. Condition No. 120 - Resource Coordination Plan (Previously numbered #122) Since the Ketchikan Lakes project has been in operation since the late 1920’s, and since it is good for all resource-management agencies to have a common understanding of ongoing project operations, KPU and the resource-management agencies shall work together in the development of a Resource Coordination Plan. The goal of this plan is to document mutual agreements concerning efficient and economical project operation and maintenance, and construction of future facilities. Participants in the development of this plan will share information pertinent to the protection of natural and cultural resources in the project vicinity. The objectives of this plan are: (1) to facilitate ongoing communication among KPU, and all the resource-management agencies regarding project-related operation and maintenance activities and construction projects; and (2) to ensure that KPU field personnel and contractors conduct project operation, maintenance, and construction of future facilities without unduly affecting natural and cultural resources. Page 6 The Resource Coordination Plan will define coordination procedures so that issues and concems can be identified, addressed, and resolved in a timely manner. It will also provide a set of instructions and maps for Ketchikan Public Utility field personnel and contractors to follow. The Resource Coordination Plan will address the following kinds of information. (1) Introduction: Explaining purpose, goals and objectives for the plan, short project background, overall structure of the plan, and an implementation schedule. (2) Regulatory framework should explain the legal framework under which this plan was developed. (3) Relationships to other plans required by the License should be explained. (4) Coordination steps and implementation of the plan should be determined and disclosed. Activities of interest to the Forest Service, and to be discussed in the Resource Coordination plan include, but may not be limited to the following kinds of topics. (1) water storage and releases, including storage limitations (if any), dates and/or criteria for filling and release; (2) procedures for flood conditions; (3) erosion prevention in the reservoir area and spillway channel; (4) procedures for removal, flushing or disposal of sediments; (5) flow maintenance and notification in advance of major changes; and (5) trash and debris removal. The Licensee shall file with the Director, Office of Hydropower Licensing, a Resource Coordination Plan approved by the Forest Service within one year of license approval. Upon Commission approval, the Licensee shall implement the plan. The Commission may require changes to the plan to ensure adequate protection of the environmental, scenic, and cultural values of the project area. Condition No. 121 - Sensitive Plant and Habitat Plan (Previously numbered #123) At least 90 days prior to starting any land-clearing, land-disturbing, or spoil-producing activities, the Licensee shall file for Commission approval, a Sensitive-Plant Habitat Plan approved by the Forest Service. The plan shall be prepared in consultation with the Forest Service and other affected State or Federal agencies. Upon Commission approval, the Licensee shall implement the plan. The Commission may require changes to the study plan to ensure adequate assessment and protection of the environmental, scenic, and cultural values of the project area. This plan shall identify requirements for construction, operation, maintenance, and monitoring measures to meet Forest Service sensitive-plant and habitat objectives and standards identified in the most current version of the Tongass Land Management Plan. The plan shall include a schedule for accomplishing these objectives and standards shall identify any needs for additional studies. Due to the unknown nature of the project's impacts on sensitiv-plant species, some of the studies (requiring a year or more) will need to be completed prior to new construction, or land-disturbing activities associated with maintenance and operations, because of the required mitigation measure’s effects on the viability of the total project. Page 7 The Licensee shall also prepare a monitoring plan to determine the effectiveness of mitigations on sensitive-plant species. If monitoring indicates to the Forest Service that changes in project structures or operations are necessary to maintain sensitive species, the Licensee may be required by the Forest Service to file, with the Commission, a schedule, approved by the Forest Service, for implementing specific changes in project structures or operations. Condition No. 122 - Administrative Access (Previously numbered #124) The Licensee shall provide the Forest Service use of the access road to Ketchikan Lake for administrative purposes. The protocols shall be developed in consultation with the Forest Service. - Easement uisit (Previously numbered #125) The Licensee shall acquire, without contribution or compensation by the United States, an casement in the name of the United States for the location of, and public access to, the access road that the Licensee constructed that is not located on National Forest System land. Licensee shall obtain Forest Service approval of the easement language and evidence of unencumbered title to the easement prepared by a certified title examiner prior to execution of the easement. Condition No. 124 - Project Area Boundary Modification (Previously numbered #126) The Licensee must immediately submit surveys as necessary for FERC to amend the project boundaries to reflect the existing road location. Condition No. 125 - Lands (Previously numbered #127) The right of Licensee and of its successors and assign to use and occupy waters over which the United States has jurisdiction, or lands of the United States under the license, for the purpose of maintaining the project works or otherwise, shall absolutely cease at the end of the license period, unless the Licensee has obtained a new license pursuant to the then existing laws and regulations, or an annual license under the terms and conditions of this license. Condition No. 126 - Solid Waste and Waste Water Plan (Previously numbered #128) At least 90 days prior to starting any activities, the Forest Service determines to be of a land- disturbing nature on National Forest System land, the Licensee shall file with the Director, Office of Hydropower Licensing, a plan, approved by the Forest Service, for the treatment and disposal of solid waste and waste water generated during construction and operation of the project. At a minimum, the plan must address the estimated quantity of solid waste and waste water generated each day; the location of disposal sites and methods of treatment; implementation schedule; areas available for disposal of wastes; design of facilities; comparisons between on- and off-site disposal; and maintenance programs. The Licensee shall not commence activities the Forest Service determines to be affected by the plan until after 60 days following the filing date, unless the Director, Office of Hydropower Licensing, prescribes a different commencement schedule. Page 8 dition No. 127 - Hazardous Substance Plan (Previously numbered #129) é least 90 days before Starting any activities, the Forest Service determines to be of a land- disturbing nature on National Forest System land, the Licensee shall file with the Director, Office of Hydropower Licensing, a plan, approved by the Forest Service, for oil and hazardous substances storage and spill prevention and cleanup. At a minimum, the plan must require the Licensee to: (1) maintain in the project area, a cache of spill cleanup equipment suitable to contain any spill from the project; (2) to periodically inform the Forest Service of the location of the spill cleanup equipment on National Forest System lands and of the location, type, and quantity of oil and hazardous substances stored in the project area; and (3) to inform the Forest Service immediately of the nature, time, date, location, and action taken for any spill. The Licensee shall not commence activities the Forest Service determines to be affected by the plan until after 60 days following the filing date, unless the Director, Office of Hydi Licensing, prescribes a different commencement schedule. nies meal Additional Note: 2 Jude Artick e from lice e eiss ice. Article 37 of the existing license grants the Licensee authority to grant permission, without prior Commission approval, for special uses of project-area lands, including conveying fee title to rights-of-way, easements, and leases. For peas p owned by the United States, old Article 37 is in conflict with federal law and needs to be el le Page 9 — TONY KNOWLES, GOVERNOR STATE OF ALASKA DEPARTMENT OF FISH AND GAME HABITAT AND RESTORATION DIVISION 333 RASPBERRY ROAD ANCHORAGE, ALASKA 99518-1599 PHONE: (907) 344-0541 1 \f Ic 1 \ lp WW IG | | 1} | Wy) L_/ FISH HABITAT PERMIT FG 96-IL-0 (AMENDMENT) \\ ISSUED:, November 14°1997 \\EXPIRES: December31, 1998 and Expol Mr. Stan Sieczkowski Alaska Energy Authority 480 West Tudor Road Anchorage, AK 99503 Dear Mr. Sieczkowski: Re: _ Bank Stabilization - Kizhuyak River Stream Number 252-36-10050 NE% Sec. 12, T. 29S., R. 23 W., S.M. SID AK9606-26AA; COE N® N-800133 Pursuant to AS 16.05.870(b), the Alaska Department of Fish and Game (ADF&G) has reviewed your request for a time extension to complete previously authorized work. The river bank stabilization project referenced above entails construction of three, 300 foot-long spur dikes and one, 700 foot-long overflow dike in the Kizhuyak River floodplain. The purpose of the project is to provide more permanent, low maintenance flood erosion protection for the Terror Lake hydroelectric power plant and tailrace facilities. Project plans call for placing the spur dikes upstream of the power plant along the west side of the river's floodplain and perpendicular to water flow. The overflow dike will parallel the river course and is located at the base of the spur dike shanks. An estimated 13,200 cubic yards (cy) of gravel will be obtained from four borrow sites near the project. One of the borrow sites includes reuse of the material placed during the fall flood of 1995 to create a temporary diversion berm. Approximately 8,000 cy of riprap will be imported to armor the face of the dikes. To reduce the potential for log jam-related debris buildup and channel scour at the spur dikes, clearing and grubbing limits have been defined around the margin of the project. The clearing limits cover about 14 acres with about half containing vegetation. Construction was planned to occur during low flow events during September and October 1996, and no equipment was to have been operated in the flowing waters of the Kizhuyak River. However, due to unresolved project financing issues the work has been delayed. The 1998 construction plans and work schedule remain the same as for 1996. The Kizhuyak River has been specified as being important for the spawning, rearing, or migration of anadromous fish pursuant to AS 16.05.870(a). The proposed project is located approximately 4 mile upstream of a portion of the river used by spawning coho, chum, and pink salmon and Dolly Varden. Beginning in mid July adult salmon begin their upstream movement to the spawning grounds. The adult salmon are found in the river through mid October. Salmon eggs deposited in streambed gravel are extremely vulnerable to any type of disturbance and they cannot withstand shock and pressure. In addition, sediment deposited on top of salmon spawning sites may suffocate and thereby kill eggs or fish fry. For these reasons, instream activities are generally prohibited in or immediately upstream of salmon spawning areas except between mid- May and mid- July 15, after the eggs have hatched and most of the salmon fry have outmigrated from the system. 11-K107LH FG 96-II-0674 -2- November 14, 1997 (Amendment II) In accordance with AS 16.05.870(d), project approval is hereby given. No stipulations will be necessary if construction activities are conducted as summarized in paragraph 1, above. The permittee is responsible for the actions of contractors, agents, or other persons who perform work to accomplish the approved plan. For any activity that significantly deviates from the approved plan, the permittee shall notify the ADF&G, Habitat and Restoration Division, and obtain written approval in the form of a permit amendment before beginning the activity. Any action taken by the permittee or an agent of the permittee that increases the project's overall scope or that negates, alters, or minimizes the intent or effectiveness of any stipulation contained in this permit will be deemed a significant deviation from the approved plan. The final determination as to the significance of any deviation and the need for a permit amendment is the responsibility of the ADF&G, Habitat and Restoration Division. Therefore, it is recommended that the ADF&G, Habitat and Restoration Division, be consulted immediately when a deviation from the approved plan is being considered. This letter constitutes a permit amendment issued under the authority of AS 16.05.870. This permit amendment must be retained on site during spur dike and overflow dike construction operations. Please be advised that this approval does not relieve you of the responsibility for securing other permits: state, federal, or local. Pursuant to 6 AAC 80.010 (b), the conditions of this permit are consistent with the Standards of the Alaska Coastal Management Program and the Kodiak Island Borough Coastal Management Program. In addition to the penalties provided by law, this permit may be terminated or revoked for failure to comply with its provisions or failure to comply with applicable statutes and regulations. The department reserves the right to require mitigation measures to correct disruption to fish and game created by the project and which were a direct result of the failure to comply with this permit or any applicable law. The recipient of this permit (the permittee) shall indemnify, save harmless, and defend the department, its agents, and its employees from any and all claims, actions or liabilities for injuries or damages sustained by any person or property arising directly or indirectly from permitted activities or the permittee's performance under this permit. However, this provision has no effect if, and only if, the sole proximate cause of the injury is the department's negligence. This permit decision may be appealed in accordance with the provisions of AS 44.62.330-- 44.62.630. Sincerely, Robert G. Bosworth, Deputy Commissioner a! Magne 2/ By: C. Wayne Dolezal Habitat Biologist Region II (907) 267-2285 FG 96-II-0674 -3- (Amendment II) cc: L. Freed, KIB J. McCullough, ADF&G D. Prokopowich, ADF&G L. Schwarz, ADF&G B. Smith, NMFS H. Hannafious, COE A. Rappoport, USFWS G. Saupé, DEC A. Blank, FWP J. Durr, OMB/DGC J. Thrall, Locher Interests Ltd. November 14, 1997 of LAM HOMER ELECTRIC ASSOCIATION, INC. MEMORANDUM DATE: February 3, 1995 TO: Stan Sieczkowski, AEA FROM: Mike Yerkes, Bradley na SUBJECT: Increase FY96 Budget for Septic Tank Maintenance We recently got a scare when the sewers backed up down here and flooded the basements in the duplex quarters. Luckily it was a plugged 6" pipe and we were able to resolve the problem and resume normal operation in 24 hours. If it had been full septic tanks it would have been weeks to thaw the ground and arrange for barges to bring over the necessary thaw rigs and pump trucks. After this scare, I did some research. Dave Eberle informs me that the septic tanks were installed in 1986 and have received hard use since then during construction and final operations. Dave indicates they have never been checked or pumped. Moreover, we can find no above grade pumpouts for the two 4000 gallon tanks servicing the crew quarters and duplexes. I can find no requirement to check or pump these tanks in the O&M manuals or the AMMS system, however, I found TSD-028-0 (attached) in the four dam pool technical standards. This standard recommends inspection annually and periodic pumping. I believe it is time to inspect these tanks and pump them. The tanks are at least 10’ below grade and access will require significant excavation and shoring. I estimate excavation and shoring costs at $1000 per tank or $3000 total. Barge and pumper truck has been quoted at $7000. Work will have to wait until midsummer when ground frost is gone. If the tanks are full of solids we may have to replace them and or use hand digging which will increase costs. I request approval to conduct this work this summer and an increase in our proposed FY96 budget of $10,000 to cover labor and contract costs. Following this inspection we will recommend adoption of a regular maintenance plan and schedule. ec: Budget Subcommittee: Pease Lovas Evans septic.mcy/kls LATTA PROJECT SEPTIC SYSTEMS FOUR DAM POOL PROJECTS TSD-028-0 ALASKA ENERGY AUTHORITY PAGE 2 2.0 TECHNICAL STANDARDS 2.1 OPERATIONS AND MAINTENANCE 1) 2) 3) 4) 5) Septic tanks require periodic pumping to remove solids accumulation. Inspect sludge accumulation annually and pump out septic tank before solids can be discharged into the drainfield. The sewage ejector at Terror Lake requires periodic maintenance. Sewage ejector maintenance shall be included in the operation and maintenance manual. See TSD-064, Operation and Maintenance Manuals. Maintain maintenance records in accordance with TSD-060, Maintenance Records. Use soaps compatible with the septic system and do not discharge chemicals into the septic system as they can be harmful to the bacteria. : The sewage treatment system at Solomon Gulch requires periodic maintenance, replacement of chemicals, and pumping of the excess sludge. Operation and maintenance procedures shall be included in the operating and maintenance manual. Plant procedures shall include a schedule for pumping of the tank and, if the tank is filled, a procedure for discontinuing use of waste system until the tank can be pumped and reactivated. Do not discharge into surface water without permits and proper treatment. If discharge to surface water is contemplated, the Owner shall apply for permits. All discharges to surface water must comply with appropriate ADEC permits. FILE: TSD028.0 DEC-06-97 SAT 11:35 AM SOA GOVERNOR'S OFFICE FAX NO. 907 269 7461 P.01 sia |e os - a petal Weiree areas | = eerie eee Wy) ————— STATE OF ALASKA OFFICE OF GOVERNOR TONY KNOWLES 3601 C Street, Suite 758 Phone: (907) 269-7450 | Fn ow 1 a : dom — a Fax Transmittal | | Anchorage, Alaska 99503 Fax: (S07) 268-7464 | j i Please deliver ic: Lecatien: | | Fax number: Ae? - O Phone number: | Number of pages including the transmittal shest: a ~ A v ¢ rd ‘ é av " dies \} ? ’ ~ A» Y cA \ => = DEC-06-97 SAT 11:35 AM SOA GOVERNOR’S OFFICE FAX NO. 907 269 7461 P. 02 David-17326 cc: Ron KETCHIKAN PUBLIC UTILITIES MUNICIPALLY OWNED eS Se November 24, 1997 RECFIVEr: acer) Maas The Honorable Tony Knowles, Governor of Alaska om PO Box 110001 Juneau, AK 99811-0001 Dear Governor Knowles: The enclosed resolutions were approved by the City of Ketchikan City Council on November 6, 1997, by the Ketchikan Gateway Borough Assembly on November 17, 1997 and by the City of Saxman City Council on November 20, 1997. Thank you for any support you can provide in positively responding to these resolutions. 4 Magy john A. Magyar General Manager JaM-nll Beclogures ee: Bob Evans, PMC Lobbyist Deanis Lewis, PMC Chairman Ror Saxton, PMC Attorncy WAUSER\NANCTLAWPDATA\O07-P1,00R DEC-06-97 SAT 11:36 AM SOA GOVERNOR’S OFFICE FAX NO. 907 269 7461 P. 03 CITY OF KETCHIKAN, ALASKA RESOLUTION NO, 97-1890 A Resolution of the City of Ketchikan, Alaska, Requesting the Assistance of Governor Knowles and the State Legislature to Pursue the Sale of the Four Dam Pool Hydruelectric Projects to the Cities of Ketchikan, Wrangell, Petersburg, the Kodiak Electric Association and the Copper Valley Electric WHEREAS, the City of Ketchikan is signatory to the Long Term Power Sales Agreement under which the people of Ketchikan are beneficiaries of the long-term benefits which TR eee To Fa ae Speen age Were ee ceeper a Oe Tale i Lake Tyee and Solomon Guich; and i WHEREAS, the four projects provide power to the cities of Ketchikan, Wrangell, Petersburg, Kodiak, Glennallen and Valdez, and the respective utilities from these communities have collectively operated the projects since 1985; and WHEREAS, the Alaska Energy Authority and these utilities have been negotiating the transfer of awnership of the projects from the State to the utilities for two years, under principles laid out by the State, including the requirement thar the existing Power Sales Agresment between the State and the utilities remain in effect after the transfer of ownership; and WHEREAS, the Four Dam Pool utilities submitted 4 proposal to the Alaska Energy Authority on July 30, 1997, to purchase the projects and the proposal subsequently was presented to the AIDEA Board and no action was taken; and WHEREAS, the State constructed or acquired the projects for the benefit of the utilities and communities served by the projects; and WHEREAS, the State of Alaska has an interest in divesting the Four Dam Pool projects to the utilities and commmnities served by the projects, as local utility ownership of the projects will provide significantly greater opportunities for rate reductions, cost controi and the protection of quality of service; and WHEREAS, the sale of the projec will benefit the State by releasing the State trom ownership liability and alleviating concerns about long-term operations. Now, therefore, be it resolved by the City of Ketchikan, Alaska as follows: Section 1. We hereby request that Governor Knowles assist in dealing with the appropriate State agencies and the 1998 State Legislature to pursue divestiture of these projects to the cities of Ketchikan, Wrangell, Petersburg, the Kodiak Electric Association and the Copper Valley Electric Association. Section 2. We further request that the State Legislature allow these utilities to secure ownership of the projects as soon as possible. = Resotution No. 97-1890 ‘ Page f DEC-06-97 SAT 11:36 AM SOA GOVERNOR’S OFFICE FAX NO. 907 269 7461 P. 04 - 8 KETCHIKAN GATEWAY BOROUGH RESOLUTION NO. 1576 A RESOLUTION OF THE ASSEMBLY OF THE KETCHIKAN GATEWAY BOROUGH, ALASKA, REQUESTING THE ASSISTANCE OF GOVERNOR KNOWLES AND THE STATE LEGISLATURE TO PURSUE THE SALE OF THE FOUR DAM POOL HYDROES.ECTRIC PROJECTS TO THE CITIES OF KETCHIKAN, WRANGELL AND PETERSBURG,:..THE KODIAK ELECTRIC ASSOCIATION AND THE COPPER VALLEY ELECTRIC ASSOCIATION; AND ESTABLISHING AN EFFECTIVE DATE. A. We represent the Ketchikan Gateway Borough and we are beneficiaries of thelong- a) term benefits which flow from the Four Dam Pool hydroelectric —— The — include ~ * Terror Lake, Swart Lake, Lake Tyee, and Solomon Gukk; B, The four projects provide power tothe cces of Ketchikan, Wrangell, Petersburg, Kodiek, Glennallen and Valdez, and the respective utilities from these communities have collectively operated the projects since 1985. C. The Alaska Energy Authority and these utilities have been negotiating the transfer of ownership of the projects from the State to the utilities for ewo years, under principles laid out by the State, iacluding the requirement thot the existing Power Sales Agreement between the Srare and the utilities remain in effect after the transfer of ownership. . D. The Four Dam Pool utilities submited 4 proposal to the Alaska Energy Authority on July 30, 1997, to purchase the projects. The proposal was subsequently presented to the AIDEA Board, and no action was taken. . E. The State constructed or acquired the projects for the benefit of the titilities and commuaities served by the projects. : F. The Scare of Alaska has an interest in divesting che Four Dam Pool projects co the utilities and comsaunities served by the projects, as local utility ownership of the projects will provide significantly greater opportunities for rate reductions, cost control, and the protection of quality of service. G. The sale of the projects will benefic the Scare by releasing the Scare from ownership liability and alleviating concerns about long-term operations. NOW, THEREFORE, IN CONSIDERATION OF THE ABOVE FACTS, IT 1S RESOLVED BY THE ASSEMBLY OF THE KETCHIKAN GATEWAY BOROUGH, ALASKA, as follows: GAMGRIRESORD>RI316 DEC-06-97 SAT 11:36 AM SOA GOVERNOR’S OFFICE FAX NO. 907 269 7461 P. 05 ” ’ City of Saxman RESOLUTION NO. 97-10-180 A RESOLUTION OF THE CITY COUNCIL OF THE CITY OF SAXMAN REQUESTING THE ASSISTANCE OF GOVERNOR KNOWLES AND THE STATE LEGISLATURE TO PURSUE THE SALE OF THE Four DAM POOL HYDROELECTRIC PROJECTS TO THE CITIES OF KECHIKAN, WRANGELL, PETERSBURG, THE KODIAK ELECTRIC ASSOCIATION, AND THE CopPER. VALLEY ELECTRIC s sasieeitaaal & WHEREAS, We REPRESENT THE CITY OF .SAXMAN) * AND WE ARES; - BENEFICIARIES OF THE LONG-TERM BENEFITS WHICH FLOW FROM THE Four! DAM POOL HYDROELECTRIC PROJECTS. THE PROJECTS INCLUDE TERROR LA _ SWAN LAKE. Lake Free, AND SOLOMAN SUCCH “WHEREAS. THE FOUR PROJECTS PROVIDE POWER TO THE CITIES orf, KETCHIKAN, WRANGELL, PETERSBURG, KODIAK, GLENNALCEN AND VALDEZ, Ane} THE RESPECTIVE UTILITIES FROM THESE ees HAVE COLLECTIVEL . OPERATED TW, GS crs INCE 1985.5 iS} naaisiare c CONSTRUCTED? Gi OF THE UTILITIES AND COMM i HE Four DAM POOL PROJECTS TO THE UTILITIES AND COMMUNITIES SERVED “BY THE PROJECTS, AS LOCAL UTILITY OWNERSHIP OF THE PROJECTS WILL . PROVIDE SIGNIFICANTLY GREATER OPPORTUNITIES FOR RATE REDUCTIONS, COST CONTROL, AND THE PROTECTION OF QUALITY SERVICE. WHEREAS, THE SALE OF THE PROJECTS WILL BENEFIT THE STATE BY RELEASING THE STATE FROM OWNERSHIP LIABILITY AND ALLEVIATING CONCERNS ABOUT LONG-TERM OPERATIONS. 2706 So. Tongass Ave. * Rt. 2; Box 1 - Saxman © Ketchikan, Alaska 99901 ¢ (907) 225-4166 11/17/97 MON 16:10 FAX 503 226 0079 ATER WYNNE FACSIMILE TRANSMITTAL Tam oh @oo1 CL: KAM Ovm 16/97 Coe Ry NOTICE: This facsimile contains confidential information that is being transmitted to and is intended only for the use of the recipient named below. Reading, disclosure, discussion, dissemination, distribution, or copying of this information by anyone other than the named recipient or his or her employees or agents is strictly prohibited. If you have received this facsimile in error, please immediately destroy it and notify us by telephone, 503-226-1191. DATE: November 14, 1997 TO: See Below FROM: Liz Westby DOCUMENT: PAGES (INCL, COVER) 4 City of Wrangell Resolution The Honorable Tony Knowles, Governor of Alaska Juneau, AK Fax: 907/465-3532 Ron Clarke, Special Assistant to the Governor Juneau, AK Fax: 907/465-3532 David Ramseur, Deputy Chief of Staff Juneau, AK Fax: 907/465-3532 Randy Simmons AIDEA Anchorage, AK Fax: 907/269-3044 Representative Gail Phillips Homer, AK Fax: 907/235-4008 Senator Robin Taylor Wrangell, AK Fax: 907/874-3470 Senator Mike Miller Nenana, AK Fax: 907/582-2770 Senator Sean Parnell Anchorage, AK Fax: 907/258-8171 Senator Drue Pearce Anchorage, AK Fax: 907/258-0226 Senator Dave Donley Anchorage, AK Fax: 907/258-1648 Senator Bert Sharp Fairbanks, AK Fax: 907/456-4221 Senator Randy Phillips Eagle River, AK Fax: 907/694-4948 11/17/97 MON 16:10 FAX 503 226 0079 Senator John Torgerson Kenai, AK Fax: 907/283-9267 Representative Alan Austerman Kodiak, AK Fax: 907/486-5264 Representative Ben Grussendorf Juneau, AK Fax: 907/465-2278 H Representative Albert Kookesh Juneau, AK Fax: 907/465-2827 Representative Irene Nicholia Juneau, AK Fax: 907/465-2197 Representative Bill Williams Ketchikan, AK Fax: 907/225-8546 ATER WYNNE Senator Al Adams Juneau, AK Fax: 907/465-4821 Senator Jerry Mackie Juneau, AK Fax: 907/465-3517 Representative Mark Hanley Anchorage, AK Fax: 907/258-8166 Representative Gene Kubina Valdez, AK Fax: 907/835-2097 Representative Norman Rokeberg Anchorage, AK Fax: 907/258-2916 Senator Georgianna Lincoln Juneau, AK Fax: 907/465-2652 Zoo2 11/17/97 MON 16:11 FAX 503 226 0079 ATER WYNNE Moos CITY OF WRANGELL, ALASKA RESOLUTION NO._ 11-97-704 A RESQLUTION OF THE COUNCIL OF THE CITY OF WRANGELL, ALASKA, REQUESTING THE ASSISTANCE OF GOVERNOR KNOWLES AND THE STATE LEGISLATURE TO PURSUE THE SALE OF THE FOUR DAM POOL HYDROELECTRIC PROJECTS TO THE CITIES OF KETCHIKAN, WRANGELL, PETERSBURG, THE KODIAK ELECTRIC ASSOCIATION, AND THE COPPER VALLEY ELECTRIC ASSOCIATION WHEREAS, we represent Wrangell and we are beneficiaries of the long- term benefits which flow from the Four Dam Foo! hydroelectric projects. The projects include Terror Lake, Swan Lake, Lake Tyee, and Solomon Gulch. WHEREAS, the four projects provide power to the cities of Ketchikan, Wrangell, Petersburg, Kodiak, Glennallen and Valdez, and the respective utilities from these communities have collectively operated the projects since 1985. WHEREAS, the Alaska Energy Authority and these utilitles have been negotiating the transfer of ownership of the projects from the State to the utilities for two years, under principles laid out by the State, including the requirement that the existing Power Sales Agreement between the State and the utilities remain in effect after the transfer of ownership. WHEREAS, the Four Dam Poo! utilities submitted a proposal to the Alaska Energy Authority on July 30, 1997, ta purchase the projects. The proposal was subsequently presented to the AIDEA Board, and no action was taken. WHEREAS, the State constructed or acquired the projects for the benefit of the utilities and communities served by the projects. WHEREAS, the State of Alaska has an interest in divesting the Four Dam Poo! projects to the utilities and communities served by the projects, as local utility ownership of the projects will provide significantly greater opportunities for rate reductions, cost control, and the protection of quality of service, WHEREAS, the sale of the projects will benefit the State by releasing the State from ownership liability and alleviating concerns about long-term operations. 11/17/97 MON 16:11 FAX 503 226 0079 ATER WYNNE NOW, THEREFORE, BE IT RESOLVED BY THE COUNCIL OF THE CITY OF WRANGELL, ALASKA: 4. We hereby request that Govemor Knowles assist In dealing with the appropriate State agencies and 1998 State Legislature to pursue divestiture of these projects to the cities of Ketchikan, Wrangell, Petersburg, the Kodiak Electric Association, and the Copper Valley Electric Association. We further request that the State Legislature allow these utilities to secure ownership of the projects as soon as possible, ADOPTED: “November 11 1997 William B, Privett, Mayor . . Christie L. Jamleson, City Clerk oo 11/17/97 MON 16:11 FAX 503 226 0079 ATER WYNNE Moos A RESOLUTION OF THE WRANGELL CHAMBER OF COMMERCE REQUESTING THE ASSISTANCE OF GOVERNOR KNOWLES AND THE STATE LEGISLATURE TO PURSUE THE SALE OF THE FOUR DAM POOL HYDROELECTRIC PROJECTS TO THE CITIES OF KETCHIKAN, WRANGELL, PETERSBURG, AND KODIAK ELECTRIC ASSOCIATION AND THE COPPER VALLEY ELECTRIC ASSOCIATION. Whereas, we represent the Wrangell Chamber of Commerce and we are beneficiaries of the long-term benefits which flow from the four Dam Pool hydroelectric projects. The projects Include Terror Lake, Swan Lake, Lake Tyee and Solomon Gulch; and Whereas, the four projects provide power to the cities of Ketchikan, Wrangell, Petersburg, Kodiak, Glennallen and Valdez and the respective utilities from these communities have collectively operated the projects since 1985; and Whereas, the Alaska Energy Authority and these utilities have been negotiating the transfer of ownership of the projects from the State to the utilities for two years, under principles laid out by the State, including the requirement that the existing Power Sales Agreement between the State and the utilities remain in effect after the transfer of ownership; and Whereas, the Four Dam Poo] utilities submitted a proposal to the Alaska Energy Authority on July 30, 1997, to purchase the projects. The proposal was subsequently presented to the AIDEA Board and no action was taken; and Whereas, the State of Alaska has an interest in divesting the Four Dam Pool projects to the utilities and communities served by the projects as local utility ownership of the projects will provide significantly greater opportunities for rate reductions, cost contral, and the protection of quality of service; and Whereas, the sale of projects will benefit the Sate by releasing the Stale from ownership Ilability and alleviating concern about long-term operations. Now Therefore Be {t Resolved by the Wrangell Chamber of Commerce of the city of Wrangell to: 1, Request Governor Knowles assist in dealing with the appropriate State agencies and 1998 State Legislature to pursue divestiture of these projects to the cities of Ketchikan, Wrangell, Petersburg, and Kodiak Electric Association and the Copper Valley Electric Association; and 2. Further request that the State Legislature allow these utilities to secure ownership of the projects as soon as possible, Qs= Serves (907) 274-1056 Date MAR 1 6 1995 PETERSBURG PILOT Client No.__%ueA Utilities request ownership 4 of state hydroelectric projects Tentative proposal now in state hands, officials say 20 32 By THEO FRANCIS Pilot writer Petersburg could become a part-owner of four state hydro- electric projects, including the Tyee Lake project that serves Petersburg and Wrangell. Under a plan proposed last week, the five member utilities would gradually take over responsibility for running and maintaining the projects, and would keep a growing share of the revenue. The plan was proposed by purchasing utilities, including Petersburg Municipal Power & Light, at a Four Dam Pool Project Management Committee meeting in Juneau. “The purchasers and the state both concur that it has to hap- pen,” said Dennis Lewis, Petersburg Municipal Power and Light superintendent. But, although the state’s Industrial Development and Export Authority agrees with the concept, the agency must now check with the Knowles Administration, he said. AIDA acts as the owner of the projects for the state. “They have to get in touch with the governor to see what the governor’s feeling is on the ownership issue,” Lewis said. “The state has the lead now.” With the utilities collectively owning the four dams, they might be more efficient, said Petersburg Mayor Dave Carlson, also the local voting member on the project commit- tee. “I think it’s worth serious discussion,” Carlson said. “It could be it’s not worth doing, but my gut feeling is it can work.” Before consultants are brought in to examine the trans- fer, Carlson said he wants some assurance that the state is will- ing to consider it. “T do not want to go out and spend a bunch of money with- out knowing there are two will- ing partners at the bargaining table,” Carlson said. The proposal, even if accept- ed by the state, won't necessari- ly mean a drop in local utility bills, said Lewis, who is also chairman of the project commit- tee. “There’s that potential,” he said. “I’m not saying it will hap- rat Little would probably change for cities receiving power from a Four Dam Pool project, Carlson said. Most important to him, the agreement between the utilities and the state would have to stay _in effect as a compact between the utilities and whatever orga- nization formed to own the pro- jects. “My only insistence is that the power-sales agreement stays in place, meaning the pool con- cept,” Carlson said. “There are a lot of advantages to pooling.” That means the utilities would continue to spread the cost of operating the dams equally between users, Carlson said. That’s a good deal for Petersburg, which otherwise might have higher costs. With utility-ownership, the hydroelectric projects could be further developed, according to Lewis. Under state ownership, that isn’t likely, he said — the state just can’t pay for it. “There’s no money available for them to do anything,” Lewis said. In fact, Lewis said, the state doesn’t seem to have the funds to pay for its current obliga- tions. He said that’s one reason for proposing the ownership transfer now. Although it is supposed to pay for some equipment fail- ures, unusual maintenance costs and repairs, the state probably won’t, Carlson said. “They have no ready ability to fulfill their end of the agree- ment,” Carlson said. If the state doesn’t provide the money it’s supposed to, the utilities can withhold their annu- al debt-payment, which goes to the state for its funding of the original dams, Lewis said. Instead, the utilities can use the money for the necessary maintenance, Lewis said. Costly, and necessary, repairs on the Lake Tyee trans- mission line and the dam at Kodiak’s Terror Lake will almost certainly outstrip what the state is willing to pay this year, he said. After years of receiving the debt-service payments without having major costs, the state officials have grown used to the income, Carlson said. “We've been paying the state $10 million to $12 million a year, and they’ve been kind of looking at that as a cash cow,” he said. “And, lo and behold, it’s time for some of that money to go back into the projects.” Under the proposal, the state would gradually reduce its responsibility for the four pro- jects over five years, according to a discussion paper released at the Juneau meeting. The state would also receive proportional- ly less money from the projects. Currently, the utilities pay a flat 4 cents per kilowatt-hour to the state to pay off the state’s debt from building and main- taining the dams. In the first year of the trans- fer plan, the state would be responsible for 40 percent of its normal costs, and the utilities would pay only 40 percent of their required debt-service. Each year the proportions would decline by 10 percentage points, according to the proposal. “Eventually something like this is going to happen,” Carlson said. “They're going to have to get back and let the local governing bodies run these things. “The state should try to get out,” Carlson said. Dare MAR 11 1995_ KETCHIKAN DAILY NEWS YU0A Client No. Class of '42 wants to know Dien br20e4 By LEW M. WILLIAMS, JR. For the Daily News * Wrangell residents say the Tyee Lake- Swan Lake intertie is a sneaky move by Ketchikan to connect the First City to the Outside world by highway. This graduate of Wrangell High School, Class of '42, says they are looking the wrong way down the road. - When this writer attended Wrangell High, there were no television sets, no microwave ovens, no air conditioners, no huge freezer cabinets in stores (no ‘I'Vs, no TV dinners) and many fewer electrical appliances. The population of the town was one-half its current 2,660. ‘The old Fairbanks-Morse diesels took care of Wrangell's electrical demand 50 years ago. They couldn't do it now with all of the new electrical devices and with the population, industrial andinfrastruc- ture growth. But Wrangell and Petersburg have ‘Tyee Lake, part of the state's Four-Dam pool, as is Swan Lake. Tyee generates 20 megawatts and can be expanded to 30. The two towns use 14 megs at peak times. Ketchikan has Swan Lake with about 22 megs of peak power and supple- ments that with the Ketchikan Lakes and Silvis Lakes hydro plants. That isn't enough for all peaks or during times of low water, such as we are experiencing this spring. Ketchikan Public Utilities has been using diesel generators and buying power from Ketchikan Pulp Co. to meet the need. Ketchikan Public Utilities Manager ‘Tom Stevenson explains that there is an important difference between the peak capacity and the annual kilowatt hours, of which there are plenty to spare at Tyee Lake. It is like the operation of an automobile. The car speedometer and the car might reach 100 miles per hour. ‘That peak is not reached often or for more than a few minutes. It's the odom- eter, the distance traveled (which de- pends upon the gas in the tank or the water behind the dam) that counts. In the case of Tyee Lake, there are 134 million kilowatt hours of energy avail- able annually and only 42 million, or 31 percent, are used by Wrangell and Pe- tersburg. That compares with 80 million kilowatt hours available annually from Swan Lake, which is pretty well used up by Ketchikan. ‘he 92 million kilowatt hours of Tyee power currently surplus to Wrangell- Petersburg needs will carry Ketchikan, Wrangell and Petersburg until more generating capacity can be brought on line. It also will provide revenue to the Four Dam Pool for expansion and re- pairing distribution systems. tere eee Those arguing against the Tyee Lake- Swan Lake intertie of 60 miles are miss- ing a look down the right road. Much of the opposition at the environmental impact statement hearings on the inter- tie in the past month have been from environmentalists. They simply oppose any development. They worry about wildlife, scenery, possibility of roads, and so forth. Some suggest that we can conserve our way to sufficient power although history shows that is impos- sible, unless a huge number of people want to go on diets and junk their TV sets and microwaves. The intertie is needed as part of a system planned for all of Southeast Alaska. The Panhandle-wide intertie system was laid out by the old Alaska Energy Authority after an extensive study. (AEA is now a division of the Department of Community of Regional Affairs). Under the long-range plan, the Swan Lake-Tyee Lake intertie would be extended from Petersburg to tie in with the Juneau area's Snettisham. Other tie- ins would be made to Sitka and to the smaller communities in Southeast and to Prince of Wales Island. More poten- tial generation sites, such as Thomas Bay near Petersburg, are available throughout Southeast that can be devel- oped without affecting fish runs and hooked to the interties. For even more generation, a power line can go from Tyee Lake up Bradfield Canal and the Craig River Valley to tie into BC Hydro. We hope that makes a road connection to the Cassiar Highway feasible. BC Hydro ties in with a continental- wide power grid but it alone has a generation capacity of 10,000 megawatts, or 238 times that of Tyee and Swan lakes combined. Hooking Southeast to BC Hydro is like hooking Southeast Alaska highways to the Canadian highway sys- tem. Power can be pumped into South- east from anyplace just as motorists from Southeast can drive anyplace. teeeeeee Before we get to roads, we'll finish with future power and intertie needs. Thomas Bay will be needed with its 70 megawatts. Tyee will have to be ex- panded to 30 megawatts. Ketchikan will have to buy Mahoney Lake power and tap Grace Lake. Snettisham will have to be expanded and Bear Creek built to its full capacity on Prince of Wales Island. Every other hydro site which can be developed without stopping salmon runs will have to be on line to meet the needs of the Class of '42 (2042, that is). Those who are more concerned about the environment and the threat of devel- opment are missing the facts of life. Just as no one predicted for a graduating Wrangell seniorin 1942 that there would be television sets, microwaves and com- puters, people are missing the next big hit to our electrical generating systems, electric cars. There are more than 15,200 vehicles registered in the Ketchikan area, ac- cording to the state Blue Book. What happens if 10 percent of those vehicles are plugged in each night to recharge batteries? Ridiculous, you say? It is the law in California that by 1998 manufacturers of automobiles have to produce a zero emission vehicle. That means an electric car. By the year 2003 {only eight years off) the major manu- facturers have to provide zero emission vehicles for at least 10 percent of the fleet they sell in California. There are 26 million vehicles registered in California this year, its Department of Motor ve- hicles tells us. That is a lot of electric cars. Some of those zero emission vehicles will make their way to Alaska. In fact, the same environmentalists who worry about the electric intertie destroying the environment will be among the first to buy zero emission vehicles to reduce air pollution. Electric cars, even with short range and slow speeds, will be adequate for small, isolated Southeast towns. Intheimmediate future for Ketchikan, a new hotel and commercial buildings are planned for the downtown and an- other cold storage will be constructed soon. We need more power just to main- tain ourselves. What will the Ketchikan or Wrangell High Classes of '42 (2042 that is) use for power? Saying no to the intertie is not the answer. Building the Swan Lake-Tyee Lake intertie and more interties, and building more generation plants, are the only way to assure Alaska Classes of '42 a bright and unpolluted future. Feeeeeet We agree with the airplane pilots who oP ose spans over water for any part of the Swan Lake-Tyee Lake inter- tie. There was an accident 30 years ago when a Grumman Goose pilot glanced’ off the power lines at Petersburg's Blind Slough. Fortunately for plane, pilot and passenger, the pilot was able to make a safe forced landing in Wrangell Nar- rows. Also, underwater cables have proved dependable and cost effective in South- east Alaska. They are not a new phe- nomenon. They provide power to Pennock and Gravina islands from Ketchikan. When the Snettisham hydroelectric project was connected to Juneau, three miles of underwater cable was laid across Taku Inlet. Actually, four cables were laid in 1973 so in the event of a failure, a switch could be made. It has never been necessary, except for test pur- poses. That is 22 years without a cable failure. The Tyee Lake distribution system has had the same success with under- water cable where there are four water crossings to get power to Petersburg. Its four-cable system was installed in 1981 and hasn't failed yet. Underwater cable is more expensive than suspended lines, or is it? When the Tyee Lake distribution line was laid, it cost about $500,000 more per mile to go underwater than to build a suspended line, according to Dick Ballard of Wrangell, coordinator for the project. That would have meant a $30 million distribution line if it all went under water. Except for four water crossings, the Tyee line was suspended across Wrangell Island, Woronkofski Island and Vank Island. The towers were placed too far apart so that lines hang to the ground when iced. Tower foundations have failed. The estimated cost of repair of the suspended parts of the system is $30 million, just what it would have cost to do the job entirely underwater in the first place. b We also should benefit from the trouble Juneau had with its suspended transmission line. In response to com- plaints of environmentalists about run- ning the line along the beach, the first power line was run near the top of mountains and the towers painted green. Weather took the entire line off the mountain the first winter. The line was rebuilt along with beach with metallic gray colored towers, which are found to blend in with the surround- ings. So, there are experiences in South- east on which engineers can profit in designing the Swan Lake-Tyee Lake in- A tertie. feeeeeee Opposition in Wrangell to the Swan Lake-Tyee Lake intertie because it might result in a highway connection to the Lower 48 for Ketchikan is ridiculous. ' Even a road down Bradfield Canal and across Cleveland Peninsula still . _ necessitates a ferry to Ketchikan’s Wrangell, already has pinpointed the Wrangell and Petersburg. Revillagigedo Island. On the other hand, funding, ‘would make Wrangell a main'~j |} aroad from Bradfield Canal has to travel tr: rtation terminal.’ It would ben- : only 12 miles along Eastern Passage efit’ all of Southeast from Petersburg (Back Canal to Wrangellites) until it south when the Prince of Wales fe reaches a narrow crossing from the system is constructed.-That ferry will = mainland to Wrangell Island. Such a give daily or twice daily connections road, for which Sen. Robin Taylor, R- between Prince of Wales and Ketchikan, to know. _ Seeeeeee < "Our question of the week: What's to be gained by killing the Swan Lake-Tyee ~ Lake intertie com with building it? ’ shy The Class of ‘42 (2042, that is) wants, —-— Qans: rites (907) 274-1056 Date JAN 1 7 19 KETCHIKAN DAILY NEWS Client No. GOQ0 A USFS asks for input on electrical intertie $30 AIOM 03390 420M 3U1 120 3344 By TOM MILLER Daily News Staff Writer a The US. Forest Service is seeking public comment on the proposed elec- trical transmission line between Ketchi- kan, the Swan Lake Hydroelectric Project and the Lake Tyee hydroelectric plant. The 60-mile line would intertie the electric systems of Ketchikan Public Utilities, Petersburg Municipal Power and Light and Wrangell Municipal Light and Power, according to a Jan. 6 letter from Linn Shipley, acting Ketchikan District Ranger. It would run north from near the head of Carroll Inlet, across the top of Revillagigedo Island, over Bell Island and onto the mainland to Lake Tyee. Ketchikan relies on the Swan Lake project for most of its generation capac- ity, according to the letter. The projecti is supplemented by smaller hydro sites and diesel generating plants. Swan Lake is now operating near its design capacity but Petersburg and Wrangell use only about one-third of the production capac- ity at Lake Tyee Energy demand in Ketchikan is ex- pected to grow, requiring expansion of generation capacity, said Shipley. KPU has said that use of the surplus energy from Lake Tyee would allow Ketchikan to meet its needs. The utility says surplus energy would provide less expensive, cleaner electrical power to earlier feasibility Ketchikan than the alternative of using more diesel power, according to Shipley. The proposedintertie i lie within a 57-mile-long corridor identified in an study as the preferred site. The corridor is about one mile wide and lies on National Forest System land administered by the Forest Service. It follows lower elevations to minimize visual impacts, avoid steep and unstable areas and avoid extreme weather condi- tions, said Shipley. A 200-foot-wide right-of-way would be cleared for it. It would require long aerial crossings at Eagle Bay, Bell Arm, Behm Canal and Shrimp Bay. The short+ est of those would be 1,200 feet. The longest, over Behm Canal, would be 4,000 feet. Possible variations ihclude construc- tion and use of an access road to serve part of the line. That road would not connect with any existing road and would not provide access between the project area and Ketchikan or other urban area, said Shipley. Underwater cables could be used as an alternative to aerial crossings at Bell Arm, the Behm Canal and Shrimp Ba The aerial conductors would connect to a terminal station or structure on the shore near the water body and continue as self-contained fluid-filled or dielec- tric cables underwater to the opposite See 'Intertie,’ page 2 Intertie Continued from page 1 1306 2wm 0332) U4 Bod 129 334 shore. Other alternatives to meet Ketchikan's energy needs that might be considered could include development of new power generation and electrical load conservation measures, said Shipley. An Environmental Impact Statement will be prepared by the Forest Service to document environmental impacts and alternatives. KPU has contrac. -d with Foster Wheeler Environmental Corp., an envi- ronmental consulting firm based in Washington, to conduct field studies and environmental analyses, direct pub- lic involvement activities and prepare the EIS. The Forest Service would issue a special use permit to KPU to construct an intertie and road on forest land if the EIS is approved. The Forest Service will seek informa- tion, comments and assistance from government agencies, individuals and organizations that are interested in or affected by the proposed activities. The objectives of the current scoping pro- cess, according to Shipley, are: * To identify the affected public and agency concerns. * To define the issues and alterna- tives that will be examined in the EIS. * To eliminate issues not within the scope of the project. * To identify analysis needs. Public meetings will be conducted in Ketchikan, Wrangell, Petersburg and Juneau. The meetings are being planned for the week of Feb. 13-17. Written comments will be accepted through March 6, said Shipley. Shipley asked that comments be as site-specific as possible. Shipley listed the potential issues in the form of the following questions: . ¢ Will construction-related air emis- ‘sions affect the air quality of the study area and/or Misty Fiords National Monu- ‘ment and Wilderness? © Will right-of-way clearing and road construction affect karst and cave re- “sources? * Will activities associated with right- :of-way clearance and road construction degrade fish habitat? © What are the possibilities for chang- ‘ing stream flow and creating barriers to fish migration? © What will be the effect of clearing wetland and riparian areas for the right- of-way and of encroachment and modi- fication of floodplains and estuarine ar- eas? ¢ What are the implications of the proposed action on timber production and sensitive and rare plant species? © What are the potential effects of right-of-way clearing on windthrow? © How will the right-of-way clearing affect wildlife habitat, biodiversity, habi- tat conservation areas, and rare and endangered species? * Would wildlife species used for subsistence harvest be affected by the transmission line and access road? If so, how? Will this affect subsistence lifestyles? ¢ To what degree will the transmis- sion line and access road affect the visual quality of key viewing areas, particularly at Orchard Lake and Eagle Lake, which have been mentioned as potential additions to the Wild and Sce- nic Rivers system? © To what degree will the transmis- sion line and road change the quality and type of recreation opportunities? © Will right-of-way clearing and road construction affect cultural resources? ¢ What are the economic implica- tions for the cities of Wrangell, Peters- burg and Ketchikan? “In addition to the current scoping process, other opportunities to com- ment on the EIS will be provided in the future," said Shipley. Prior to the release of the draft EIS, tentatively scheduled for February 1996, the Forest Service will conduct a series of workshops on the document. After the draft is filed, more public comment time will be available. A final EIS is tentatively planned for October 1996. People who want more information or who want to make comments should contact Becky Cross, EIS Liaison, Tongass National Forest, Ketchikan Ranger District, 3031 Tongass Ave.; or Ellen Hall, Project Manager, Foster Wheeler Environmental Corp., 10900 N.E. 8th St., Bellevue, Wash., 98004. KPU has received $8.6 million from the state to perform design and engi- neering work on the $60 million project, said KPU Manager Tom Stevenson. Once a final EIS is in hand, the project will take 18 months to complete, he said. = ” Bee Preferred Route Attemative Route Revillagigedo Island Graphic courtesy of U.S. Forest Service (Qs: i (907) 274-1056 Date FEB 1.6 1995 PETERSBURG PILOT Client No. Oe 4 Lake Tyee connection Public h 2loM 0320 4204 Few Petersburg residents attended a public session on a proposed power-sharing agree- ment between Petersburg, Wrangell and Ketchikan. The proposal would run a link between the Lake Tyee hydroelectric plant on the main- land and Ketchikan’s Swan Lake power plant’ on Revillagigedo Island. Surplus power from the Tyee project would then meet Ketchikan’s growing power needs until at least 2015, according to projections. Petersburg’s and Wrangell’s electricity needs would still have piiority. Although the Wednesday night hearing was one of the first steps in an environmental assessment of the intertie pro- ject, which is planned for U.S. Forest Service land, most com- ments concerned possible eco- nomic benefits from the project. The project would allow Ketchikan to use Tyee-generat- ed power at night, when demands are low, said Dennis Lewis, superintendent for Petersburg Municipal Power and Light. That would allow Ketchikan’s own Swan Lake to replenish itself, prolonging the efficiency of that project, he said. In addition, by selling the currently unused power from the Tyee project, the. Four-Dam Pool will generate more revenue to cover its relatively fixed costs, Lewis said. Without a proposed third generator for the Tyee Lake project, however, the sharing arrangement wouldn’t be as aring held for electric intertie effective, Lewis said. The intertie will run south from Tyee Lake and cross to Bell Island, then’ to Revillagigedo Island, passing Orchard Lake en route to Swan Lake. Different options call for the line running east or west of Eagle and Orchard lakes. Although current proposals focus on an aerial cable with an access road, some possibilities include helicopter-construction and submarine cables at cross- ing points. Written comments on the impact of the proposed intertie will be accepted until March 6. Send comments to Public Involvement Coordinator, Foster Wheeler Environmental Corporation, 10900 -Northeast 8th. Street, Bellevue, Washington 98004-4405.°"" Q Quolity Services —— (907) 274-1056 _ FEB 23 1995 Dat WRANGELL SENTINEL Client No._ Ute Tyee Lake -- 2iCm 4204 632d : by Allen L. Bird burg, through Thomas Bay Power Not many communities are as Authority. It is almost as good as fortunate to have power supplied having a goose that lays golden as it is in Wrangell and Peters- eggs. Aproblem is, like that goose, it is attractive enough to make other communities look covetously at the system. Itis going to take more be Pee tunnel leading through a granite mountain to Tyee Lake, 1,397 feet above sea level on the mainiand southeast of Wrangell Island. POWER SOURCE - Electricity serving Wrangell and Petersburg begins in the generators In the power plant (arrow) that covers the end of a than just a casual glance to see if the goose is able to produce enough eggs (a.k.a electrical power) to take care of the communities with first priority. LOWELL HIGHBARGIN, general manager of Thomas Bay Power Authority. What might be confusing to some is the name, Thomas Bay Power Authority, when no power comes from Thomas Bay. It was originally planned that power to the system, one of four major hy- dro-electric power projects in the state, would come from Thomas Bay, north of Petersburg. When it A tale of two cities' electrical power was determined that it was more efficient to produce power using water from Lake Tyee, the origi- nal project name stuck. Swan Lake, source of Ketchikan’s pri- mary power, is also part of the “Four Bam Pool,” as are Solomon Gulch and Terror Lake. The latter two serve Glenallen, Valdez and Kodiak. All are state owned. Lake Tyee is in the mountain south of Bradfield Canal, just a few miles east of Anan Bear Ob- servatory. Generating electricity through use of water power has been common in the Lower 48 since depression days when dams such as Hoover, Peck and Grand Coulee harnessed some of America’s heavily flowing rivers. There’s adifference inthe Tyee project, built during the years 1981-84. At Tyee, no dam was con- structed. This hydro-electric sys- tem gets its water pressure more like pulling a plug from the bot- tom of a bathtub. It’s not unique. This “bottom tap” system, is also utilized at Snettisham, southeast of Juneau. But, for most people not living in Europe, where the technique is fairly common, it is Continued fon back page Tyee power consumption increasing | faster than was ori A071 UPe « Continued ‘from page 1 unusual, With the water already there, replenished by rain and snow, engineers just had to decide where to install a “drain pipe.” Beginning close to sea level, a 7,220-foot tunnel was blasted out of the granite mountain, almost horizontally, until it was approach- ing a spot under the lake. At that point, a 1,122-foot shaft was carved toward the surface and an angled tunnel connected the shaft to the lake, 146 feet below the normal lake surface level. (Maxi- mum is at 1,396 feet but it draws down in winter.) The tunnels and shaft allows water to be directed downward into an extensive pipe system, called the penstock, to the power plant thatencloses the open- ing down at the head of the canal. Here is where the power is gener- ated. With two “impulse” type tur- bines installed, 20 megawatts of power can be produced. Space in the power building was provided, during initial construction, to al- low a third turbine and generator to be installed. These turbines, which convert water pressure to electricity, are 90 percentefficient, says Carl Thrift, foreman at the power plant. Thrift said the generators pro- duce 13,800 volts but power is “shipped out” at 69,000 volts to power stations where it will be converted to voltages that can be utilized by industry, homes and businesses. Electricity reaches the two prime “middleman” customers, the cities of Wrangell and Peters- burg, over 81.9 miles of power - lines. The majority, 70.5 miles, is overhead lines but 11.4 miles is submarine. Encased in pressur- ized oil-filled tubing, the power lines go from the mainland to the south end of Wrangell Island. After angling over Wrangell Is- land, the line is under water to Elephant’s Nose on Woronofski Island, is then submerged, with a short jump across Vank Island, until it reaches Mitkof Island, on the way to Petersburg. At the present time, Lake Tyee is capable of producing more megawatts of power than is uti- lized by Wrangell and Petersburg, leaving a surplus that could be sold— much of the time. But, the surplus is getting smaller each year. During the four or five sum- mer months, June through Sep- tember, both generators operate continuously, except when down for maintenance. Last year, they were, at times, running both gen- . erators through mid-December. “We're about 10 years ahead of our projected growth in power usage,” said Lowell Highbargin, general manager of Thomas Bay Power Authority. “Highest de- mand in 94 was 13.7 megawatts. In 1989 peak demand was 11/02.” During winter months, when water is not spilling, there is con- siderably less surplus power avail- able at this time. “We have to back off to where 14/8 megawatts is the maximum that can be con- tinuously produced.” Higher pro- duction would use too much wa- ter, Atthe rate power consumption is growing, it is questionable if much surplus power would be available to sell. When you con- sider how long it will take to have the proposed intertie completed and operating, and the cost, any value to Ketchikan should be looked at carefully, Highbargin indicated. Highbargin, who had previ- ously managed Solomon Gulch power plant at Valdez, maintains his office at the power station on Zimovia Highway, south of Wrangell. Thrift, formerly a millwright, is one of three men living and working at the power plant. He, Dave Shilts, an electrician, and mechanic Barre Gadd, handle the majority of maintenance problems thatcome up at the plant. Mostly, they say, it is regular, scheduled preventive maintenance. There are pleasant homes avail- able for personnel assigned to the project at the site. There isn’t much sunlight in the area, how- ever. No sun actually reaches the site from October through March. “You can see it out there on the otherside of the canal,” said Thrift. iginally projected BARRE GADDrunsa scheduled check on power production They also don’t get any television. “We watch lots of video movies.” The videos come in on twice- weekly Sunrise Aviation flights, the same planes that bring them mail, groceries and other needed supplies. Thé men work 10 days on duty and four off. They can leave the island and goto Wrangell on Sunrise flights. EE LAKE HYDROELECT ENERGY REGULATORY COMMISSION P OWNED BY ALASKA POWER AUTE OPERATED BY THOMAS BAY POWER ss SERVING PETERSBURG AND WRANGELL > rag aace omen PLANT FOREMAN Carl Thrift traces the route of power lines to users in Wrangell and Petersburg. (907) 274-1056 Date _FEB 23 1995 WRANGELL SENTINEL Client No.4 2a A Intertie meetin RIOM 4229 Zoe 150 F4h dROD 0376 by Allen L. Bird If interest in the proposal can be judged on numbers attending, it is evident that more people in Wrangell are concerned with the proposed intertie of Swan Lake and Tyee Lake hydro-electric projects. More than 20 attended the planning meeting at Wrangell City Hall Feb. 16; only about 15 showed up for the corresponding meeting in Ketchikan two days earlier. At both meetings, the recep- tion probably fell short of what the planners had hoped. Although designed to help Ketchikan stave off a power shortage, opposition in that city was reportedly strong, based onconcern forenvironment, aviation safety and economics. It quickly became clear that in Wrangell opposition was based on economics and a fear of losing control of the power system. There also seems to be a feel- ing that the line needed for trans- mission of electrical power is merely a poorly disguised excuse to construct a highway connect- ing Ketchikan with the the rest of the world without Alaska’s ferry system. Vicinity map of proposed and alternative routes. g generates resistance As is currently proposed, a 60- mile line would intertie the electri- cal systems of Ketchikan with Tho- mas Bay Power Authority that sup- plies Wrangell and Ketchikan. If completed, Ketchikan Public Utili- ties (KPU) would.be able to meet some of its needs by purchasing surplus power from Thomas Bay’s generators at Lake Tyee. Since the transmission line would. be almost entirely in Tongass National Forest, the U.S. Forest Service is responsible for determining a variety of concerns within its jurisdiction. Among the considerations are fish and wild- life habitat, air emissions during construction, timber production, sensitive and rare plant species, wetland and riparian areas forright of way, subsistence harvesting of wildlife, recreation, cultural -re- sources pad ecoucuntics for the tere, cities. * Forest Sabie: lacking person- * nel staffing to prepare an Environ- mental Impact Statement (EIS), has hired Foster Wheeler Environ- - Continued-on back j pager.) >. Wrangellites question cost, benefits of power intertie 210M 4RAA Fob 130 sus Continued from page 1 mental Corporation of Bellevue, Wash., toconduct field studies and environmental analyses. A Foster Wheeler team is already at work directing public involvement ac- tivities and will prepare an EIS that is to meet regulations of the Na- tional Environmental Policy Act and Forest Service procedures. Initial scoping meetings were held for the week of Feb. 13-17, with ameeting in Petersburg sched- uled following the Ketchikan and Wrangell meetings. Following an explanation of the project, its cost, proposed benefits and a time table for completion by Ellen Hall and Dave Jenkins of Foster Wheeler, with additional input from Dave Rak of Wrangell District Forest Service, Wrangellites were offered the op- portunity to ask questions and express opinions. Questions included cost of the study and who was paying for it. The figure given was $1.9 million to be paid by KPU. Further ques- tions brought out, however, that the money came through a state grant. So, it is apparently taxpay- ers’ money. Total cost of the project, ifitis decided to go through with it, could easily amount to more than $70 million. It will take al- most two years just to complete the study. Wrangell Councilmen Douglas Roberts questioned the feasibility of the project, asking if Lake Tyee had enough water to handle addi-~ tional demands on power produc- tion. He was told that this question would be part of the study. Dick Ballard, when it came his time to speak, said it was already estab- lished that any additional genera- tion from Lake Tyee would require construction of a 50-foot dam where the small creek currently flows from the lake in order to provide adequate water head to handle installation of a third gen- erator. Ballard said that without the dam and third generator, both of POA OF7D which would add tremendously to the cost of the project, the transmission line intertie would be ofno benefit. It would only be able to supply interruptible power, he claimed. Ballard said there was obviously no simple solution to Ketchikan’s need for power, rapidly becoming critical, but there surely must be a better one than is being currently proposed. Roberts also questioned the extent of study by KPU onsources of additional power in the Ketchikan area, without con- structing a road to Bradfield Ca- nalareaand the Tyee power plant. He asked if the people pushing for the intertie were seeking a transmission line or just using it as an excuse to construct a road that could eventually be a high- way intertie with a road through Canada. Bruce Harding, another Wrangell councilman at the meet- ing, asked Hall about the criteria that would be used to say the project was not feasible. In response, Harding was told that it would be based, in large measure, on economic feasibility and if construction would involve serious environmental impact — in the point of view of the Forest Service or other agency. Decid- ing officer is‘to.be Linn W. Shipley, acting district ranger at Ketchikan. John Martin, who also ex- pressed the opinion that the project was-a~quest for a road corridor, not a power need, said he was finding himself in an un- usual position. “I’m looking for spotted owls so we can shut this thing down,” he said. Terry Nikodym said he wanted to see an exact count of the spot- ted frogs come out of this study. Wrangellites can add their in- putto the scoping process by con- tacting Becky Cross, EIS Liai- son, Tongass National Forest, Ketchikan Ranger District, 3031 Tongass Avenue, Ketchikan, AK 99901, (907) 225-2148. ae ae Municipal of Anchorage Municipal Pie Miyetotn Mayor 1200 East First Avenue Anchorage, Alaska 99501-1685 2 Telephone: (907) 279-7671, a (907) sere 5804, 277-9272 March 26, 1998 Alaska Industrial Develosmen and Export Authority Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of February 1998. Sincerely, Doug Hal Chief Power Dispatcher DH/pjc Attachment cc: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA eit-pattylocso-optting.Energy into Anchorage for Over 60 years 26-Mar-98 ALASKA INTERTIE USAGE REPORT FY 98 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT JULY 2408 0 32838 0 798 0 0 0 0 oO 0 0 AUGUST 2023 0 26584 0 832 O 0 0 0 0 0 0 SEPTEMBER 4617 0 22827 0 843 0 0 507 0 0 0 oO OCTOBER 6825 0 20691 0 1057 0 0 ° 0 0 0 0 NOVEMBER 1593 0 24430 0 995 0 0 0 0 0 0 0 DECEMBER 1177 0 34782 0 985 0 0 0 0 0 0 0 JANUARY 116 0 26514 0 1011 O 0 O 0 0 0 0 FEBRUARY 525 0 12482 0 921 0 0 0 0 0 0 0 MARCH APRIL MAY JUNE YR TOTAL 19284 0 201148 0 7442 0 0 507 0 ° 0 0 ENERGY $ YTD MONTH MLP DELIVERIES CEA DELIVERIES BL DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS LINE TOTAL JULY 2408 33636 0 0 0 35246 0 0 0 798 36044 AUGUST 2023 27416 0 0 0 28607 0 0 0 832 29439 SEPTEMBER 4617 23670 0 507 0 27444 0 507 ° 843 28794 OCTOBER 6825 21748 0 oO 0 27516 0 0 0 1057 28573 NOVEMBER 1593 25425 0 ° 0 26023 0 0 0 995 27018 DECEMBER 1177 35767 0 0 0 35959 0 0 oO 985 36944 JANUARY 116 27525 0 0 0 26630 0 0 0 1011 27641 FEBRUARY 525 13403 0 0 0 13007 0 0 0 921 13928 MARCH 0 0 0 0 0 0 0 0 0 0 0 APRIL 0 0 0 0 0 0 0 0 0 ° 0 MAY ° 0 0 0 ° 0 0 0 ° 0 0 JUNE 0 oO O 0 0 0 oO 0 0 0 0 YR TOTAL 19284 208590 0 507 0 220432 0 507 0 7442 228381 ENERGY $ YTD $1,121,998.88 $0.00 $2,580.63 $0.00 $37,879.78 $1,162,459.29 26-Mar-98 ALASKA INTERITE USAGE REPORT FY 98 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS AEGT TO GVEA AEGT TO FMUS GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT JULY 0 0 0 0 0 0 0 0 0 0 0 AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 0 . 0 0 0 0 0 0 0 0 0 0 0 ocooaooc lo eoooaoeoco oe ecooaoaoco lo coco aoco eo ecooooc le coooooco eo coooeoaoc fe oooooco oe eoooaoc eo eooaoaoc ef coco oc eo coo ocooca lf MONTH MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL JULY 0 0 0 0 0 0 0 0 0 AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL sooo oe OCC OC Seco OOOO OOO CO sco eo eo OOO COC Sscooeo eo OO COCO CO Sseeoooe eo OO CCC CS esecooeo oe O COCO CO seooeo oe OOOO CO Secooao eo OOOO CO sooo eo CCC COC Sooo OOOO OCC CO Sseoo oOo OC OOO COC $0.00 $0.00 $0.00 $0.00 $0.00 $0.00 mw WA ae Municipality of Anchorage Municipal Light & Power ek ee 1200 East First Avenue Anchorage, Alaska 99501-1685 Telephone: (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 March 26, 1998 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: As of March 26, 1998, all tower cell phones for snow load monitoring equipment are functioning normally. Respectfully, e Doug H Chief Power Dispatcher DH/pjc ewatarpayhtting..mergy into Anchorage for Over 60 years Li “CHUGACH ELECTRIC ASSOCIATION, INC. Cie lectric ASSOCIATION, INC. April 14, 1998 Mr. Stan Sciezkowski AIDEA 480 W. Tudor Rd. Anchorage, AK. 99503 Re: Disposal of Westinghouse DWE Type Breaker Reference AIDA letter of 3/28/98 — Alaska Intertie Equipment Mr. Sciezkowski: Per your request, this letter is verification that the referenced breaker (previously located at the Teeland AEA Substation) has been permanently disabled, removed, and disposed of. Its serial number was 65Y1039. Should you need any other information on this subject, please contact me at 762-7661. Sincerely pee R Rie Paul R. Risse Manager of Substation Operations PRR/s (P:/Substation Dept/TLD_BKR_Disposal) Attachment: AIDEA Disposal Authorization 5601 Minnesota Drive ¢ P.O. Box 196300 ¢ Anchorage, Alaska 99519-6300 Phone 907-563-7494 © FAX 907-562-0027 ALASKA INDUSTRIAL DEVELOPMENT * Sea xscuni SOT cet = ALASKA ME ENERGY AUTHORITY 480 WEST TUDOR ANCHORAGE, ALASKA 99503 907 / 269-3000 FAX 907 / 269-3044 March 28, 1997 Mr. Paul Rissee RECEIVED Manager Substation Operations AP} Chugach Electric Association RO 1 1997 5601 Minnesota Drive Operationg Anchorage, Alaska 99519-6300 RE: Alaska Intertie Equipment - Disposal of Westinghouse Type DWE Power Circuit Breakers Dear Paul, The Alaska Energy Authority authorizes Chugach Electric Association to dispose of the Westinghouse Circuit Breaker Type DWE. This circuit breaker has no salvage value due to age and condition of components. Also, it was removed from service due to the safety warning from Westinghouse Electric Corp. The manufacturer stated that “the lower bushing flange is subject to cracking and could lead to a catastrophic failure and that a potential exists for damage to substation equipment and injury to personnel or even death.” Therefore, please disable the Power Circuit Breaker so this circuit breaker or any of its components cannot be used. You are then authorized to dispose of the circuit breaker remains. Please verify to me when you have disabled and disposed of this circuit breaker. Sincerely, Stan Sieczkowski Manager, Maintenance and Operations CC: Dennis McCrohan, AIDEA : ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY /= ALASKA mE ENERGY AUTHORITY 480 WEST TUDOR ANCHORAGE, ALASKA 99503 907 / 269-3000 FAX 907 / 269-3044 November 25, 1997 Ms. Linda Holzman State of Alaska Department of Natural Resources, Division of Lands 3601 C Street, Suite 1080 Anchorage, AK 99503-5937 Subject: Anchorage Fairbanks Intertie Right-of-Way Notification of Maintenance Clearing DNR-ADL-213063. Dear Ms. Holzman: As discussed in our telephone conversation of this date, the Alaska Energy Authority plans to perform routine right-of-way clearing of the subject transmission line, in the section located between the Douglas substation (north of Hatcher Pass/Willow Creek Road) to the Stevens substation (south of Yoder Road). Clearing is planned for the December 1998 - February, 1999 period. If you have additional questions concerning this matter, please do not hesitate to call me at 269-3000, or call our consultant for regulatory compliance matters, Jim Thrall, at 258-2200. Sincerely, e Stan Sieczkowski fo 7 Operations Manager SS/JHT/kav cc: J. Thrall, LIL | File 4 STATE OF ALASKA DEPARTMENT OF NATURAL RESOURCES DIVISION OF LAND xe S DY « 3601 C Street, Suite 1080 . ms Anchorage, Alaska 99503-5937 (907) 269-8552 APPLICANT ENVIRONMENTAL RISK QUESTIONNAIRE The purpose of this questionnaire is to help clarity the types of activities you propose to undertake. The questions are meant to help identity the level of environmental risk that may be associated with the proposed activity. The Division of Land's evaluation of environmental risk for the proposed activity does nat imply that the parcel or the proposed activity is an environmental risk from the presence or use of hazardous substances. Through this analysis, you may become aware of environmental risks that you did not know about If so, you may want to can- sult with an environmental engineer or an attorney. Stan Sieczkowski, Operations & Maintenance Mgr., Alaska Energy Authority(AEA) Apolicant Name Ooing Business As 480 West Tudor Road, Anchorage, Alaska 99503 Address Clty State Zp por 345-5875 004 258-2200 Jim Thrall Home Phone Work Phone Contact Person Describe the proposed activity: Permission to cross Department of Natural Resources lands near Curry(Township 29 North, Ranges 3&4 West) is requested to perform maintenance work on two damaged transmission line structures. The structures, located within our permanent 400' wide Alaska Intertie easement, are unstable and need to have their foundations repaired or replaced. An inspection is scheduled for Summer of 1998, with construction activities scheduledfor summers 1999-2000, In the course of your proposed activity will you generate, use, store, transport, dispose of, or otherwise come in cantact with toxic and/or hazardous materials, and/or hydrocartons? Yes (x] No[ J If yes, please list the substances and the associated quantities, Use a separate sheet of paper, if necessary. Only that fuel and_oil required _to operate vehicles to access our eo easement will be used; no storage of any substance will occur. 102-4008A.frm (Rev, 4/36) If the prongged activities involve any storage tanks, either above or below ground, address the following questions for each tank. Please use a separate sheet of paper, if necessary, and, where appropriate, include maps or plats: a. Where will the tank be lecated? N/A b. What will be stored in the tank? c. What will be the tank's size in gallons? d. What will the tank be used for? (Commercial or residential purposes?) e. Will the tank be tested for leaks? f. Will the tank be equipped with leak detection devices? [] Yes [] No !fno, describe: Co you have any reason to suspect, or do you know if the site may have been previously contaminated? Yes[{ } Nof<}~ If yes, please explain: | certify that due diligence has been exercised and proper inquiries made in completing this questionnaire, and that the forego- ing is true and correct to the best of my knowledge. TM Gein afr sfelve Applicant Stan Sieczkowski Date AS 38.06.035{a) authorizes the director to decide what Information is needed to process an application for tho cate or use of state and and fesources, This informadon is made a part of the state public land records and becomes public information under AS 09.25.1140 and 09.25.120 (untess tho information qualifies for confidentiality under AS 38.05.036{a}(9) and confidentiality Is requested), Public information ts open to \nspection by you or any member of the public. A person who is the subject of the information may challenge Its accuracy or completeness under AS 44.99.3510, by giving 3 written description of the challenged information, the changes needed to correct it, and a name and address where the person con be reached. False statements made In an application for a benefit are punishable under AS 11.56.2140. 102-4008A.frm (Rev. 4/36) STATE OF ALASKA mono AR Box 667 DEPARTNENT OE SE aca’ prin Asis Habitat & Restoration Divi E g EVE 772-9336 abila estoration Divis JUL 0 6 1998 June 29, 1998 Alaska Industrial Development and Export Authority Mr. Stephen M Hart, P.E. Project Manager R.W. Beck, Inc. 1001 Fourth Avenue, Suite 2500 Seattle, WA 98154-1004 Re: Sunrise Lake Water and Hydroelectric Project, FERC Project No. 11591-000 Alaska Department of Fish and Game comments on the Sunrise Scoping document. Dear Mr. Hart: The Alaska Department of Fish and Game’s (ADF&G) has reviewed the Sunrise Lake Water Supply and Hydroelectric Project, May 1998. These comments represent the review of the scoping document, the site visit of May 28, 1998 and subsequent communications. Our comments repeat and supplement those contained in our letters of 6/7/98 and 6/27/98 with respect to information needs This information will be required to define the need for additional instream flow related investigations, and the types of investigations needed. Pre-, during construction, and post construction plans are required. Plans for emergency shut downs and maintenance are also needed. If mitigation alternatives are presented, the costs and specifics should be identified and a plan for placing them in escrow presented. An expanded detailed schedule for pre and post licensing steps is required as requested in our prior correspondence regarding the “Communications Protocol”. We have provided an example of the schedule details and format needed in eariier communications (see Old Harbor, Alaska APEA schedule which was provided as an example). For example, road construction and improvement plans should be presented in detail, and not simply as an optional “contractors choice”. The ADF&G and applicant have limited fish and wildlife knowledge of the project area. Thus, a better understanding of seasonal fish and wildlife species composition and distribution by life phases within the project area are needed. During the site visit (5/28/98) I located the remains of pink salmon jaw bones along the bank approximately 300 feet above the upper inter-tidal area. I was not able to survey the habitat between this area and the falls. Included should be: FISH e Seasonal distribution of anadromous and resident fish species by life phases Special emphasis should be placed on defining the uppermost extent of anadromous fish distribution. e Characterization of seasonal passage, spawning, incubation habitats by species. e Sampling Sunrise Lake to verify the presence or absence of resident fish. If fish populations are verified the further studies should include the identification of spawning habitat and impacts of lake water level fluctuations on fish production within, upstream, and downstream of the reservoir.. e Fish sampling methods should include electroshocker, baited minnow and hoop traps in the bypass reach with the addition of a variable mesh gill net in the lake and applicable to the species, life phase and habitat to be sampled. . e Impacts of the submerged pipe including construction phase across Zimovia Strait on commercial fisheries, specifically shrimp trawl should be evaluated. WILDLIFE e The extent of beaver activity and the affect of lower water levels in the beaver area. e Waterfowl use of the lake and beaver area. e Impacts of construction activity and camp on deer. e Impacts of helicopter activity on eagles, waterfowl and deer. HYDROLOGY Additional hydrologic information is needed and should be collected on a continuous basis to evaluate seasonal input/output relationships of stream flow within the project area. Seasonal lake level and volume should be integrated into water balance evaluations. Gaging at the outlet to the lake needs modification to capture all of the water being released. During our site visit it appeared as though a portion of the water from the lake was not being measured. Also, we request seasonal temperature profiles of the lake and downstream reaches to identify temperature sensitive habitat. Additional information needs may be generated based on findings of these studies. Specific details regarding the procedures used to estimate the current synthetic flow analysis estimates are needed. Additionally, how and why were sites used in the correlation selected? Were U.S. Forest Service, the Orsborn, and U.S.Geological Survey Hydrologic models considered? Among desired long- term flow calculations are: monthly duration analyses, one in two year peak flood flows estimates, mean daily flows, mean monthly flows are required. e Location and estimated flow of all tributaries assumed to contribute 5% of more of the flow in the mainstem reach downstream of the tributary. . e Lake Depth Data Seasonal velocity and depth characteristics of key habitats, e.g. tributaries to the lake, outlet of the lake, beaver pond area, anadromous reach area, any water body reach used by fish and wildlife that will potentially be impacted. OTHER COMMENTS Project and infrastructure details must be expanded. Specific information should be acquired and analyzed, as summarized below relating to all aspects and components of the project (including the water supply pipeline): power generation, transmission facilities, road or other access, buildings, and other hydroelectric projects that may be interconnected or impacted by this project. As an example, if road construction and improvement will occur, plans with schedules should be presented in detail, and not simply as an optional “contractors choice”. Additional information needs may be generated based on findings of these studies. I have attached an example of a periodicity chart for your reference. Sincerely, fret ocala James P. Cariello Habitat Biologist ce: Lana Shea Flanders, ADF&G H&R, Douglas Janet Kowalski, ADF&G H&R, Juneau William Hanson, ADF&G H&R, Douglas Christopher Estes, ADF&G SF/RTS, Anchorage Dean Beers, ADF&G SF, Petersburg Ed Crane, ADF&G, WC, Petersurg Bryan Lynch, ADF&G, CF, Petersburg Phil Mooney, ADF&G H&R, Sitka Dave Bright, ADF&G SF, Crystal Lake Hatchery, Petersburg Steve Brockmann, USFWS, Ketchikan Jane Fadely, NMFS, Juneau Randy Hojem, Wrangell, USFS Steve Brady, Wrangell, USFS Nick Jayjack, FERC, Washington DC Linwood A Watson, FERC, Washington, DC John Dunker, ADNR, Juneau Duane Peterson, USFWS,, Juneau Liorraine Marshall, DGC, Juneau Dave Sturdevant, ADEC, Juneau Raymond Alt, Tyee Lake Hydro Stan Siecuszkowski, AIDEA, Anchorage Judith Bittner, AK Office of History, Anchorage Rick Albright, USEPA, Anchorage Ryan Winn, COE Harry Hall, FERC, Portland David Boergers, FERC, Washington, DC Richard Stokes, Alaska Native Brotherhood, Steven Hart, R.W. Beck, Seattle Scott Seabury, City of Wrangell Tim Gillen, City of Wrangell GENERAL FRESHWATER AND ESTUARY RESIDENCE AND/OR UTILIZATION FOR PACIFIC SALMONIDS FOR THE STIKINE AREA TIMING WINDOWS FOR INSTREAM CONSTRUCTION ACTIVITIES PINK/CHUM |----------------| (June 1 - Aug 1) COHO |-----------------------------|_ (June 1 - Sept 15) STEELHEAD |--------| (July 15 - March 1) JUN JUL AUG SEP OCT NOV DEC JAN FEB MAR APR PINK SALMON SALMON SOCKEYE SALMON CHINOOK SALMON COHO SALMON STEELHEAD CUTTHROAT ADULT TROUT (resident) EGG/ALV DOLLY VARDEN (resident) Note: These are generic timing windows and site specific information should take precedence. Because of the variability of fish presence, abundance, and timing by the system, the exact dates of allowable construction may vary. Site-specific fisheries and field information, including the A.D.F.& G. Anadromous Stream Catalog, should be used to determine timing windows for instream activities. M dN 1 C€ tf P @€ kL tt Y o F a N € H O R €@€ G E Rick Mystrom = Mayor EGEIVE/) SEP 24 1998 September 22, 1998 Alaska Industrial Development and Export Authority MEP Municipal Light & Power = Mr. Stan Sieczkowski AIDEA POWER MANAGEMENT 480 West Tudor Road 1200 East First Avenue Anchorage, Alaska 99503-6690 Anchorage Alaska Dear Stan: 99501-1685 Please find attached the revised Alaska Intertie Usage Report for the current fiscal e year through the month of August 1998, showing 67 MWH AIDEA to CEA. phone 5 907.263.5450 Sincerely, fax 907.263.5441 mie nai Chief Po patcher DH/pjc Attachment CG: M. Kohler, ML&P S. Matthews, AEGT B. Evans, GVEA J. Cooley, CEA J. Hall, MEA C.Petty, AEA ¢:\1-patty\I[OC\so-oprtr\usage\cov-Itr.doc 21-Sep-98 ALASKA INTERTIE USAGE REPORT FY 99 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT AIDEA TO CEA AIDEA TO MLP AIDEA TO AEGT JULY 684 0 9912 0 0 0 0 0 0 0 0 oO AUGUST 602 0 6405 ° 45 0 143 0 0 67 0 0 SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 1286 0 16317 0 45 0 143 0 0 67 0 oO ENERGY $ YTD MONTH MLP DELIVERIES CEA DELIVERIES BL DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS LINE TOTAL JULY 684 9912 ° 0 0 10596 0 0 0 0 10596 AUGUST 602 6450 oO 143 67 7007 0 0 210 45 7262 SEPTEMBER 0 0 ° ° 0 0 ° 0 o ° ° OCTOBER ° oO 0 0 0 0 ° 0 0 0 0 NOVEMBER 0 0 ° 0 0 0 0 0 0 0 0 DECEMBER oO 0 0 0 0 O 0 0 0 0 0 JANUARY 0 0 0 0 0 0 0 0 0 O 0 FEBRUARY 0 0 0 0 0 0 0 0 0 0 0 MARCH 0 0 0 0 0 0 0 0 0 0 0 APRIL 0 0 0 0 0 0 0 0 0 0 0 MAY 0 0 0 0 0 0 oO 0 ° 0 oO JUNE 0 0 0 0 0 0 0 0 0 0 0 YR TOTAL 1286 16362 0 143 67 17603 0 0 210 45 17858 ENERGY $ YTD $90,655.45 $0.00 $0.00 $1,081.50 $231.75 $91,968.70 BILLING CODE 6717-01-M UNITED STATES OF AMERICA FEDERAL ENERGY REGULATORY COMMISSION NOTICE OF ISSUANCE OF DRAFT LICENSE APPLICATION AND PRELIMINARY DRAFT ENVIRONMENTAL ASSESSMENT (PDEA) (October 22, 1998) Take notice that the following hydroelectric application has been filed with the Commission and is available for public inspection: a. Type of Application: Major New License; Applicant-Prepared Environmental Assessment Process Project No.: 11588-000 Applicant : Alaska Power & Telephone Company (AP&T) Name of Project: Otter Creek Hydroelectric Project Location: Entirely within the Tongass National Forest, on Kasidaya Creek three miles south of Skagway, Alaska Applicant Contact: Mr. Robert Grimm, President Alaska Power & Telephone P.O. Box 3222 Port Townsend, WA 98368 Send Comments to : Mr. Glen Martin, Project Manager Alaska Power & Telephone P.O. Box 3222 Port Townsend, WA 98368 1-800 982-0136 (360) 385-1733 X122 FERC Contact: Carl Keller (202) 219-2831 AP&T mailed a copy of the Preliminary Draft Environmental Assessment (PDEA) and draft license application to interested parties on October 19, 1998. The Commission received a copy of the PDEA and draft license application on October 20, 1998. With this notice, we are soliciting preliminary terms, conditions, prescriptions, and recommendations on the PDEA, and comments on the draft license application. After the application is officially filed with the Commission, we will request final terms, conditions, prescriptions, and recommendations on the DEA and final application. DC-A-22 Sonia] BE /So~/ File Project No. 11588-000 “/S All comments on the PDEA and draft license application for the Otter Creek Project should be sent to the address noted above in item (f) with one copy sent to the Commission at the following address: Carl J. Keller, Project Coordinator Federal Energy Regulatory Commission Office of Hydropower Licensing - Room 6H-10 888 First Street, N.E. Washington, DC 20426 All comments must (1) bear the heading "Preliminary Comments", "Preliminary Recommendations", "Preliminary Terms and Conditions", or "Preliminary Prescriptions"; and (2) set forth in the heading the name of the applicant and the project number of the application. Any party interested in commenting must do so before January 18, 1999. With this notice, we are initiating consultation with the STATE HISTORIC PRESERVATION OFFICER, as required by § 106, National Historic Preservation Act, and the regulations of the Advisory Council on Historic Preservation, 36 CFR 800.4. Linwood A. Watson, Jr. Acting Secretary ENERGY REGULATORY COMMISSION — WASHINGTON, D.C. 20426 OFFICIAL BUSINESS PENALTY FOR PRIVATE USE, $300 P-11588 STAN SLECZKOWSKT ALASKA ENERGY 480 WEST Topor ANCHORAGE, AK 99503 101479 MANAGER AUTHORITY 0a U.S. OFFICIAL MATL? PENALTY FOR PRIVATE USE $300 * 7230618" LVS. POSTAGE Ssaanaa NOU @6 °97 16:54 FR DRYDEN & LARUE 987 522 2534 TO 2693044 P.61 IDRYpEN ¢ LalRue CONSULTING ENGINEERS 6436 Homer Drive, Anchorage, AK 99518 Mailing Address: P.O. BOX 111008, ANCHORAGE, AK 99511-1008 (907) 349-6653 @ FAX 522-2534 COVER LETTER This telecopier message is coming from the office of Dryden & LaRue, Fax # (907)522-2534. It consists of _4 pages including this page. Sent to: John Kennedy Sent by: Al Peabody Date: November 6, 1997 John, Attached is a draft of a proposal to provide technical support for the Snow Load Monitoring System. If you have any questions, please give me a call. CH be cc: Stan Sieczkowski Electric Power: Transmission, Distribution, Substations, Control Systems, Generation, System Studies NOV @6 °97 16:54 FR DRYDEN & LARUE 987 S22 2534 TO 2693044 P.@2 1!!! DRAFT !!! November 6, 1997 Mr. John Kennedy MATANUSKA ELECTRIC ASSOCIATION P.O. Box 2929 Palmer, Alaska 99645 Reference: Anchorage - Fairbanks Intertie Snow Load Monitoring System Propesal for Technical Support for Operation and Maintenance Stan Sieczkowski requested that we prepare a scope of services and budget for providing MEA with technical support for the operation and maintenance of the Anchorage - Fairbanks Intertie Snow Load Monitoring System. We are prepared to provide support services in three areas: training, maintenance and “proofing” the system. Training Some formal training of dispatchers and others concerning the operation of the SLMS may be desirable. We will work with MEA and the other involved utilities to develop the scope of training needed. Maintenance and Repairs The system will need maintenance and repairs from time to time. We propose the following scope of services: + Provide assistance as needed for troubleshooting including analyzing data in advance of site visits to prepare a troubleshooting checklist and accompanying MEA personnel to the site for system checkout and repair. + Coordinate with the system supplier SSI and manufacturers for warranty service and repairs. At present the base station is using D&L’s portable zip drive for backup of its disk drive. We will purchase and install a backup system for the base station. — “Proofing the System” During the winter, field observation of the line’s behavior and its correlation with the instruments’ readings will be needed in order to provide the dispatchers with guidelines for operating the line. We propose the following scope of services: NOV @6 °97 16:55 FR DRYDEN & LARUE 987 S22 2534 TO 2693844 P.@3 Matanuska Electric Assn., Ine. November 6, 1997 Mr. John Kennedy Page 2 + Prepare written guidelines for data to be collected and reported during field observations with a form to be filled out for each trip. + Assist with line patrols by helicopter and snow machine to make the observations needed for correlation of instrument readings to field conditions. ¢ Periodically observe the base station operation and review recent data. + Assist with preparation of operational guidelines based on the field observations. We understand that helicopter and snow machine or snow cat transportation will be furnished and that generally an MEA representative will accompany us during trips for field verification. How soon firm operational guidelines based on field proofing can be developed will depend a great deal upon how many heavy snow loading incidents occur this winter and how successful we are in observing them, Budget We understand that the IOC has established a budget of $56,000 for the 1998 fiscal year which began July 1, 1997. Our billings for services under this budget through the end of October are $42,143.31 leaving a remaining budget of 13,856.49. The time and effort that will be needed for proofing and maintenance will depend on the weather and the equipment reliability. At this point it doesn’t look like the budget remaining will get us through the winter. We will bill our services on a time and materials basis in accordance with the attached fee schedule. We look forward to seeing how the system operates. Thank you for the opportunity to make this proposal. DRYDEN & LaRUE, INC. Alan B. Peabody, P.E. Enclosures ee: Stan Sieczkowski NOV @6 *9? 16:55 FR DRYDEN & LARUE 987 S22 2534 TO 2693844 P.@4 DRYDEN & LaRUE, INC. FEE SCHEDULE January 1, 1997 PRINCIPAL, « geen eosnsene vee ABE BHHASAE SHE BE: $110.00/hour PROJECT MANAGER . ...........22-.20000005 $100.00/hour PROJECT ENGINEER. ..........0. 000 e eee renee $ 97.00/hour SENIOR ENGINEER . ...... @PTNG EG TTD PPSSs aE 3 92.00/hour SENIOR FIELD ENGINEER .............---00- $ 85.00/hour STAFF ENGINEER wae ness ote eee eee enews ae $ 72.00/hour FIELD ENGINEER ............-0--00002 00s $ 62.00/hour AUTOCAD DESIGNER/DRAFTSMAN (with computer)... ... $ 62.00/hour INSPECTOR ..... 2.2.0... cece eee ees $ 52.00/hour WORD PROCESSOR ......... 0020 e eee ene $ 42.00/hour CLERICAL & EXPEDITOR .................--. $ 37.00/hour SUPPLIES Blueline Prints ........ os Sew ee Weeks wees ae $1.50 each Drafting Adhesive 006s sc6 esse cn eet ees es ous $1.50 each Film o .. ee e e t ees $4.00 each Laminating Sheets84 x11 .......-.-2-.------- $0.75 each Laminating Sheets 11x17) 2.2.22. ee ee eee eee $1.00 each Mylar$ cc esti cnt nee eed ee wee we $5.00 each Mileage © 0... eee ee ee $0.35/mile Paintlet PHN 6 oc acsc tie es Des HTH HEHEHE OES $0.75 each Plotter Bond «1... eee ee eee eee $3.00 each Velie, 066 6 F366 R HES EERE SHH DGD HSH a SD . $3.00 each Rerox Copies cis cee e eee eee eee eee trees « 30,10 each Note: (1) @) (3) (4) (5) The Fee Schedule is subject to review on January 1 each year. Expenses incurred as a necessary part of the engineering services provided under this contract will be billed at actual cost. These expenses include airfare, subsistence, repro-- duction, telephone tolls and other items billed through Dryden & LaRue. Subcontractor services contracted by Dryden & LaRue at the request of the Owner will be billed at actual cost times 1.10 multiplier (10%). These services include subcontracted engineering, surveying and other as directed by the Owner. Unusual overtime requirements requested by the Owner may be billed at ‘straight time’ times 1.25 multiplier (25%). Interest at the rate of 1.5 percent per month may be charged on all unpaid accounts after 30 days. xk TOTAL PAGE.84 *« Matanuska Electric Association, Inc. { uj ca P.O. Box 2929 yuausdojenad 1eH¥5P Palmer, Alaska 99645-2929 7 930 Telephone: (907) 745-3231 g66l ¥- Yo Fax: (907) 745-9328 December 2, 1998 Mr. Stan Sieczkowski Alaska Energy Authority 480 West Tudor Anchorage, AK 99503 Dear Mr. Sieczkowski: This letter is to memorialize the phone conversation we had on November 25, 1998, and subsequent developments. During your call to me two primary items were discussed. You stated the IOC had given its approval of MEA’s re-clearing contract proposal. MEA has proceeded with soliciting bids. Our schedule is to open bids on December 23". After the bids have been opened, I will contact you with the results. It is my understanding the IOC may wish to consider a budget revision if the bids exceed the amount budgeted. On the matter of the snow load monitoring and battery replacement, you stated Dryden and LaRue’s proposal for technical support was approved by the IOC, as was the previously budgeted amount of $20,000 for the battery replacement. We discussed this work and I agreed to provide you with additional information and documentation on similar work that was done last year. If this documentation withstands the scrutiny of the IOC, approval! will be given by the IOC to pay all appropriate expenses related to the battery replacement and the punch list items identified in Dryden & LaRue’s proposal. We will be facing some different conditions this year than when the batteries were replaced last year, such as colder weather, fewer daylight hours, and snow. These conditions will likely result in more time required to complete the work. Hopefully we can discuss this further on December 4" at AIDA’s office. Sincerely, S2elr Robert C. Drake Operations Manager NOV @4 °97 @8:32 FR DRYDEN & LARUE 9a? S22 2534 TO 26qs044 Rez ‘3 PRCA TSEC a ARETE chal a) . : DATE: 02/06/97 SHIP TO: PO Box 71249 & 758 ILLINOIS 6T PHONE: FAIRBANKS, AK 99707-1249 FAX: FAIRBANKS AK 99701 (907) 451-5665 (907) 451-5681 CONFIRMING: nie UY DATES ef DRYDEN & LARUE INC Po Box 111008 pat IMPORTANT: PURCHASE ORDER NUMBER MUST ANCHORAGE, AK 99511-1008 BE INDICATED ON EACH SHIPPING CONTAINER, 6 PACKING LIST, INVOICE, OR CORRESPONDENCE, APR 23 1997 PACKING LIST MUST ACCOMPANY EACH SHIPMENT. ATTENTION: DELBERT LARUE fe RTT TT SHIPPING VIA; VENDOR ACCT.# PHONE: (907) 349-6653 TERMS: NET 30 FAX: (907) 522-2534 FOB: 1 -l DUEDATE: 08/01/97 QUANTITY usu DESCRIPTION UNIT PRICE TOTAL PRICE THIS IS REVISION #003 TO GVEA PURCHASE ORDER #74945 AND SUPERCEDES THE ORIGINAL PURCHASE ORDER AND ANY REVISION (S) ISSUED TO DATE. QUESTIONS CONCERNING THIS PURCHASE ORDER, AS REVISED, SHOULD BE DIRECTED TO ROBERT D. FATH, GVEA PURCHASING AGENT, BY TELEPHONE AT (907)~451-5620 OR BY FAX AT (907)-451~5661. THE PURPOSE OF THIS REVISION IS TO ADD LINE ITEM #4 (TEHNICAL SUPPORT)- ALL OTHER TERMS AND CONDITIONS REMAIN THE SAME. 1 1 ror DESIGN SERVICES _ 44000.00 44000.00 DESIGN SUPPORT FOR THE NORTHERN INTERTIE PROJECT. 2 1 Lor DESIGN SERVICES 88000.00 88000.00 AMEND DESIGN AND ADMINISTRATION SERVICES FOR THE ANCHORAGE-FAIRBANKS INTERTIE BY ADDING ADDITIONAL FUNDING FOR INCREASED SCOPE PER DRYDEN & LARUE LETTER DATED 15 OCTOBER 1996, 3 | ce DESIGN WORK 28000.00 28000.00 ADDITIONAL FUNDING FOR WORK RELATED TO DESIGN AND ADMINISTRATION SERVICES FOR \ INSTRUCTIONS TO VENDOR l GOLDEN VALLEY ELECTRIC ASSOC., INC. 1. This purchase order subject to terms and conditions noled on face and reverse ide. 7 2 Purchase order na. must appear on material and documents. ‘An Equal Opportunity Employer 2. Packing last required with each shipment, Casa nee 4 Invoice by item number. Duplicate invoice required. Og. ELL d— 5. No substiiutions may be made without prior appreval of Goiden Valley Electric Association, Inc. 6. Direct all inquires to Purchasing Department at above address. /oonomas K. Hartnell, Purchasing Agent 7, Acknowledgement and ship date required if not shipped within 5 days of receipt of this purchase: order. 6, Payment tema are Net 30 days unless otherwine indicaled. Vendor Copy NOV @4 ’97 @8:33 FR DRYDEN & LARUE 987 522 2534 TO 2693044 F.63 DATE: 02/06/97 ~ SHIP TO: « oe y 758 ILLINOIS stv PHONE. FAIRBANKS, AK 99707-1249. -- FAX-FATRBANKS AK 99701 (907) 451-5665 (907) 451-5681 CONFIRMING: TF to . UATE: 7 MZ, DRYDEN & LARUE INC PO BOX 111008 IMPORTANT: PURCHASE ORDER NUMBER MUST ANCHORAGE, AK 99511-1008 BE INDICATED ON EAGH SHIPPING CONTAINER, PACKING LIST, INVOICE, OR CORRESPONDENCE. PACKING LIST MUST ACCOMPANY EACH SHIPMENT. ATTENTION: DELBERT LARUE il SHIPPING VIA: VENDOR ACCT.# PHONE: (907) 349-6653 TERMS: NET 30 FAX (907) 522-2534 FOB: L _] DUEDATE: 08/01/97 THE ANCHORAGE - FAIRBANKS INTERTIE. TECHNICAL SUPPORT 60000.00 60000.00 PROVIDE TECHNICAL SUPPORT FOR OPERATIONS AND MAINTENANCE FOR THE SF INTERTIE SNOWLOAD MONITORING SYSTEM PER PROPOSAL DATED 15 OCTOBER 1996, 220000.00 a EU eS eae) ETT GOLDEN VALLEY ELECTRIC ASSOC., INC. 2. Purchase order na. must appsar on material and documents. An Equal Opportunity Employer 2 Packing fist required with each shipment. 4 Invoice by item number. Duplicate invoice required. (pets ste 53. No substitutions may be made without prior approval of Golden Valley Electric Association. inc. 6. Direct afl inquires to Purchasing Department at above address, iomas K. nell, Purc asing Agent 7, Acknowledgement and ship dale required if not ahipped within 6 days of receipt of thie purchase order. THIS PURCHASE ORDER IS EXEMPT FROM NORTH STAR BOROUGH AND CITY OF & Payment terms are Net 30 days uniese olherwine indicated. FAIRBANKS SALES TAX UNDER ALASKA STATUTE’S SECTION 10.25.540 Vendor Copy 4k TOTAL PAGE.@3 *« (am United States Forest Alaska Region Tongass National Forest ; a Department of Service Petersburg Ranger District Agriculture P. O. Box 1328 Petersburg, AK 99833 File Code: 2720 Date: March 1, 1999 Alaska Energy Authority |W {ec ) | Stan Sieczkowski | U) 480 W. Tudor Road a Anchorage, AK 99503 —— Alaska Industrial Devel Dear Mr. Sieczkowski: and Export Authority The Forest Service is required to regularly inspect all sites under special use permit to ensure that the terms of the authorization are being met. The frequency of inspections are dependent upon the type of use, conditions noted during the last inspection, and the availability of Forest Service personnel and funding. This coming field season we are planning to inspect the portion of Alaska Energy Authority’s powerline located on National Forest System lands on Mitkof Island. If you have any questions, or if representatives of Alaska Energy Authority are interested in participating in the upcoming on-site inspection, please contact Russ Beers at (907) 772-3871. Sincerely, ht. PATRICIA A. G AM District Ranger 2720_ak_energy_authority_pre_insp_ltr_990301 a rdb | + -~ Caring for the Land and Serving People Printed on Recycled Paper ue ——$_— Try HECEINE 6V APR 18 1997 GOLDEN VALLEY ELECTRIC ASSOCIATION ING. Box 71249, Fairbanks, Alaska o4/89KAadgapatrial evelopment and Export Authority April 11, 1997 Stan Sieczkowski Alaska Industrial Development and Export Authority 480 West Tudor Anchorage, AK 99503-6690 Subject: Alaska Intertie Usage Report Dear Stan: GVEA, THE ALASKA INTERTIE NORTHERN CONTROL AREA OPERATOR, SUBMITS THE FOLLOWING: Per article 10.1.4.6 of the Alaska Intertie Agreement, we are submitting the Alaska Intertie Usage Report for fiscal year 1997 through the month of March 1997. ~Keau Bradley Ev ee System Dispatch Manager Attachment cc: John Cooley CEA Tim McConnell AMLP Sam Matthews AEGT Dave Gerdes FMUS ALASKA INTERTIE SCHEDULED ENERGY REPORT (MWh) 4/11/97 3:35 PM INTERTIE AMLP CEA CEA CEA AEGT AEGT BL INTERTIE GVEA GVEA FMUS FMUS FY97 MIDPOINT to to to to to to to MIDPOINT to to to to MONTHLY MONTH AMLP to GVEA FMUS GVEA FMUS AEGT GVEA FMUS GVEA GVEA to AMLP CEA AEGT AMLP CEA TOTALS JULY 0 0 30478 0 803 0 0 0 4 29 0 0 0 14 AUGUST 1075 0 34580 0 812 0 0 0 0 0 0 0 0 vv+87 SEPTEMBER 3581 0 34189 0 786 0 0 0 0 0 0 0 0 38556 OCTOBER 877 0 13448 0 764 0 0 0 0 5 0 0 0 15094 NOVEMBER 587 0 11528 0 1094 0 0 0 0 0 0 0 0 13209 DECEMBER 1535 0 28431 0 1204 0 0 0 0 0 0 0 0 31170 JANUARY 10980 0 24269 0 1230 0 0 0 0 19 0 0 0 36498 FEBRUARY 11838 0 10538 0 936 0 0 0 0 0 0 0 0 23312 MARCH 2622 0 32677 0 955 0 0 0 0 0 0 0 0 36254 APRIL 0 MAY 0 JUNE 0 = ee - = — = a= aa = = YEAR TOTAL 33095 0 220138 0 8584 0 0 0 4 53 0 0 0 261874 ALASKA INTERTIE SCHEDULED RESERVES REPORT (MWH) INTERTIE AMLP CEA CEA CEA AEGT AEGT BL INTERTIE GVEA GVEA FMUS FMUS FY97 MIDPOINT to to to to to to to MIDPOINT to to to to MON f MONTH AMLP to GVEA FMUS GVEA FMUS AEGT GVEA FMUS GVEA GVEA to AMLP CEA AEGT AMLP CEA TOTALS JULY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AUGUST 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SEPTEMBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 OCTOBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NOVEMBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DECEMBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 JANUARY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FEBRUARY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MARCH 0 0 0 0 0 0 0 0 0 0 0 0 0 0 APRIL 0 MAY 0 JUNE 0 a a 7 YEAR TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 t aaska@enrie SCHEDULED ENERGY recep uwe) 4/11/97 3:34 PM GVEA FMUS CEA AMLP AEGT TOTAL FY97 RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS MONTH 30478 0 29 4 803 31314 JULY 35655 0 0 0 812 36467 AUGUST 37770 0 0 0 786 38556 SEPTEMBER 14325 0 5 0 764 15094 OCTOBER 12115 0 0 0 1094 13209 NOVEMBER 29966 0 0 0 1204 31170 DECEMBER 35249 0 19 0 1230 36498 JANUARY 22376 0 0 0 936 23312 FEBRUARY 35299 0 0 0 955 36254 MARCH 0 APRIL 0 MAY 0 JUNE 253233 0 53 4 8584 261874 . YEAR TOTAL ALASKA INTERTIE SCHEDULED RESERVES REPORT (MWh) GVEA FMUS CEA AMLP. AEGT TOTAL FY97 RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS MONTH 0 0 0 0 0 0 JULY 0 0 0 0 0 0 AUGUST 0 0 0 0 0 0 SEPTEMBER 0 0 0 0 0 0 OCTOBER 0 0 0 0 0 0 NOVEMBER 0 0 0 0 0 0 DECEMBER 0 0 0 0 0 0 JANUARY. ) 0 0 0 0 0 FEBRUARY 0 ) 0 0 0 0 MARCH 0 APRIL 0 MAY 0 JUNE 0 0 0 0 0 0 YEAR TOTAL GOLDEN VALLEY ELECTRIC ASSOCIATION INC. Box 71249, Fairbanks, Alaska 99707-1249, Phone 907-452-1151 February 27, 1997 Stan Sieczkowski Alaska Industrial Development and Export Authority 480 West Tudor Anchorage AK 99503-6690 Subject: GVEA FY98 Alaska Intertie Operating Budget Submittal Attached is GVEA’s FY98 budget submittal for: 1. NORTHERN HALF TRANSMISSION LINE MAINTENANCE AND WORK PLAN 2: SUBSTATION PREVENTIVE MAINTENANCE PLAN FOR HEALY, GOLD HILL, AND CANTWELL SUBSTATIONS 1. (all. Marvin Riddle Manager of System Operations cc: Brad Evans SOUTHERN UTILITY PARTICIPANTS (MW) AMLEP CEA AEG&T HEA MEA TOTAL NORTHERN UTILITY PARTICIPANTS (MW) FMUS GVEA TOTAL MITCR DETERMINATION AEG&T AMLE&P CEA FMUS GVEA AFMITR98 Propasal 22797 31. 27. 40. 20. 79. 724% 910% 366% 616% 384% 148.00 & oO oo 30 MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS 30. 109. 95-96 -00 -50 50 90 (MITCR) DETERMINATION FOR FY 1998 ANNUAL SYSTEM DEMAND 149.00 149. 220.70 215. 169. 533. 145. 96-97 3 YR AVE. 00 MW 50 MW 36 MW 86 MW \< -90 MW 134.10 115. 13 MW 03 MW FY 98 22. 19. 28. 14. 55. 140. 21 MW 54 MW 26 MW 43 MW 57 MW 00 MW Page 1 APPROVED PROPOSED 3/1/97 UNITS FY 98 FY 98 USEAGE KWH 224,200 BUDGET $ $1,309,410 MITCR KW 140,000 140, ENERGY $.000/KWH 4.88E03 ENERGY 0.XXX cents 0.488 cents CAPACITY S$IKW $0.00 $1.54 3/14/97 MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS (MITCR) DETERMINATION FOR FY 1998 ANNUAL SYSTEM DEMAND APPROVED PROPOSED 9/26/96 9/25/96 FY 97 REV. FY 97 REV. FY 96 FY 95 287,000 300,000 300,000 342,000,000 356,640,000 $1,142,662 $1,142, 662 $980,662 $1,272,704 $1,068,893 140,000 140,000 140,000 140,000 140,000 3.32E03 3.18E03 2.73E03 3.LIE-33 2.50E-03 0.332 cents 0.318 cents 0.273 cents -311 cents -25 cents $1.35 $1.35 $1.16 $1.50 $1.26 AFMITR98 Propasal 22797 Page 2 3/14/97 ALASKA INTERTIE FISCAL YEAR 1998 ENERGY PROJECTIONS FMUS GVEA AEG&T CEA ML&P MON TOTAL MONTH MWH MWH MWH MWH (in gvea) Jul-97 0 39,300 800 0 0 40,100 Aug-97 0 41,700 800 0 0 42,500 Sep-95 0 30,000 800 0 0 30,800 Oct-97 0 9,800 900 0 0 10,700 Nov-95 0 4,300 1000 0 o| 5,300 Dec-97 0 5,600 1100 0 i) 6,700 Jan-98 0 5,800 1100 0 0] 6,900 Feb-98 0 10,900 900 0 0 11,800 Mar-98 0 15,300 900 0 0 16,200 Apr-98 0 9,100 800 ) 0 9,900 May-98 0 12,200 800 0 0 13,000 Jun-98 0 29,500 800 0 0 30,300 FY 98 TOTAL 0 213,500 10,700 0 0 224,200 FY 97 57,800 266,765 10,700 TOTAL INTERTIE PROJECTED ENERGY USAGE FOR FY 98 224,200|MWH PROJECTED ENERGY USE APPROVED BY BUDGET COMMITTEE MWH Alaska Intertie FY 98 Usage Projections Proposal 22597 3/14/97 ALASKA INTERTIE FISCAL YEAR 1998 ENERGY PROJECTIONS FMUS GVEA AEG&T | FMUS | GVEA | AEG&T |ML&P_ CEA CASH FLOW ENERGY | CAPACITY TOTALS $0 $191,784 $3,904 2 430: $0 $203,496 $3,904 $0 $146,400 $3,904 $0 $47,824 $4,392 $0 $20,984 $4,880 $0 $27,328 $5,368 $0 $28,304 $5,368 $0 $53,192 $4,392 $0 $74,664 $4,392 | $0 $44,408 $3,904 $0 $59,536 $3,904 $0 $143,960 $3,904 | $0 $1,041,880 $52,216 $22,222 $85,578 $34,203 $30,092 $43,520 TOTAL REVENUE FROM APPROVED MWH $1,309,711 O&M BUDGET FY 98 $1,309,410 DIFFERENCE $301 Alaska Intertie FY 98 Usage Projections Proposal 22597 2 3/14/97 CHUGACH, ELECTRIC ASSOCIATION, INC. Cian kectric ystriat- Development Alaska In February 2, 1996 i eeead Export Authority Mr. Stan Sciezkowski AIDEA 480 W. Tudor Rd. Anchorage, AK 99503 Dear Mr. Sciezkowski: Subject: Salvage of Replaced Teeland Substation Westinghouse DWE Circuit Breaker The existing Teeland Substation SVC circuit breaker is to be replaced within the next two months. Your direction is requested as to the breaker's disposition. It is a Westinghouse 169DWE4O breaker and has been identified in a Westinghouse April 19, 1995 Safety Advisory as a hazard to personnel and equipment. On July 3, 1995, ABB sent us a fax offering to purchase the tapered bushings (three total) for $820 each, provided they were sent to Greensburg, Pennsylvania and passed their inspection. On January 31, 1996, Mr. Joe Brunson of ABB stated they currently had no need of the bushings; consequently, the breaker has no apparent value. If you approve, Chugach Electric will handle the disposal of the breaker. Please notify me of your wishes with regard to disposal of the breaker. Sincerely, 924. sxe Paul R. Risse Manager, Substation Operations PRR/cak aidea.pr 5601 Minnesota Drive ¢ P.O. Box 196300 « Anchorage, Alaska 99519-6300 Phone 907-563-7494 ¢ FAX 907-562-0027 98/15/95 TUE 15:14 FAX 907 762 7663 CEA OPERATIONS oor . CHUGACE _:LECTRIC hugach Vs ASSOCIATION, INC Civic . FAX bate Ave 5, 1975 To: STAN SIECZAOWSK Ys AIDE A From: Asypey UDpELHOVEM Phone: /-9O07- 7O2- 76/2 1-907-762-7663 Comments: For assistance, please cail Chugach Electric Association’s Operations Dept. at 1-907-762-7685. Type of Fax Machine: Canon Laser Class 7000 rms/fax/cak 08/15/95 TUE 15:14 FAX 907 762 7663 CEA OPERATIONS (Hoo2 Chugach Electric Association Anchorage, Alaska August 9, 1995 To: IOC Maintenance Subcommittee Members From: Ashley Udelhoven, Maintenance & Test Engineer Subject: Teeland Breaker 538 Westinghouse Type 169DWE40 A safety advisory issued by Westinghouse Electric on April 19, 1995 has delayed Chugach's (CEA) planned maintenance activities at Teeland Substation for Breaker $38 and the 230/138/13.8-kV SVS transformer. The purpose of this letter is provide an update on events resulting in the delay, prior to the upcoming subcommittee meeting on August 16 , 1995. The Intertie Maintenance Subcommittee met on April 4, 1995 to discuss a variety of Intertie issues. At that time, major maintenance was scheduled to take place June 12 - 29, 1995 for the breaker and transformer mentioned above. This work was to be completed by CEA as part of its maintenance contract with the State of Alaska. Joe Killian of Golden Valley Electric (GVEA) and I began coordinating the work and scheduling of an ABB service engineer. A day or two before GVEA issued a purchase order for ABB's services, both CEA and GVEA received a safety advisory from Westinghouse for type DWE breakers. The advisory recommended inspection and replacement for all six bushing assemblies for the Teeland breaker and repair of the internal epoxy pedestal hardware. Although Westinghouse is the breaker OEM, it has since sold its high voltage breaker business and in the advisory designates ABB as a third party source for replacement parts, In early June it was agreed between Brian Hickey, Joe Killian, Stan Sieczkowski and I to delay major maintenance at Teeland. I then telephoned most members of the IOC subcommittee to advise them of the situation. The extensive repairs to breaker 538 preempted major maintenance on the breaker and transformer. Also, replacement parts were unavailable from ABB due to a labor problems at their factory. Since June I have obtained information from Chuck Huntley, ABB representative in Anchorage, for replacement bushing assembly cost and availability. Initial estimates for repair/replacement of the bushings assemblies indicates that a installing a new breaker may be more cost effective and a preferable long term solution. Replacement parts alone exceed $ 17,000, FOB factory. Additional cost information will be available at our next meeting. Issues that need consideration at the meeting are: , A Cost/Benefit comparison of alternatives, repair vs. replacement Rescheduling and budgeting breaker repair/replacement and transformer major maintenance » Other suggestions and alternatives ? If you have any questions please feel free to contact me at 762-7612. Attachments 04/15/95 _ TUE 15:15 FAX 907 762 7663 CEA OPERATIONS _ o. 9 aims Date: W2/95 To: Ashley Utilhovan - Chugach Electric FAX 907-762-7663 ( me a cc: Chuck Huntley - Huntley & Associates FAX 907-276-6632 ps yl a Subject: DWE Breaker Options Per our conversation, ABB is acting as a third party in the replacement of parts for the Westinghouse DWE breakers. Westinghouse has retained all liabilities for the DWE breaker line. ABB recommends that the items outlined in the Westinghouse service advisory for the DWE breaker be followed, y Typical options/scenarios for replacing/repairing the DWE bushings and replacing parts as stated in the Westinghouse service advisory for the DWE breaker. - Send bushings back to ABB Greensburg for refurbishment, lead time is 4 weeks after receipt of an order. Concurrently, install epoxy pedestal hardware oO and replace required parts in the lever box at utility site. This option requires a EWE 4 week outage. L q3 Install a spare breaker. Take the DWE out of service and replace parts per the \W jo? service advisory either at utility shop or ship the breaker to ABB Greensburg ore* for repairs. The ABB Greensburg option is approximately $21K for the 121kV breakers and $31K for the 161 kV breakers, plus shipping costs. After the repairs have been completed, the DWE can be used a spare breaker or can be used to replace other DWE breakers in need of repair. Please note that at this time ABB can only offer to refurbish the existing bushings. As of 6/1/95 our primary porcelain supplier Industrial Ceramics Inc., located in Derry, PA, announced that they would be closing their facilities. The Plant has been on strike since the first quarter of 1995, which is the reason why The ABB Breaker Parts and Service Group has been having difficulties meeting requirements for DWE porcelain assemblies and DWE flange replacements. As of this writing we have identified a new source for DWE flange replacements only. We are continuing in our efforts to identify a supplier for the total DWE porcelain assemblies which is the porcelain/flange combination, We are accepting orders for DWE flange replacements only at this time. We have issued purchase orders to our new vendor to purchase the fixtures required to refurbish and test the DWE porcelain/flange combination. The fixtures are scheduled to arrive mid June and set up and test runs will be performed efter that date. Standard lead times will be four weeks after receipt of an order. We foresee the first production DWE flange replacements being shipped from our few vendors Incation by 7/3 1/95. Thank you for patience and support in this critical DWE issue. If you have any questions or comments please call me in Greensburg at 412-838-7263. Regards, Joe Durante ABB Breaker Parts and Service 08/15/95 TUE 15:15 FAX 907 762 7663 CEA OPERATIONS Boos APR- 6-95 THU 14:26 ABB PO'TR T&D COMPANY FAX NO. 4128°°7171 P10 Ly Note: Most of the items listed above are kept in stock or can be procured within a 2-4 waek time frame (e.g. Lever, Pin and Roller), Based upon the customer returning the porcelain assemblies to ABB, the leadtime will average 4 - 6 weaks from recelpt of porcelain assembiles at ABB. Porcelain Assemblias Qty Req'd = Atty Req'd 121/145 kV 145kV, 50kA Price Description 20-40kA All 169kV each Leadtime 121/145 kV Pore Assy - New (# 1D03200G01) 3 $6480 24 weeks 121/146 kV Porc Assy - Refurbished 3 $4130 See Note 121/145 kV Flange Replacement Only 3 $2704 4-6 weoks 121/145 kV Credit - New Pore Assy Purchase (See Note) $1400 See Note 121/145 kV Credit - Refurbished Porc Assy Purchase (See Note) § 700 See Note 161 kV Porc Assy - New (# 1003200GQ2) 6 $8222 24 weeks . 161 kV Pore Assy - Refurbished 6 $4850 See Note r 161 kV Flange Replacement Only 6 $2704 4-6 weeks 161.le-Credit - New Porc Assy Purchase (See Note) $ 1640 See Note 161 kV Credit - Refurbished Pore Assy Purchase (See Note) $ B20 See Note Notes; There is a very limited supply of new porcelain assemblies available at present. Porcelain assemblies have not been ordered prior to the advisory issuance due to the high cost of the porcelain. it is presumed that if a utility must purchase new porcelain assemblies with the leadtimes listed, then the option of a new breaker becomes more valid and ABB can not afford to keep high quantities of these porcelain assemblies in stock. In an attempt to offset some of the cost If new porcelain assemblies are purchased, ABB is offering @ credit for re-usable**“ porcelain assemblias that the customer returns. Please note this credit Is only offered for return quantities equal to or lower than the quantity of new porcelain assemblies purchased and will be offered on a case by case basis. Any credits for retired breaker porcelain assemblies will be negotiated on an individual basis. Refurbished porcelain assemblies will only be available if returns are made from new bushing purchase credits or if utilltles retire a breaker and are willing to sell ABB the porcelain assemblies from the retired breaker, None are available at present. ABB will offer = credit similar to the new bushing credit for re-usable*** porcelain assemblies that the customer returns. Please note this credit is only offered for return quantities equal to or lower than the quantity of refurbished porcelain assemblies purchased and will be offered on a case by case basis. ***Reusable shall be defined as free of any damage including, but not limited to, chips, and or cracks. Porcelain assemblies must also pass the ABB hydrostatic test In order to ba considered reusable. ABS reserves the right to pass/fail any porcelain assembly sent back for purchase credit. RMR instructions have been sent to the fiald by Diane Towzey. Any questions regarding the return af porcelain assemblies should be directed to Diane at 412-864-7690. Please note that any credits issued will be done after the porcelain assembly has been returned and 08/15/95 TUE 15:16 FAX 907 762 7663 CEA OPERATIONS APR- 6-95 THU 14:26 ABB PO ‘TAD COMPANY FAX NO, 41292__.71 P,09 The information given below regarding porcelain assemblies may effect the customer's decision to keep or retire the breaker(s). It is very important for us to know if the customer will be keeping the breaker(s) and proceeding with inspection or replacement or retiring the breaker(s). !f your customer decides to retire the breaker(s), please inform Larry Brunson at 412-864-7590 as soon as possible. This will allow us the option to contact the customer for possible purchase of the porcelain assemblies for refurbishment. Infarmation as follows: Field Kits Kit 1 Kit 2 Qty Rea'd = Qty Req'd 121/145 kV 145kV, 50kA Price Kit Part # Description 20-40kA All 169kV per Kit Leadtime §501C63HO1 Lever §492C34H24 Pin 1D03251H11 Roller 70020BG975 Screw (set with Nylok) 5492C46HO1 O-Ring 5492C46HO2 O-Ring 512A406H10 Screw (Filister Head with Nylok) 5492C12HOB Gasket (Int. Top/N.I, Both)* 5492C12HOS9 Gasket (Interrupter Side Bottom) ** §492C12HO4 Gasket {Y Tank Bottom) 52D4859HO3 Rupture Disc 513A454HO5 Seal Gasket (Rupture Disc) 513A454HO6 Compressor Gasket (Rupture Disc) 1657B11HO1 Desiccant Bag 512A196G04 Greose (Beacon #325) 513A209HO1 Grease (Molykote) 512A196H36 Grease (DC-1292) 512A1961421 Loctite (#271 Red) 4041B67M01 Gauge (Open Contact Gauge) Set of Instructions wee 2H 3 ON OWWW AH HK WWOWAwWW NN . 23242220 NNW00 0 ' *Gaskets for Interrupter Side (Top Gasket) and Non-Interrupter Side (Both Top and Bottom Gaskets) Porcelain Assembly **Bottom Gasket for Interrupter Side Porcelain Assembly 5861697G01 Kit 1 1 $2679 See Note 5861897G02 Kit2 . 1 $1037 See Note Kit 1 includes all of the necessary itemsiexcept porcelain assemblies) as listed above to accompliah actions (1), (2), & (3) in the advisory Kit 2 Includes all of the necessary items(except porcelain assemblies) as listed above to accomplish actions (1) & (2). No action is required for Item (3) When ordering the fieid kits, please indicate only the part number for the appropriate kit. All items will be necessary if the actions listed in the advisory are to bo accomplished correctly. Hoos 08/15/95 TUE 15:16 FAX 907 762 7663 CEA OPERATIONS 006 Westinghouse 11 Stanwix Street Electric Corporation Pittsourgn Pennsylvania 16222-1384 April 19, 1995 ASHLEY UDELHOVEN CHUGACH ELECTRIC ASSOCIATION PO BOX 196300 ANCHORAGE, AL 99518 Subject: Bushing Flange Inspection and Recommended Corrective Actions for Westinghouse-Type DWE Power Circuit Breakers IMMEDIATE ATTENTION: DANGER! FAILURE TO FOLLOW THIS SAFETY AD RY COULD RESULT IN DEATH SERIOUS PERSONAL INJURY, AND/OR PROPERTY DAMAGE. It is the purpose of the this advisory to alert users of Westinghouse-type DWE Power Circuit Breakers rated 121, 145, and 169KV of the need to make an immediate visual inspection of the lower bushing flanges of the interrupter side of 121 and 145KV breakers and both lower flanges of breakers rated 145KV, 50KA and 169KV. It has been discovered in some field installations, that the cast aluminum alloy flanges at the bottom of the larger and tapered porcelain weather casing which houses the interrupter on (21/and 145KV breakers or the same weather casing on both sides of 145KV, 50KA and :169KV breakers may not meet metallurgical specifications and are therefore subject to ‘cracking at the thin wall section adjacent to one of the flange mounting bolts. If cracking occurs, the strength of the mechanical attachment of the flange to the weather casing is reduced and it is possible for the pressurized porceiain to eject out of the flange. This has happened in three cases. Ten other flanges are known to have cracked. Fortunately there have been no personnel injuries, although it is clearly recogni t_ the potential exists for damage to substation equipment and injury to personnel or even death. It is recommended that the 121, 145, and 169K V-type DWE breakers be considered as potentially dangerous to personnel and property until the recommended corrective actions are completed. An immediate visual inspection of lower flanges on the specified breakers is recommended to search for cracks. 08/15/95 TUE 15:17 FAX 907 762 7663 CEA OPERATIONS oo7 April 19, 1995 Page 2 In order to make the visual inspection, the breaker must first be de-energized electrically and grounded following local safety procedures. The SF, gas pressure must be reduced to 5 psig while personnel make the visual inspection for cracks in the lower flanges to preclude a bushing ejection from occurring during inspection. After de-energizing and grounding the breaker and reducing the SF, pressure to 5 psig, a careful visual inspection should be made for longitudinal cracks in the thin wall sections of the flange which are recessed for the flange mounting bolts. Refer to Figure 1. All thin wall sections adjacent to the flange mounting bolts are to be inspected. If any cracks are observed, the breaker should remain off-line with SF, pressure at 5 psig until corrective action is completed. If no cracks are found in the specified lower flanges, the breaker may have the ground removed, be re-pressurized, and energized electrically, but still considering it as potentially dangerous until the following three corrective actions are taken. These three corrective actions are recommended to be taken as soon as the specified breakers can reasonably be scheduled for outage. Corrections are: (1) Because of a recognized quality problem in the metallurgy of the lower flanges of the interrupter side tapered bushings of 121 and 145KV and the tapered bushings on both sides of 145KV, SOKA, and 169KV breakers those bushing assemblies should all be replaced in order to eliminate the possibility of future flange cracking and subsequent porcelain ejection with the obvious risk to personnel and property. The porcelain/flange assemblies should be returned to ABB in order to have the marginal flanges removed and replaced with quality flanges, reusing the existing porcelains. ABB Power T&D Company presently supports all named breakers with replacement parts, service, and technical assistance as Westinghouse no longer manufactures high voltage circuit breakers. Inspection at the factory once the flange is removed may reveal that some porcelains shipped prior to 5/31/83 might also need to be replaced. Some pre- 5/31/83 porcelains have been found to not have the sand band fully applied. (The abrasive gripping surface on the lower end of the porcelain that is enclosed by the flange.) There have been several instances reported where a slow SF, gas leak has been determined to be caused by the short sand band allowing minor movement of the porcelain which defeats the gas seal. US/L9/9YD LUB LD:18 FAX YU7T 16Z 1663 CEA UPERATLUNS 008 April 19, 1995 Page 3 (2) (3) Loose hardware has been found in several DWE breakers, one of which failed catastrophically due to the loose hardware. The loose hardware was found at the top and bottom of the internal epoxy insulating pedestal which supports the interrupter. Refer to Figure 1. The loosening of the hardware is more likely in breakers with higher numbers of operations, but there is long term potential for loosening in all DWE breakers and therefore the problem must be corrected to prevent jamming of the contacts and possible failure to close with attendant hazard to personnel and property. Loosened hardware was also found in a breaker that would not be considered as having a high number of operations. Corrective action involves removing the hardware, applying Loctite#271 (red), reassembling hardware with applied Loctite, and torquing to 40 ft-lb. The Loctite may be purchased from local supply houses. Excessive wear has been observed in several 145DWE4O0 breakers in regard to a linkage connecting pin in the lever box. Refer to Figure 1. The wear is more apparent on breakers with a high number of operations, but is also a potential long-term problem for all of the following type DWE breakers, and excessive wear was also noted on some breakers with a moderate number of operations. 121DWE20 145DWE20 121DWE31 145DWE40 121DWE40 Consequences of excessive pin wear are the potential for jamming or the contacts being left in an intermediate position, both conditions possibly resulting in breaker failure with hazard to personnel and property. For breakers subjected to frequent operation, the following corrective action is recommended: © Replace shaft seal lever located inside lever box with heavy-duty lever having approximately 75% contact surface between lever and pin. ¢ Install new more durable pin connecting vertical operating rod to shaft seal lever. Corrective action recommended for breakers operating on an infrequent basis consists of replacing the pin connecting the vertical operating rod to the shaft seal lever with a new more durable pin. VoO/Lo/¥D LUBE 1D:18 FAX 907 76Z 7663 CEA OPERATIONS Boos April 19, 1995 Page 4 There is no recommended corrective action for lever box components on the following type DWE breakers: 121DWES0 169DWE31.5 169DWE20 169DWE40 Heavy duty shaft seal levers and more durable pins were used on these breakers when they were originally manufactured. In summary, an IMMEDIATE visual inspection for cracks in lower flanges of tapered bushings on the interrupter side ee 145KV DWE breakers and the tapered bushings on both sides of 145KV, 50KA, 169KV breakers is urgently recommended. Breakers determined to have cracked flanges should be kept off-line with reduced SF, gas pressure of 5 psig. ALL DWE BREAKERS SHOULD BE CONSIDERED AS POTENTIALLY DANGEROUS UNTIL THREE CORRECTIVE ACTIONS HAVE BEEN TAKEN: (1) Replacement of all lower flanges on the tapered bushings to prevent future cracking and the potential porcelain ejection. (2) Application of Loctite#271 on hardware at the top and bottom of the internal epoxy insulating interrupter support in order to prevent future hardware loosening. (3) Replace shaft seal levers and pins connecting vertical operating rods to shaft seat levers to prevent possible jamming or malfunction in the following DWE breakers: ¢121DWE20 > 145DWE20 ~TZ1DWE31 145DWE40 121DWE40 For assistance in developing a corrective action plan, please contact the ABB Electric Utility Sales Office serving your area, or the local ABB Distributor. A follow-up advisory will be issued by ABB to inform of the availability of the replacement bushing assemblies to permit initiating a rotation program for replacement and also the availability of shaft seal levers and durable linkage pins. The materials will be available for purchase from ABB Power Circuit Breaker Parts and Service. 08/15/95 LUB 15:19 FAX 907 762 7663 CEA OPERATIONS Mo10 April 19, 1995 Page 5 During the interval when the breakers are in service waiting for the three corrective actions to be completed, a significant change in the SF, leak rate should be recognized as an indication that a bushing flange problem has developed and the visual inspection of flanges as outlined at the beginning of this letter should be undertaken. AS STATED PREVIOUSLY, ALL DWE BREAKERS SHOULD BE CONSIDERED AS POTENTIALLY DANGEROUS UNTIL THE THREE CORRECTIVE ACTIONS ARE COMPLETED. Users of SF, DWE breakers should contact your ABB Electric Utility Sales personnel or your local ABB distributor to: 1. Obtain written instructions to assist you with making the corrections. 2. Obtain RMR instructions for the return of bushings and/or breakers to ABB for refurbishment. 3. Obtain pricing and scheduling information for the parts and services to implement the above corrections. If your company has taken any of your DWE breakers out of service and sold them to another company, please forward this letter to that company, or advise the writer of the new owner and their address. Your help in assisting us reach all present users with the above information would be greatly appreciated. Attached is a list of the DWE breaker(s) that our records show to be sold and delivered to you. This advisory consists of seven pages. If you do not receive all of the pages, please contact the undersigned. Yours truly, Cérporate Customer Service Discontinued/Divested Products Attachments: Figure | and list of DWE breakers sold to you. cc; Larry Brunson - ABB Power T&D Company, Inc. Foster Plaza 5 651 Holiday Drive Pgh., PA 15220-2740 08/15/95 TUE 15:19 FAX 907 762 7663 THIN WALL SECTIONS IN THE RECESSES FOR THE FLANGE MOUNTING BOLTS VISUALLY INSPECT THESE \ CEA OPERATIONS DISK @o11 LOCTITE *211 TO BE APALIED TO MOUNTING HARDWARE AT JOP AND BOTTOM OF THAIS EPORKY INSULATING PEDESTAL |e || R/ LINKAGES CONNECTING PIN IN THIS LEVER BOX FIG, 4 BREAKERS SHIPPED $.0.% G.0.# 6671038 = PO15105 651099 = PO15105 65Y1037 =PO15105 DELIVERED B44 840404 840404 TYPE 169DWE4O 16SDWE40 TtESDWE4O QTY COMPANY RAME 4 1 1 ALASKA POWER AUTHORITY ALASKA POWER AUTHORITY ALASKA POWER AUTHORITY STREET AODRESS 334 W STH AVENUE 334 W STH AVENUE 334 W STH AVENUE city ANCHORAGE ANCHORAGE ANCHORAGE STATE AK AK AK ZIP CODE 99501 99501 99501 PRESENT USER COMPANY NAME UNKNOWN a CHUGACH £1. ASS.:[EALAND SUBSTATION} GOLDEN VALLEY EL. ASS.-HEALY SUBSTATION €992 Z9L L06 XVd OZ:¢T ANL ¢evst/so SNOILVYddO Vado zt0oR He, . " Ke Me WE SN oy Municipalty of Anchorage Municipal Light & Power seu ayer 1200 East First Avenue 18, 1997 Anchorage, Alaska 99501-1685 Telephone: (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of June 1997. Sincerely, Joe Soa €ting Chief Power Dispatcher JS/pjc Attachment cc: H. Nikkels, ML&P Doug Hall, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA c\t-pattylocwo-opitting. Energy into Anchorage for Over 60 years 15-Jul-97 MONTH JULY AUGUST SEPTEMBER OCTOBER 3MBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD MONTH JULY AUGUST SEPTEMBER OCTOBER ‘MBER ‘MBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ENERGY $ YTD . ALASKA INTERTIE USAGE REPORT FY 97 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA 0 1075 3581 877 587 1535 10980 11838 2622 5770 720 755 40340 MLP DELIVERIES CEA DELIVERIES BL DELIVERIES 0 1075 3581 877 587 1535 10980 11838 2622 5770 720 755 40340 ecco oO oO OC OO 31281 35392 34975 14212 12622 29635 25499 11474 33632 42965 34861 22920 329468 30478 34580 34189 13448 11528 28431 24269 10538 32677 41875 34009 22222 318244 eco eo oo Oo 803 812 786 764 1094 1204 © ec 0 0 Oo OO 1230 ° 936 955 1090 852 698 ooo oo 11224 ooo fo oC OO oO Oo GVEA DELIVERIES FMUS DELIVERIES 33 0 ° 5 0 19 23 105 185 oo 0 oO oO OO Oo ooo ° eco oo OO CO GVEA RECEIPTS 30478 35655 37770 14325 12115 29966 35249 22376 35299 47645 34729 22977 358584 $978,934.32 29 ooo oo oO oO Oo 0 0 0 oO coco o ooo FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS 0 coo oo ooo o $0.00 29 181 $494.13 a ) $10.92 803 812 786 764 1094 1204 1230 936 955 1090 852 698 11224 B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT coo oO oOo oO ooo °o LINE TOTAL 31314 36467 38556 15094 13209 31170 36498 23312 36254 48758 35686 23675 369993 $30,641.52 $1,010, 080.89 15-Jul-97 MONTH JULY AUGUST SEPTEMBER OCTOBER /EMBER UECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL MONTH JULY AUGUST SEPTEMBER OCTOBER ‘EMBER ‘EMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL ALASKA INTERITE USAGE REPORT FY 97 SCHEDULED RESERVE TRANSFERS AT THE MIDPOINT IN MWHs. MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS AEGT TO GVEA AEGT TO FMUS GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT 0 ecocooe OOO OC Oe 0 eoooe Oe OOO Ot 0 ecco oe OOO OCC CO 0 coo Oo eoC OOO OCC Ot 0 coo oOo OOO OCC Ot 0 eoco oe OOO OCC Oe MLP DELIVERIES CEA DELIVERIES AEGT DELIVERIES GVEA DELIVERIES FMUS DELIVERIES 0 eooo eo OOO OOO 0 ecocoo ooo OCC Oe 0 SseoooeoO OOO OOO 0 ooo o OOOO OOO ecocoo eo oO eC OOO COS 0 coco oe OOOO CO st ecco oO OO OOOO oe 0 eooo eo OOO OCC OS 0 ecooeoeo OOO OCC Oe 0 secooo oO OO OCC Ot Sooo OO OC OOO OC OO Se GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS AEGT RECEIPTS LINE TOTAL 0 coo oO OOO OC OCC St $0.00 0 ecooeo OO OC OOO COS $0.00 9 i $0.00 0 coo oO OOOO OC $0.00 0 ecooeo eo OOOO OC $0.00 ecoccooae oe OO OCC $0.00 GOLDEN VALLEY ELECTRIC ASSOCIATION INC. Box 71249, Fairbanks, Alaska 99707-1249, Phone 907-452-1151 D Aero JUL 14 1997 July 10, 1997 Alaska Industrial Development and Export Authority Stan Sieczkowski Alaska Industrial Development and Export Authority 480 West Tudor Anchorage, AK 99503-6690 Subject: Alaska Intertie Usage Report Dear Stan: GVEA, THE ALASKA INTERTIE NORTHERN CONTROL AREA OPERATOR, SUBMITS THE FOLLOWING: Per article 10.1.4.6 of the Alaska Intertie Agreement, we are submitting the Alaska Intertie Usage Report for fiscal year 1997 through the month of June 1997. Birebeytoors Bradley Evans System Dispatch Manager Attachment cc: John Cooley CEA Tim McConnell AMLP Sam Matthews AEGT Dave Gerdes FMUS ALASKA INTE HE SGHEVDULED ENEHGY HEPOH | (MWH) Holgt 3:55 PM INTERTIE AMLP CEA CEA CEA AEGT AEGT BL INTERTIE GVEA GVEA FMUS FMUS FY97 MIDPOINT to to to to to to to MIDPOINT to to to to MONTHLY MONTH AMLP to GVEA FMUS GVEA FMUS AEGT GVEA FMUS GVEA GVEAto AMLP CEA AEGT AMLP CEA TOTALS JULY 0 0 30478 0 803 0 0 0 4 29 0 0 0 4 AUGUST 1075 0 34580 0 812 0 0 0 0 0 0 0 0 vee? SEPTEMBER 3581 0 34189 0 786 0 0 0 0 0 0 0 0 38556 OCTOBER 877 0 13448 0 764 0 0 0 0 5 0 0 0 15094 NOVEMBER 587 0 11528 0 1094 0 0 0 0 0 0 0 0 13209 DECEMBER 1535 0 28431 0 1204 0 0 0 0 0 0 0 0 31170 JANUARY 10980 0 24269 0 1230 0 0 0 0 19 0 0 0 36498 FEBRUARY 11838 0 10538 0 936 0 0 0 0 0 0 0 0 23312 MARCH 2622 0 32677 0 955 0 0 0 0 0 0 0 0 36254 APRIL. 5770 0 41875 0 1090 0 0 0 0 23 0 0 0 48758 MAY 720 0 34009 0 852 0 0 0 0 105 0 0 0 35686 JUNE 725 0 22222 0 698 0 0 0 0 0 0 0 0 23645 YEAR TOTAL 40310 0 318244 0 11224 0 0 0 4 181 0 0 0 369963 ALASKA INTERTIE SCHEDULED RESERVES REPORT (MWH) INTERTIE AMLP CEA CEA CEA AEGT AEGT BL INTERTIE GVEA GVEA FMUS FMUS. FY97 MIDPOINT to to to to to to to MIDPOINT to to to to MONT MONTH AMLP to GVEA FMUS GVEA FMUS AEGT GVEA FMUS GVEA GVEA to AMLP CEA AEGT AMLP CEA TOTALS JULY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 AUGUST 0 0 0 0 0 0 0 0 0 0 0 0 0 0 SEPTEMBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 OCTOBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 NOVEMBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 DECEMBER 0 0 0 0 0 0 0 0 0 0 0 0 0 0 JANUARY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 FEBRUARY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MARCH 0 0 0 0 0 0 0 0 0 0 0 0 0 0 APRIL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 MAY 0 0 0 0 0 0 0 0 0 0 0 0 0 0 JUNE 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Se fa Bo a YEAR TOTAL 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ALASKA. .... ERTIE SCHEDULED ENERGY RECEIP 15 (MWH) GVEA FMUS CEA AMLP AEGT TOTAL RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS 30478 0 29 4 803 31314 35655 0 0 0 812 36467 37770 0 0 0 786 38556 14325 0 5 0 764 15094 12115 0 0 0 1094 13209 29966 0 0 0 1204 31170 35249 0 19 0 1230 36498 22376 0 0 0 936 23312 35299 0 0 0 955 36254 47645 0 23 0 1090 48758 34729 0 105 0 852 35686 22947 0 0 0 698 23645 358554 0 181 4 11224 369963 ALASKA INTERTIE SCHEDULED RESERVES REPORT (MWH) GVEA FMUS CEA AMLP AEGT TOTAL RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS RECEIPTS 0 0 0 ) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ) 0 0 ) 0 0 0 0 0 0 0 0 0 0 0 0 0 ) 0) 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 ) 0 0 0 0 0 ) 0 0 0 0 0 0 0 0 0 0 7/8/97 3:55 PM FY97 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YEAR TOTAL FY97 MONTH JULY AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YEAR TOTAL Ny ae Municipality of Anchorage Municipal Light & Power Rick Mystrom, Mayor 1200 East First Avenue Anchorage, Alaska 99501-1685 Telephone: (907) 279-7671, Telecopiers: (907) 263-5804, 277-9272 August 12, 1997 Mr. Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the revised Alaska Intertie Usage Report for the current fiscal year through the month of June 1997. Sinc®rely, Doug Hall Chief Power Dispatcher DH/pjc Attachment ce’ H. Nikkels, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA e\-patty 10Cso-oPSEING“ENergy into Anchorage for Over 60 years 11-Aug-97 ALASKA INTERTIE USAGE REPORT FY 97 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHs MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA’ B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT JULY 0 0 30478 0 803 ° 4 29 0 ° 0 0 AUGUST 1075, 0 34580 0 812 O 0 0 0 0 0 0 SEPTEMBER 3581 0 34189 0 786 0 0 0 0 0 oO 0 OCTOBER 877 oO 13448 0 764 0 0 5 0 0 0 0 IMBER 587 0 11528 0 1094 0 0 0 0 0 0 0 DECEMBER 1535 0 28431 0 1204 0 0 0 0 0 ° 0 JANUARY 10980 0 24269 0 1230 0 ° 19 0 0 0 0 FEBRUARY 11838 0 10538 ° 936 ° 0 0 0 0 oO O MARCH 2622 ° 32677 0 955 ° 0 0 0 0 0 0 APRIL 5770 0 41875 0 1090 0 0 23 0 ° ° 0 MAY 720 0 34009 0 852 0 0 105 0 0 0 ° JUNE 725 0 22222 0 698 0 0 0 0 0 0 0 YR TOTAL 40310 0 318244 ° 11224 0 4 181 0 0 0 0 ENERGY $ YTD MONTH MLP DELIVERIES CEA DELIVERIES BL DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS LINE TOTAL JULY 0 31281 0 33 0 30478 oO 29 4 803 31314 AUGUST 1075 35392 0 0 0 35655, 0 0 0 812 36467 SEPTEMBER 3581 34975 ° ° ° 37770 ° ° ° 786 38556 OCTOBER 877 14212 ° 5 0 14325 0 5 0 764 15094 MBER 587 12622 0 ° 0 12115 0 0 ° 1094 13209 ‘MBER 1535 29635 0 0 0 29966 0 0 0 1204 31170 JANUARY 10980 25499 0 19 0 35249 0 19 0 1230 36498 FEBRUARY 11838 11474 0 0 0 22376 0 0 0 936 23312 MARCH 2622 33632 0 O oO 35299 ° 0 O 955 36254 APRIL 5770 42965 0 23 0 47645 0 23 0 1090 48758 MAY 720 34861 0 105 0 34729 0 105 0 852 35686 JUNE . 725 22920 0 0 . 0 22947 0 0 0 698 23645 YR TOTAL 40310 329468 0 185 0 358554 0 181 4 11224 369963 ENERGY $ YTD $978,852.42 $0.00 $494.13 $10.92 $30,641.52 $1,009,998.99 NY ae Municipality of Anchorage Municipal Light & Power Soe ee re 1200 East First Avenue Anchorage, Alaska 99501-1685 Telephone: (907) 279-7611, Telectpiis G0") es Seo August 12, 1997 Rn) .yub LAN ie 14 1997 j yriai Developme niaska WAaUSTES ; Mr. Stan Sieczkowski Aloe ad Export Authority AIDEA 480 West Tudor Road Anchorage, Alaska 99503-6690 Dear Stan: Please find attached the Alaska Intertie Usage Report for the current fiscal year through the month of July 1997. rely, A iain Chief Power Dispatcher DH/pjc Attachment cc: H. Nikkels, ML&P S. Matthews, AEGT B. Evans, GVEA L. Colp, FMUS J. Cooley, CEA J. Hall, MEA L. Day, AEA c\-paeyrocso-uttingeEnergy into Anchorage for Over 60 years 11-Aug-97 ALASKA INTERTIE USAGE REPORT FY 98 SCHEDULED TRANSFERS AT THE MIDPOINT IN MWHS MONTH MLP TO GVEA MLP TO FMUS CEA TO GVEA CEA TO FMUS CEA TO MEA B.LK. TO GVEA GVEA TO MLP GVEA TO CEA GVEA TO AEGT FMUS TO MLP FMUS TO CEA FMUS TO AEGT JULY 2408 0 32838 0 798 0 0 O 0 0 0 0 AUGUST SEPTEMBER OCTOBER NOVEMBER DECEMBER JANUARY FEBRUARY MARCH APRIL MAY JUNE YR TOTAL 2408 ° 32838 0 798 O 0 0 0 0 0 0 ENERGY $ YTD MONTH MLP DELIVERIES CEA DELIVERIES BL DELIVERIES GVEA DELIVERIES FMUS DELIVERIES GVEA RECEIPTS FMUS RECEIPTS CEA RECEIPTS MLP RECEIPTS MEA RECEIPTS LINE TOTAL JULY 2408 33636 ° 0 0 35246 ° 0 0 798 36044 AUGUST ° 0 ° 0 0 0 ° 0 0 0 0 SEPTEMBER 0 0 0 0 0 o 0 0 0 0 0 OCTOBER 0 0 ° ° 0 0 0 0 ° 0 0 NOVEMBER 0 0 ° ° 0 0 0 0 0 0 ° DECEMBER 0 0 ° 0 0 0 0 0 ° 0 0 JANUARY 0 0 ° ° 0 0 0 0 0 0 0 FEBRUARY 0 ° 0 ° 0 0 0 0 0 0 0 MARCH 0 0 ° 0 0 0 ° 0 o 0 0 APRIL 0 0 0 0 0 0 ° 0 0 0 0 MAY o ° ° 0 0 ° 0 0 ° 0 ° JUNE 0 “0 ° ° 0 0 ° 0 o 0 0 YR TOTAL 2408 33636 ° ° 0 35246 0 0 ° 798 36044 ENERGY $ YTD $179,402.14 $0.00 $0.00 $0.00 $4,061.82 $183,463.96 Drvben ¢ LARUE IINc. CONSULTING / ENGINEERS 6436 Homer Drive, Anchorage, AK 99518 Mailing Address: PO. BOX 111008, ANCHORAGE, AK 99511-100 ih (907) 349-6653 © FAX 522-2534 // V & July 14, 1997 or an, Mr. Stan Sieczkowski ALASKA ENERGY AUTHORITY 480 W. Tudor Rd. Anchorage, Alaska 99503 Reference: | Anchorage-Fairbanks Intertie Snow Load Monitoring System Maintenance Activities Quarterly Report Replace page 2 This letter is in regards to the letter which was delivered July 14, 1997 on the above referenced project. Please replace Page 2 from the previous letter with the new page 2 which is enclosed with this letter. Sorry for the inconvenience. DRYDEN & LaRUE, INC. al SS QRBOAKES Dawn M. Stiles Secretary Transmission, Distribution, Substations, System Planning Alaska Energy Authority July 14, 1997 Mr. Stan Sieczkowski Page 2 not responding to calls. The weather station was found to be operating correctly, and the cellular phone worked, so we suspected the modem. We replaced the modem and cellular phone transceiver. We later went to ML&P dispatch to change the phone number in the Base Station database and successfully called the Douglas weather station. We found a bug in the Campbell Scientific data logger software which required that we reset the date in the data logger. The removed modem was sent back to Campbell Scientific, Inc. for repairs. We also explored different routes of wintertime access to all towers using snowmachines, during the first quarter of 1997. This was done to find the most direct routes of winter access to the towers. It included mapping all areas traveled and plotting the selected routes on 1"=1 mile USGS maps. The routes mapped took into account private property, rights-of-way, river crossings and noted any other physical obstructions one may encounter when accessing the towers using a snowmachine. Copies of these maps were sent to GVEA and are currently available at D&L’s office. These maps could be used when maintenance operations are such that using a helicopter would not be as feasible or economical. On March 20, 1997, two D&L personnel explored and mapped routes for the line section from Douglas substation to tower 85 via snowmachine. We also replaced the cellular transceiver in tower 41. Tower 41’s number was a long distance call from Anchorage, the new one was a local number. We also investigated an apparent load cell problem with tower 32, so we checked and tightened all connections from the load cell to the data logger. Later we found that the Base Station was unable to contact these towers from the time we had worked on them. On March 21, 1997, two D&L personnel explored and mapped routes for the line section from tower 85 to tower 119 via snowmachine. We were unable to reach tower 120 from the right-of-way because of a steep hill. The weather station quit answering calls on March 5, 1997 so we again suspected the modem. A new modem was ordered to keep as a backup for future maintenance. We received the new modem, ordered from Campbell Scientific, Inc., and on March 25, 1997 two D&L personnel went to Douglas substation to replace the modem. We were met there by MEA operations engineer Ray Morgan. Correct voltage to the cellular transceiver was verified. We then installed a handset and successfully called our Anchorage office. The weather station was later called successfully from a remote computer three times within a half hour. Correct time on the data logger was set before leaving. There have been no problems contacting Douglas weather station since this visit. We then investigated the communications problems we were having with towers 32 and 41. The individual equipment was all verified to be operating correctly. We noted that the relay controlling power to the cellular phone was not operating at the correct time. We determined that when the station was turned off, the data logger’s internal clock would reset to an incorrect time. This “bug” can be fixed with a software upgrade when the batteries are replaced this fall, or the clock can be reset Houmuer Electric Association, Inc. Corporate Office Central Peninsula Service Center 3977 Lake Street 280 Airport Way Homer, Alaska 99603-7680 Kenai, Alaska 99611-5280 Phone (907) 235-8551 Phone (907) 283-5831 FAX (907) 235-3313 FAX (907) 283-7122 P We (0) E G E \ WY ib \ August 29, 1997 | NU iM sep <3 1997 4 1, trial Developmen sjaska Industri Tl and Export Authority Mr. Stan Sieczkowski AIDEA 480 W. Tudor Rd. Anchorage, AK 99503-6690 Dear Stan: RE: Alaska Intertie Refund for FY97 I have reviewed the proposed refund transmitted by Elaine McCambridge’s letter of August 13, 1997. I have also reviewed the Alaska Intertie Agreement Section 8.4.5 concerning refund of excess revenues over costs. As a result of this review I do not believe this refund is calculated correctly. It is based only on the energy revenues, and excludes demand revenues in the calculation. The correct calculation is as follows: Participant Usage % Refund Billings Due GVEA $1,202,443 88.771 $545,142.94 ML&P $26,917 1.987 $12,202.16 CEA $38,762 2.862 $17,575.53 AEG&T $65,263 4.818 $29,587.32 FMUS $21,154 1.562 $9,592.24 Totals $1,354,539 100.00 $614,099.57 plus minor adjustments for the pennies. It is my understanding that the Budget subcommittee is going to review this before it is finalized. We need to schedule a meeting at an early date. Mr. Stan Sieczkowski August 29, 1997 Page 2 I will look forward to your response. Sincerely yours, HOMER ELECTRIC ASSOCIATION, INC. AC aera S. C. Matthews Major Projects Engineer LREFUND.SCM/js CC: John Cooley CEA Brad Evans GVEA Tim McConnell ML&P Larry Colp FMUS Ray Morgan MEA Don Stead HEA Norm Story HEA United States Fotcer Alaska Region Tonyacss National Forest Department of Service Wrangell Ranger District Agriculture P.O. Box 51 Wrangell, AK 99929 File Code: 2720 Date: August 14, 1997 eh Stan Sieczkowski, Project Manager Alaska Energy Authority AUG z 0 1997 480 West Tudor Alask Anchorage, AK 99503 ska Industrial p evelopment and Export Authority Dear Mr. Sieczkowski: This is in response to your June 9, 1997 request to have machinery cross protected fish streams outside the timing window as spelled out in our Erosion Control and Stream Crossing Measures dated May 1, 1997 and made part of AEA’s Term Special Use Permit. I appreciate your patience in this tardy reply to your request. Specifically, Irby Construction Company desires to cross streams #1 and #2 on Vank Island after August 15th, and streams #1, #2, and #4 through #20 on Mitkof Island after September 15th. We are agreeable to allow a variance to the above-referenced stream crossings, subject to the following conditions: 1.) AEA will notify the Forest Service of the presence of any adult fish seen in the above-referenced streams following the above-referenced dates. Our intent is not to have folks go out of their way looking for fish, but if folks see adult fish activity while near a stream crossing, we would appreciate learning about it. 2.) Crossings of streams containing adult fish must span the entire stream itself. Submitted and approved design sketches appear to meet this condition on all of Mitkof and Vank Island protected fish streams. 3.) Additional punch, or corduroy logs through wetland areas must not be obtained from trees within one tree-height distance (or approximately 80-100 feet) of wetlands, streams or ponds on Vank Island only. Additional punch or corduroy logs may be necessary, and must be obtained from drier upland areas adjacent to the right-of-way corridor prior to entering the wetland area. 4.) Per telephone agreement between Remy Williams and Patrick McCoy on August 5th, Typar material will be employed beneath the corduroy logs along the entire beaver pond crossing (stream #1) on Vank Island. Typar will be fully removed following all project work, unless agreed to by the Forest Service that such removal will cause more harm to the beaver pond than good. Stan Sieczkowski, AEA Page 2 5.) The number of stream and wetland crossings must be minimized in so far as feasible. This single point is crucial towards minimizing, as much as can be expected, the likelihood of mucking up critical wetlands that are so prevalent under this power transmission corridor. Single trips daily to and from the project work site are highly encouraged. Work crews are encouraged to carefully plan their daily activities so that extraneous trips to retrieve forgotten/misplaced items while utilizing a tracked vehicle is minimized. 6.) The Forest Service will make one more attempt to verify anadromous fish species in Vank Island streams in late August or early September, and will convey the results to the Alaska Department of Fish and Game. Please be aware that agreed-to mitigation measures on Mitkof Island may not necessarily be identical on Vank Island. For instance, the use of "pioneer trails" while encouraged on Mitkof Island, will be discouraged on Vank Island, and the use of additional corduroy logs to facilitate the travel of equipment on Vank Island will be encouraged along the existing travel corridor. On Vank Island, dead and down woody material found within the transmission line corridor, and dead standing trees located along the edges of the transmission line corridor are encouraged to be utilized. In the absence of such material, the contractor may cut Alder found within or adjacent to the transmission line corridor first, and other species located immediately adjacent to the corridor and within easy retrieval of the excavator. Our emphasis on Vank Island is to fully utilize the existing travel corridor only. I am including a separate Forest Service write-up concerning our understanding of some of the issues surrounding the Tyee transmission line work on Mitkof Island for your information. If you have any questions please contact Patrick McCoy at the address above or at (907) 874-2323. Sincerely, Q \G VU rrr ooh TEPHEN J. BRADY istrict Ranger Enclosure cc: D.Helmick, PRD United States Forest Region 10 Petersburg Ranger District Department Service Tongass National Forest P.O. Box 1328 of Agriculture Petersburg, Alaska 99833 (907-772-3871) Reply To: 1950, 7710 Date: July 17, 1997 Subject: Alaska Energy Authority Tyee Transmission Line Improvement Project To: Pat McCoy, WRD I'd like to offer this as an addition to the trip report Dave Helmick wrote on our July 1, 1997 inspection. When we looked at the State land muskeg, | made it clear that what | had to say about what to do/what not to do on that land was immaterial. | told them they needed to confer with the State (or Mental Health, as the case may be) for a decision. The benefit that | received from looking at the State muskeg was to get prepared for upcoming operations on NFSL muskegs - what to allow, what to avoid, etc. When we looked at Olsen’s, | stressed that the LTF was under special use permit to another entity and had significant clean-up requirements pending at the site. |! made it clear that nothing was to be done by IRBY, etc., at that site that would interfere with the clean-up. This was why it was imperative for the FS to be given several days notice before IRBY was to use the site for anything. I'd like to reinforce that the restoration of natural drainage at the tower/anchor sites is to be accomplished via hand work. | think there was general agreement that using heavy equipment to re-establish drainage would only result in additional damage. During the inspection, it was also agreed that trees needed for additional corduroy would be marked by the FS prior to cutting. Alder does not require designation prior to cutting. On July 9, 1997, Remy Williams, Stan Siezkowski, and Dan ? (AEA) and Dennis Lewis (Petersburg Power Superintendent) visited me at my office. Stan was very concerned that the FS was not being honest with AEA on their contractor's performance. | told him | had two major concerns. One was that communications continue to be a rough spot. The example | gave him was being contacted by the local fuel contractor regarding providing aviation gas for helicopters for the project. | told Stan that all of that stuff should be coming back through IRBY to Power Engineering to AEA and then to the FS. | told him | realized that was very time consuming, but that | didn’t want to be dealing with confusion on my end. | felt that was AEA’s job to straighten out with their contractor. Stan agreed with this and reinforced that Remy was the person we needed to be dealing with exclusively. The second concern | shared with them was that, back when the project was in the pre-work stages, the FS was continually assured that this project would not require much time on our part. | told them after viewing the site on July 1, | realized that the FS needed a liaison on-site most of the time. | told them | was very disappointed by this realization, as we do not have the extra time to spare and another high priority project would suffer as a result. | also told them that | would recommend to the Wrangell District that they send a representative over to Mitkof Island to view the work being done in order to get a better feel for what was coming their way. 2 INTHAM District Range cc: D. Helmick