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Intertie Operating Commitee Meetings 2000
ALASKA INTERTIE loc. MEETINGS STAN SIECZKOWSKI ANCHONAGE FAIRBANKS INTERTIE ALASKA INTERTIE OPERATING COMMITTEE COMMITTEE MEMBERS January 20,2000 MEMBERS UTILITY PHONE INTERTIE OPERATING COMMITTEE Bob Day ML&P 263-5295 Chairman John Cooley CEA 762-4789 Vice Chairman Bob Drake MEA 761-9283 Brad Evans GVEA 451-5655 Don Stead HEA 235-3336 Stan Sieczkowski AEA 269-3024 Secretary DISPATCH SUBCOMMITTEE Brad Evans GVEA 451-5655 Chairman Doug Hall ML&P 263-5453 John Cooley CEA 762-4789 Ray Morgan MEA 761-9318 Don Stead HEA 235-3336 RELIABILITY/PROTECTION SUBCOMMITTEE Luke Sliman CEA 762-7602 Chairman Larry Hembree ML&P 263-5243 Don Stead HEA 235-3336 Ray Morgan MEA 761-9318 Don Ritter GVEA 451-5658 MACHINE RATIN BCOMMITTE Steve Gilbert CEA 762-4446 Chairman Alex Gajdos GVEA 451-5654 Hank Nichols ML&P 263-5329 Stan Sieczkowski AEA 269-3024 Don Stead HEA 235-3336 CADA/METERING Brad Evans Mary Battensmith Paul Johnson Ray Morgan Don Stead BUDGET SUBCOMMITTEE Stan Sieczkowski John Cooley Bob Day Bob Drake Don Stead 451-5655 263-5263 762-4447 761-9318 235-3336 269-3024 762-4789 263-5295 761-9283 235-3336 MAINTENANCE SUBCOMMITTEE Monte Ervin Bob Drake Doug Hall Paul Rissee Stan Sieczkowski 451-5686 761-9283 263-5453 762-7661 269-3024 MMUNICATION SUBCOMMITTEE Chairman Chairman Chairman ek O AACKA CONTE TE Foc,WEETINE APRIL 2,OO _SVEA. 'Abi cipast Lab ity PHO Zh ieo 2Kowek'EA _wU9-3024. Baan thee CHUGACH 762-74YOTyhyCook,Chua nek 762 4784 Krodley Coons GN 45\-S6S5WansxNaixCLBMe<P 263-533 \ O Gob fhecy cr Wi hby?2EG>-S U1'S Dow Sram LEA Bs-3336 he. 02000 244.te>[67 AORNES| April 24,2000 Alaska Electric Generation and Transmission Cooperative,Jim Patras City of Seward -Dave Calvert Chugach Electric Association,Inc.-John Cooley Golden Valley Electric Association,Inc.-Brad Evans Homer Electric Association,Inc.-Don Stead Matanuska Electric Association,Inc.-Robert C.Drake Re:Responsibility for Spinning Reserves Dear Sir/Madam, The matter of the allocation of responsibility for spinning reserves underAddendumNo.1 of the Intertie Agreement is scheduled for action at the April 27 meeting of the Operating Committee.It is important to all Railbelt utilities that the implementation of the spinning reserve obligations under the Intertie Agreement be brought up to date. The changes in the utility industry since 1985,the advent of non-utility generators such as independent power producers,and the new ways in which utilities use and operate generating resources make this topic one of some urgency.Spinning reserves are the backbone of system reliability.The allocation of the responsibility for providing spinning reserves must be equitable under today's circumstances to ensure that adequate spinning reserves are available when they are needed. To address these issues,and to aid in the discussion of this issue at the April 27" meeting of the Operating Committee,I have attached to this letter a proposed resolution for your consideration.It addresses the allocation of spinning reserves within the context of Addendum No.1 by proposing an interpretation of the existing spinning reserves allocation formula in light of today's circumstances.In essence,it would interpret the phrase "utility system”to mean control area,and would apportion responsibility for spinning reserves based on all of the generation expected to be online in a control area during an hour,regardless of the capability of the resource or of who owns or dispatches it. This approach would eliminate disputes over who owns or dispatches a generating unit,and eliminate the current incentive for contractual game playing.Instead,it would make the common sense presumption that all generating resources in a control area should contribute to the spinning reserves available to the system.Under this approach, independent power producers would have to contribute their fair share to system spinning reserves,and would not get a free ride at the expense of the generating utilities.I believe that this approach is more consonant with today's realities,and is worthy of your support. If you have any questions or suggestions regarding this proposal prior to the April27"meeting,please contact me at (907)263-5295 (dayrh@anchorage.ci.ak.us).We look forward to discussing and resolving this issue at the next Operating Committee meeting. Sincerely, Robert H Day Acting Manager, Power Management April 24,2000 Re:Responsibility for Spinning Reserves Page 2 of 2 RESOLUTION OF THE INTERTIE OPERATING COMMITTEE GOVERNING THE CALCULATION AND ALLOCATION OF SPINNING RESERVES Pursuant to Sections B-2.1.2,B-2.2.3,B-2.4.3 and B-2.4.4 of Addendum No.1 of the Intertie Agreement,the Operating Committee hereby adopts the following provisions for the implementation of Operating Reserves,Operating Reserve Obligations and Utility Participant's Allocation under Addendum No.1. 1.For purposes of implementing the provisions of Sections B-2.1,B-2.2 and B- 2.3,Utility Participant shall be interpreted to mean only those Utility Participants that operate a Control Area. 2.For purposes of implementing the provisions of Sections B-2.1 and B-2.2, generating unit capability for each generating unit that is integrated into the Intertie System will be established prior to the first day of each month pursuant to Section B-.2.2.2(b),using the average ambient temperature forecast for each such month in the zone in which each generating unit is located. 3.For purposes of Section 2.3,the phrases "...the capability of the largest generating unit contingency in operation at each Utility Participant...”and "..largest on-line generation unit capability...”shall mean the generating unit capability of the largest generating unit that is in operation in the Control Area of a Utility Participant during the relevant time period,and shall include all generating units that are integrated into the Utility Participant's Control Area, without regard to who owns,operates or receives the electrical output of such generating resources. 4.Prior to the beginning of each clock hour,each Utility Participant that operates a Control Area will communicate to all other Utility Participants that operate Control Areas by telephone (or other electronic means agreed to in writing by these Utility Participants)the generating units,and the capabilities of those units,which it plans to operate during the next clock hour. 5.Spinning reserve obligations will be apportioned to each Utility Participant that operates a Control Area using a ratio,the numerator of which will be the larger of sum of the generating unit capabilities of all generating units in the Control Area planned to be on line in the next clock hour or the sum of the generating unit capabilities of all generating units in the Control Area actually on line in that clock hour,and the denominator of which will be the sum of the generating unit capabilities of all generating units planned to be on line in all Control Areas in the next hour. RESOLUTION OF THE INTERTIE OPERATING COMMITTEE GOVERNING THE CALCULATION AND ALLOCATION OF SPINNING RESERVES PAGE1 OF 2 6.Not later than five days after the end of each month,each Utility Participant that operates a Control Area shall provide to all other Utility Participants that operate Control Areas data reflecting the generating units that were planned to be on line in such Utility Participant's Control Area during each hour in the preceding month,and the generating units that were actually on line in such Utility Participant's Control Area during each hour in the preceding month. 7.If the data provided pursuant to section 6 above establishes that during any hour in the preceding month generating units were on-line in the Control Area of a Utility Participant with a total of unit capabilities in excess of the total of unit capabilities which the Utility Participant had planned to be on line prior to the start of such hour,the other Utility Participants that operate Control Areas shall be entitled to compensation pursuant to Section B-2.4.7.Such compensation shall be based on the difference between the Spinning Reserves that were provided by the other Utility Participants operating Control Areas, and the Spinning Reserves that the other Utility Participants with Control Areas would have provided if the generating units that actually operated during such hour had been used to calculate the Spinning Reserve obligations. RESOLUTION OF THE INTERTIE OPERATING COMMITTEE GOVERNING THE CALCULATION AND ALLOCATION OF SPINNING RESERVES PAGE 2 OF 2 ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY {=ALASKAmE)=ENERGY AUTHORITY 480 WEST TUDOR ANCHORAGE,ALASKA 99503 907 /269-3000 FAX 907 /269-3044 April 20,2000 Mr.Bob Drake Operations Manager PO Box 2929 Palmer,Alaska 99645-2929 RE:Alaska Intertie -Right of Way Clearing Contract #ROW2000-03T Draft Dear Bob, The draft has been reviewed and |have only a few minor questions or suggestions. e The owner definition should include State of Alaska or reference the state for legal purposes. e The state should be named as an additional insured.(Sec.18). e lt appears this spec was developed from a standard and it references highways (Sec.13 A). Do you want it included? e Please include the standard restrictions for ROW clearing near streams and roads.This requirement for a visual barrier and selective hand clearing in these areas was stipulated in the contract for the ROW clearing performed last year. e The width of the clearing should be a minimum of 100-ft within the 400-ft ROW.This is measured 50-ft on either side of the center phase conductors. Please proceed to issue the Right of Way clearing contract ROW2000-03T to clear the Intertie ROW from the north side of the Talkeetna River to Chulitna Ridge near structure 250.Included for your contract are 6 sets of the map for this area. The FY 2000 budget is $25,000 for ROW clearing.The budget for FY 2001 is to be discussed at the next IOC meeting in Fairbanks on April 27.If more funds are needed to complete this job we should request them in the new budget.| Sincerely, Stan Sieczkow Operations Manager Coc:Dennis McCrohan,AIDEA Monte Erwin,Maintenance Committee Chairman Apr=25-00 08:56 From-HOMER ELECTRIC 9072353323 T5086 =P.02/02 0 Fe44 Homer Electric Association,Inc. Corporate Office Central Peninsula Service Center 3977 Lake Street 280 Airport WayHomer,Alaska 99603-7680 Kenai,Aluska 99611-5280Phone(907)235-8551 Phone (907)283-5831FAX(907)235-3313 FAX (907)283-7122 April 24,2000 Stan Sieczkowski Alaska Energy Authority 480 West Tudor Road Anchorage,AK 99503-6690 Dear Stan: RE:AVIATION INSURANCE Homer Electric Association,Inc.has not been able to get aviation insurance coverage to the Jevel required by our Bradley Lake O&M Contract.That level is one million dollars per seat to a maximum of $10 million with a property damage maximum of five million dollars.The total maximum is $15 million. The best that we can get is one million dollars per seat to a total maximum five million dollars. We are binding this coverage,including slung cargo rider today.HEA is requesting a waiver of section 13 d of the contract,recognizing this reduction of coverage.It is my understanding that this coverage is betrer than what generally is available in Alaska today. Thank you for your consideration. Sincerely, HOMER ELECTRIC ASSOCIATION,INC. N.L.Story General Manager C:Reading File Don Stead Beth Wythe F:ATFints\2000\BradleyA viationInsurance.wpd Loc.Meeting[-20-00 @ HECr7T -"O LAL EN LIE aw Grecekouski-_ABA 269-302 F-Tey SEAD _Neb}e 235-3326 TAQ R=Va MLEP 263 Sane ass ts Punwecs MLS e 26s-S 331 Mike Kreck MLE 2637S 235 - =<3.\5 (Deke.MEA 1b[-92&3 Tohn Cooken ce 162-4189 ALASKA INTERTIE OPERATING COMMITTEE O ummary -Formal Operating Committee Actions/R mmendation Meeting Formal Actions/Recommendations TAB ACTION Dates 3/9/83 Election of Officers.2 4/13/83 No formal actions.- 5/18/83 No formal actions.- 6/15/83 Adopted Operating Committee (IOC)Handbook format and guideline listing.2 7/13/83 Adopted listing of Operating Committee Officers Adopted revised guidelines for Handbook. Accepted the report of the Reserves/Loadshed Subcommitteee. Accepted the report of the Scheduling/Dispatch Subcommitteee.&WNHND8/11/83 Adopted Gilbert Commonwealth proposal on Intertie Relaying and Protection.3 Adopted Reserves/Load shed requirements.3 Adopted first SCADA/Metering/Communications requirements.4 9/22/83 Adopted Article III of the draft Intertie Contract.2 Adopted the changes in Article XIII of the draft Intertie Contract (Operating Committee's position on reserves).2 Adopted Machine/Rating uniform rating forms.4 10/20/83 Formed Dispatcher/Training Subcommittee.2 Adopted Computer to Computer Data Link Standards.4 Adopted Operating Guides 2,3,4 &5.4 11/17/83 No formal actions.- 1/11/84 No formal actions.- 2/15/84 Readopted Operating Guides 2,3,4 &5 and adopted Guide index.4 Adopted $10,000 for the preparation of Machine/Rating manuals.5 3/21/84 Reinstated existing officers for one more year.2 Adopted Operating Committee participants to discuss the scope of the study on the data link with AEA. Adopted to review the proposed CEA Accounting and Scheduling Screen Format Displays. Adopted first Operating Committee budget of $183,399.00 BA4/18/84 Adopted request to AEA for spinning reserve and load shed study. Adopted Operating Guides 1 and 6. 5/9/84 Adopted to activate Reliability/Criteria Subcommittee.2 Adopted that the Secretary write a letter concerning the current kwak Meeting Dates Formal Actions/Recommendations TAB ACTION O 6/14/84 7/12/84 8/23/84 10/11/84 O 11/15/84 12/13/84 1/18/85 2/14/85 Or Intertie Agreement and the annual Operation Intertie funds. Adopted that each utility issue a letter of no objection releasing the Ebasco load data. Adopted the draft outline of Machine/Rating Handbook. Adopted rewrite of NERC Guide 16. Adopted that the Reliability subcommittee's task is to evaluate the proposed methods to be used to meet the reserve requirements. Adopted the approach of dual redundancy in regards to data link. Adopted to evaluate the results of the University of Alaska Fairbanks dispatcher training. AEA commitment to have an Engineer. Adopted -SCADA/Metering/Communications Subcommittee's work towards setting standard for metering conventions. No formal actions. Review-Alaska Railbelt Interconnected Electric System Data Book. Adopted SCADA/Metering/Communications -Dispatch/Scheduling Subcommittee's recommendation on "Minimum Intertie Operating Requirements." Review the Anchorage Fairbanks Intertie Operating Procedures. Dispatch/Scheduling Subcommittee to review: the Intertie Operating Procedures;NERC Guide No.10,NERC Performance Criteria and NERC Minimum Criteria for Operating Reliability. Adopted UAF to Reliability/Criteria Subcommittee. Adopted revision to UAF Dynamic Stability Study. Adopted SCADA/Metering/Communications Subcommittee's recommendation on "sign conventions.” ML&P to complete their review of the Anchorage-Fairbanks Intertie Operating Procedures Draft Manual. Accepted SCADA/Metering/Communications report. Accepted Machine/Rating Handbook for review by |OC members. Accepted Dispatch/Scheduling Subcommittee report. Adopted Anchorage-Fairbanks Intertie Data Link Requirements. Adopted NERC Guide No.10 and NERC "Control Performance Criteria." Adopted position on Healy SVS limitations on starting. Assigned Dispatch/Scheduling subcommittee to identify losses. Adopted recommendation to upgrade the G/C/A (12/31/84) "Anchorage-Fairbanks Data Link to reflect the ML&P/GVEA vendor specifications." Election of Officers. Adopted motion for AEA to furnish loss tables. 2 3 4 4 htAkW Meeting Formal Actions/Recommendations TAB ACTION Dates 4/17/85 Appreciation for the services by Mr.Keith Sworts.2 O AEA to determine interim power flow maximum values.3 15/85 Adopted motion on ASCC coordination with IOC.2 Adopted motion on North/South 50/50 share on MITCR interim cost.6 6/12/85 A letter of appreciation to Dr.John Aspnes-Dispatcher Training Seminars.2 7/10/85 Anchorage-Fairbanks Intertie be recognized as an Alaska Intertie.2 Adopted Intertie Operating Procedures and Transmission Loss Study be dated whenever there is a revision.3 Readopted !OC budget of $183,399.5 8/14/85 IOC thanks John Marshall for the work done on Under Frequency Load Retention Plan. !OC concurred with the Under Frequency Load Retention Plan.WKN10/9/85 Adopted IOC meeting location rotation. IOC to meet at least once a month. Adopted the designated participants. Adopted Operating Guide No.4. Adopted Alaska Intertie Operations Hourly Data and Summary sheet for the interim/test period. 11/13/85 |Adopted Operating Guide No.6,Voltage and Reactor Control. Adopted Operating Guide No.3,Scheduled Interchange.O55 Adopted IOC bimonthly meetings. Adopted Test Standards for Alaska Intertie Metering.&NDAt>&NMNMPD3/12/86 Election of Officers. Adopted NERC Operating Guide No.9.a)4/23/86 Adopted IOC FY87 budget.5 5/21/86 Adopted IOC FY88 budget.5 Adopted FY87 MITCR calculations.6 7/16/86 Adopted-amended Power Flow &Stability Analysis Contract w/UAF 3 Directed AEA to revise the AIA -Self Insurance 6 Adopted motion to require insurance documentation.6 Adopted the amended Data Base Management Contract with UAF.6 9/17/86 No formal actions. 11/12/86 |Adopted the 10 power flow and 3 stability cases for study by UAF.3 1/14/87 Adopted to have the subcommittee chairman be an operating committee member or alternate.2OAdoptedmotionforthedevelopmentofspinningreservedeficiency accounting and reporting and investigate control performance methods and procedures.4 Meeting Formal Actions/Recommendations TAB ACTION Dates Adopted-UAF obtain better analytic tools and software for the study. O 1/87 Election of Officers.2 Adopted NERC Guide No.14.4 5/20/87 Election of Secretary.2 Appreciation and thanks to Ed Morris.2 Adopted FY88 Operating Budget,$132,000.5 Adopted FY88 MITCR calculations.6 7/8/87 Adopted motion not to accept Electrocon software proposal.3 Electrocon software substitution by UAF.3 Adopted motion not to accept the UAF GIC proposal. Intertie maintenance cost reimbursement.6 9/9/87 No formal actions. 11/18/87 No formal actions. 1/13/88 Adopted draft FY 1989 budget. Recommended IOC participation at a meeting with GE in NY.6 Adopted no cost extension for the two contracts with UAF.6 3/16/88 Election of Officers.2 Adopted Intertie Outage Report Form with Instructions,Intertie 4 Switching Procedures,and Intertie Switching Order with Instructions.O Adopted $12,000 per Schweitzer relay installation.5 4/11/88 Adopted load flow cases 1 &2 and stability cases 1 &2.3 Special Adopted motion to install Modified Voltage Feedback and SVC 3 Meeting Voltage Preset Point. Adopted SVC modifications and testing schedule.3 Adopted $30,000 for 3 UPS complete.5 5/11/88 Recommended load shedding criteria evaluation.3 6/13/88 Adopted-GE installation should not require additional protection 3 Special Adopted AEA order UPS installation.6 Mtg. 7/13/88 Adopted the correspondence policy.2 Adopted motion to write a letter of thanks to UAF.2 Adopted NERC Guide No.1.4 Adopted Intertie Outage Report Instructions and summary sheet.4 Adopted IOC FY1990 budget.5 Adopted $24,000 for group insurance.5 Oo Adopted the new subcommittee list.2 Adopted the FY89 MITCR calculations.6 Meeting Formal Actions/Recommendations TAB ACTION Dates_11/9/88 FMUS to look into under frequency load shedding for compliance.4 Adopted NERC Guidelines (Appendix I.F and Guide 11).4OAdoptedthechangestoArticle17,Insurance and Liability,AIA.6 1/11/89 Adopted motion to accept the RFP for Data Base Management.3 Adopted motion to secure Contractor for the Evaluation of Existing 3 Railbelt Utilities Under Frequency Load Shedding Program. Adopted Revenue Metering Standards and Test Standards.4 Adopted NERC Guide No.Ill,Emergency Operations.4 3/8/89 Election of Officers.2 Adopted motion not to accept the final report on the SVC 3 performance evaluation. Adopted motion-Proposal from UAF for Data Base Management 3 Adopted motion not to pursue economic dispatch and optimum 3 power flow options. Adopted NERC Guides IV through VI.4 4/12/89 Adopted RFP for the under frequency load shedding program.3 Special Adopted FY90 MITCR calculations.6 Mtg. 5/10/89 Adopted motion to accept UAF Data Base Management proposal.3 Adopted motion to declare the data link operational.4 Adopted motion to accept the Amendment No.1 to Alaska Intertie Agreement,Article 17.6OAdoptednottofundCollectionandAnalysisofGeomagnetic Disturbance Data from the Anchorage-Fairbanks Intertie. 7/12/89 Adopted $1,000,000 line of credit proposal.5 Adopted $142,000 FY91 IOC operations budget.5 8/7/89 No formal actions. Special Mtg. 9/13/89 Adopted UAF to maintain the Electrocon Program.3 Accepted UAF Workshop Dates.3 Adopted motion to send out Test Standards for Alaska Intertie Revenue Metering to utilities.4 Adopted motion to receive the quotes for demand recorder system from Landis &Gyr and General Electric Co.4 Adopted Alaska Intertie FY91 Budget.5 11/8/89 Adopted Operating Guide 35.4 1/10/90 Adopted to install Schweitzer Display/Transducer Adapters,DTA.3 Adopted to install Dynamic System Monitors.3 Adopted $85,000 towards field tests to determine the turbine- governor response characteristics.5 Adopted AEA to administer field tests contract.6O5/90 Election of Officers.2 Adopted Technical Guidelines for Operation,Metering,and 5 Meeting Dates Formal Actions/Recommendations TAB ACTION O 5/9/90 7/12/90 9/12/90 11/14/90 1/11/91 3/12/91 5/8/91 O 7/10/91 9/11/94 11/13/91 1/23/92 O 1/92 Protective Relaying for Non-Utility Power Producers and Cogenerators. Adopted RFP to establish the trust account. Accepted-IOC/ASCC Coordination subcommittee mtg minutes. Modifications to the SVC system. Adopted $120,000 IOC budget for FY92. Adopted FY91 MITCR calculations. IOC thanks AEA and John Zidalis for the hospitality at Bradley site. No formal actions. No formal actions. No formal actions. Election of Officers. Adopted utilities to purchase PTI PSS/E program. Adopted FY92 MITCR calculations. IOC chooses not to purchase PTI PSS/E program for UAF. UAF to provide proposal describing what UAF can provide for research and training. Utilities update IOC and its subcommittees member list. Release the data base. Adopted $50,000 for IOC budget for FY93. Adopted SVC reserve funds for the repair of the Goldhill SVC bldg. AEA letter to PTI on under frequency load shedding study. Protection Coordination subcommittee Chairman's letter to PTI. Adopted the ten year climbing cycle for line maintenance. MEA investigate and evaluate insulator flashover problem on Teeland-Douglas 138 kV line. IOC write a letter to AEA about installing a guard structure for the Caswell Lakes road crossing of the Intertie. Combine Dispatch and Reserves Evaluation subcommittees. Combine Reliability/Criteria &Protection Coordination subcommittees Proposal offered by ML&P. Adopted Alaska Operating Guide. Siemens disconnect switch operation and operating criteria. Adopted $6,500 for the guard structure installation. Adopted additional $15,000 towards the completion of the under frequency load shedding study. Election of Officers. Secretary to compile a list of formal actions taken by the IOC. AEA submit budgets before calculating energy and capacity rates. ASCC to fund additional load shedding cases. 6 aNOOWbh(6)NNNM Meeting Formal Actions/Recommendations TAB ACTION Dates Consider a proposal offered by AML&P,Intertie metering.4 OQ Adopted $49,300 to investigate the structural integrity of towers.5 13/92 Approved the proposed Talkeetna tap by MEA.3 Approved Quantum meters.4 Approved $5,000 for Douglas substation RTU.5 Adopted FY93 MITCR calculations.6 --FY '93 -- 7/8/92 No formal actions. 7/14/92 IOC Chairman contact Machine/Rating subcommittee Chairman.2 Special Reliability/Protection subcommittee is to complete conclusions and Meeting recommendations.3 Reaffirm the method of calculating the operating reserves.4 Spinning reserve requirement calculation -motion failed.4 Adopted capability of a unit.4 Operating reserve obligations for Bradley Lake -motion failed.4 Spin obligations under joint unit participation -motion failed.4 Selling of required spinning reserve by utility participants- motion failed.4 Tabled Appropriateness or Adequacy of declared spin.4 ©Adopted Reserve Calculations Post Bradley Lake.4 13/92 No formal actions. Teleconf. 9/9/92 Distribute a list of current members to IOC and its various subcommittees.2 Submit comments on Dryden &LaRue Report "Anchorage- Fbx.Intertie,Investigation of Structural Integrity of Towers."6 11/12/92 IOC reaffirms development of procedures for the investigation of outages.4 1/13/93 Pertinent correspondence be distributed to other subcommittee members.2 Formulate a motion concerning the implementation of the revised load shedding schedule.3 3/19/93 Election of Officers.2 Adopted $5,000 for expenses associated with FERC rule making on 5 transmission line issues. 5/17/93 Election of IOC Chairman.2 Teleconf.Accepted the IOC's ASCC subcommittee's recommendation. 8/93 New Coordination/Regulation subcommittee.2 Operating Reserves and other Reliability issues.3 ML&P SILOS Program.3 7 Meeting Dates Formal Actions/Recommendations TAB ACTION O 7/14/93 9/8/93 9/22/93 Special Mtg. 11/10/93 1/20/94 2/25/94 3/30/94 6/3/94 7/15/94 9/22/94 9/28/94 Teleconf. Oxleconf. Adopted $15,000 to determine the integrity of foundation for structure #570. Adopted FY94 MITCR calculations. Obtain legal interpretation of the AIA Section 10.1. --FY '94 -- Participants develop Controller Responsibilities and Duties. Comments on Intertie Operations and Related Issues - The motion failed. Hold special meeting to asses the duties and responsibilities of the State. Authorize energization of in-lines switches at Stevens Appointed Fred LeBeau temporary Chairman SCADA Subcommittee No formal actions. No formal actions. Formalize requirements for energizing Stevens Substation Establish a Budget Subcommittee Accept ML&P offer to reduce controller costs Failed to modify energization requirements for Stevens Substation Election of officers Authorize $25,000 for Tower 749 engineering Adopted SILOS programs for Chugach and ML&P Authorized replacement of 3 electro-mechanical relays Adopted FY95 budget of $1,068,983 Approved payment of legal expenses for FERC transmission effort --FY '95 -- No formal actions. ML&P's motion on selling of spinning reserves failed No formal actions. No formal actions.On&aah&94-001 94-002 94-003 94-004 94-005 94-006 94-007 94-008 94-009 94-010 94-011 Meeting Formal Actions/Recommendations TAB ACTION Dates 11/16/94 Assigned Dispatch Subcommittee to develop scheduling and O accounting procedures for intertie accounting at metered points.4 94-012 11194 No formal actions. Teleconf. 1/18/95 Approved operating Healy SVS on the bus side of breaker 4 95-001 Approved modifications to Schweitzer relays 3 95-002 Approved addition of PT's at Cantwell 3 95-003 Approved disabling out of step blocking at Healy 3 95-004 Authorized Relay/Protection Subcommittee to contract with Dreyden LaRue for differential snow loading problems 3 95-005 Established a Maintenance Subcommittee 2 95-006 Approved installation of a DTA at Douglas 3 95-007 3/15/95 Approved quarterly reporting procedure to General Managers 4 95-008 Approved Differential Ice Loading Standard Operating Procedure 4 95-009 Authorized $10,500 for Dispatcher Training by ECC 5 95-010 Accepted the Machine Rating Handbook 4 95-011 Delayed election of officers to May meeting 2 95-012 5/17/95 Election of Officers 2 95-013 Adoption of FY'96 budgt in the amount of $1,272,704.5 95-014 Adoption of the MITCR calculations 3 95-015 Adopt the 342,000 MW-hours 2 95-016 On No formal actions. --FY '96 -- 11/16/95 Approved expenditure of $190,000 for Replacement of 3 Westinghouse 5 96-001 breakers. Approved increase funding for Differential Ice Loading Study by $35,000.5 96-002 Approved to support GCl's fiber optic communications stydy.Expend 5,6 96-003 $2,000 for in-house labor. Adjournment 96-004 1/17/96 Approved invoices billed.5 96-005 Approved that participants pay the capacity charges by July 15 of each year.5 96-006 Approved allowing GVEA the reallocation of $15,000 from "brush clearing”5 96-007 to "repairing helo pads.” 3/20/96 Election of Officers 2 96-008 6/11/96 Approved MITCR calculations as proposed by Budget Subcommittee 3 96-009 Approved the FY '97 Budget in the amount of $980,662 5 96-010 O --FY '97 -- 9 Meeting Formal Actions/Recommendations TAB ACTION Dates On:No formal actions. 9/25/96 Acceptance of FY '97 Budget Revision 5 97-001 Acceptance of Invoice Policy 5 97-002 11/20/96 No formal actions. 1/15/97 No formal actions. 3/19/97 Election of IOC Chairman 97-003 Electoin of IOC Vice Chairman 97-004 Temp.Chairman for Reliability Protection Subcommittee 97-005 Motion to Approve $50,000 for Dryden &LaRue Proposal 97-006 IOC Resolution -Comm.Recommendation to Intertie Participants Group 97-007 5/28/97 Approved the FY 98 Budget: Total Expenses:$1,365,410 Energy Rate:.509 Capacity Charge:$1.61/kw 97-008 --FY '98 -- 7/23/97 No Formal Actions. Oris:Adopted Operational Procedures for the Differential Snow Loading and MonitoringSystemasrecommendedbytheDispatchSubcommittee 98-001 2/27/98 Approved Budget Increase of $270,700 98-002 Adopted Bradley Model -Zero Sequence Impedance Data 98-003 Election of Officers 98-004 5/28/98 Approval of FY99 Budget with Total Projected Expenses of $1,133,805 98-005 Approval of MITCR and Energy Rates as proposed by Budget Subcommittee AEG&T 31.81% ML&P 27.42% CEA 40.77% GVEA 100% Dollars Per Kilowatt -$1.34 Energy Rate -5.15 mils 98-006 8/28/98 Approval -|OC recognize operating limit for the Intertie to be 79 MW into Healy as determined in PTI Report #R66-94 98-007 11/19/98 No Formal Actions. --FY '99 -- Oo John Cooley will write a letter to Saxton asking for opinions and suggestions about protection against liability on Spare Parts Agreement 99-001 10 Meeting Dates_ Formal Actions/Recommendations TAB ACTION O- 8/24/99 1/20/00 Approval of FY 2000 Budget of $1,027,560 with a shortfall of ($372,685) Approval of MITCR of 0.466 cents with a Capacity Charge of $1.21/kw Bob Day motioned to participate locally in a January 1,2000 contingency plan drill test the night of September 8-9,1999 --FY '00 -- Approval of 57.7 Hz for the Eklutna relay settings Acknowledgement of interest or disinterest in further consideration of the ML&P General Manager's proposal for the assessment and allocation of spinning reserves 11 99-002 99-003 99-004 00-001 00-002 O 10. 11. ALASKA INTERTIE INVOICE POLICY July 31,1996 The Budget Subcommittee shall meet quarterly and review the summary report of invoices paid to verify the proper coding and amounts.The Utilities shall provide the committee with a quarterly summary showing %spent,authorized amount,and line item balance. All invoices submitted to AEA shall have the proper backup to verify charges.The backup shall consist of payroll sheets,documented contract payments,copies of paid invoices for material and equipment,approved vehicle charges,and line item budget codes. Invoices paid by Utilities for Intertie approved items shall be submitted to AEA within 60 days after the Utility month end closing in which the payment was made.The Utilities shall provide the budget committee a quarterly report describing the non-routine projects that have been performed. The Utility that has incurred or made a firm commitment to incur an expense for the Intertie that will cross over the fiscal year end,shall notify the Budget Subcommittee by June 30.The notification shall identify the expense,the estimated amount,and the approximate time payment will occur. No invoice shall be paid by AEA if the IOC budget line item amount approved is exceeded until authorized by the Budget Subcommittee. The Budget Subcommittee shall have the authority to modify line item amounts if the total Intertie budget is not exceeded by 5%. All invoices shall be processed in the order received;however,non-Utility invoices shall be processed first. AEA shall provide quarterly reports by the 15"working day following the end of the fiscal year quarter to the Budget Subcommittee.Revenues,energy projections and use,line item expenses,investments,adjustments and any other pertinent data shall be reported. The budget shall be tied as close as practicable to the maintenance schedule. An audit may be conducted in accordance with Section 10.5 of the Alaska Intertie Agreement. Line item emergency expenditures or modifications,in addition to the approved IOC budget,require Budget Subcommittee review and IOC approval within 90 days of the action. h:\all\stanOC\Invoice Policy\Alaska Intertie Invoice Policy -July 31,1996 NUOICEPolicyTlaroe ©ALASKA wre IOC MEETING O SECRETARY LOCATION ACTION ACTION ACTION ACTION ACTION ACTION {00-{|00-} 00-} 400-} {00-|00-| PARTICIPANT lyes|No [ass|[yes|No {ass}|yes|No Jass|fyes|No [ass][yes|no |ass|[ves|No {aas| ALASKA ENERGY AUTHORITY [|_|{||Ltt |] tLt! lLti!s Ltt |Let) ANCH MUN.LIGHT &POWER Ltt Jttt tt |}LCL]CLE}ECL)LL!| ALASKA ELECTRICG&T Ltt |}LCL tJtttt Jj CEL |J CLE}Ltt f CHUGACH ELEC.ASSOC.Lt ||}Ett |Lit ttt}|}Ct?|Cott FAIRBANKS MUN.UTIL SYS.Ltt} tEt |!LEE} LEtLsttLt t |}Let GOLDEN VALLEYELECASSOC {[|[||{Jt ts LC¥tLtI}LLL!Lit Jittt i ACTION ACTION ACTION ACTION ACTION ACTION 100-}|00-}{00-}|00-}00-|{00-| PARTICIPANT lyes|No |ass}|yes|No jass||yes|No [ass]fyes|No jas}[ves|no |ass|_lves|No |ass| ALASKAENERGY AUTHORITY [|_j || L jt [|J Ltt |Lit |Ell |}Li |J ANCH MUN.LIGHT&POWER Ltt Jtt yt |j}CL?|} ELt |}LLt}Lt}4 ALASKA ELECTRICG&T Lit | tL_tsyitt ttl CLLEt}Lit!Ltt } CHUGACH ELEC.ASSOC.Ltt!ttt!CLELtEsvttt |J LE}EL) FAIRBANKS MUN.UTIL SYS.Lit }LLtit} Lti}Clit jtt}|}Ltt 4 GOLDENVALLEYELECASSOoc [_|[||Li ||LCL!LLL! CLEtLst1tLt |f stan\userdata\utl\iocvote1.xls ALASKA INTERTIE OPERATING COMMITTEE AGENDA Thursday,April 27,2000 SB10:00 a.m.' Golden Valley Electric Association < Boardroom 758 Illinois St Fairbanks,Alaska (907)451-5655 Chairman -Bob Day Members Utility Phone Fax Email John Cooley CEA 762-4789 762-4540 |Johncooley@chugachelectric.com Bob Day,Chair.ML&P 263-5295 263-5441 Dayrh@ci.anchorage.ak.us Bob Drake MEA 761-9283 761-9328 Brad Evans GVEA 451-5655 451-5657 BWEvans@aqvea.com Don Stead HEA 235-3336 235-3313 Stan Sieczkowski AEA 269-3024 269-3044 ssieczkowski@aidea.org 0 |Adoption of Prior Meeting Minute A. Approval January 20,2000 ification of Agenda Committee Reports and Corre ndenc moo@>H. Visitor' Dispatch Subcommittee Brad Evans,GVEA 451-5655 Reliability/Protection Subcommittee Luke Sliman,CEA 563-7494 Machine /Rating Subcommittee Steve Gilbert,CEA 762-4446 SCADA/Metering /Communication Sub Bob Day,ML&P 263-5295 Budget Subcommittee Stan Sieczkowski,AEA 269-3024 Maintenapre Subcommittee Monte Ervin,GVEA 451-5686 Intertie Status Réeport-(MCA Correspondence Received vetl mments Related to Items on Agenda 0. © ' Vil. Vill. Recess leWorksganfersitLhpatchSubcommittee LawlSpinningReserveIssuesbeIntertieAssignmentAgreement-GVEA x»)Stevens Substation Operation Procedures Wop €-K Committee Charter and MissionSfAobmeRenoet)B.Reliability/Protection Subcommittee .)4"Stage Load Shedding ) Recloser SchemeBakCommitteeCharter and Mission C.Machine /Rating Subcommittee Joint Maintenance Labor Agreement 2.)Spare Parts Agreement Update SX)Committee Charter and Mission D.SCADA/Metering /Communications Subcommittee " Ss Project SCADA Communications yoo w,DropsCommitteeCharterandMissionSstxvensQ E.eae Subcommittee{Financial Report ee hetatyFY2001Budget Committee Charter and Mission F.Maintenance Subcommittee sh Quarterly Maintenance ReportsSouthernROWClearingaComacCharteoneMissionRieDoseG.ML&P Quarterly Report for intertie Outages 1.)FY 2000 Events H.10C Committee Pan peList eerEFMLSFormalOperatihgpin,Lhe peopl/Recommendations A.Election of Officers Subcommittee Assignments A.Dispatch,SubcommitteeWe,_-PjB.Reliability /Protection Subcommittee esgt sy?CMT. C.Machine /Rating Subcommittee D.SCADA/Metering /Communication Sub E.Budget Subcommittee F,Maintenance Subcommittee IX.Determine Agenda for Next Meetin Meeting Location:Date: CE ZO X.Adjournment h:\all\sdean\stan\ioc\agenda.doc Time: JO :CO Ky] <hfoe YrD__Bev,Gr 410%7 be provd bull 1,029,S60 os 1 -tbeeX a rreacninng fief =Hou) wat _2cepe HE A __»20._lonanenl-wp 21 00701 Clebined Pefy,endlbey i) -__. ee a ee ---- _- _-- SEE oO 4-27 ID,Apprestanr_wokufeat/ TMA,pyre EXbAwa DewcLoprereb/Lhit-('Coa Venter. :Bp.Y 2001 Dud get : b FE , B nN _ Ne _ |SI nOre -2.Cosh;ALASKA wre 1OC MEETING <Q) SECRETARY LOCATION A/C RAS ACTION ACTION ACTION ACTION ACTION ACTION fe ow Day 00-00fo.00S][00-60 G |meGeos [00-6 %>]=[oo-] [oo-]wenu fe BudoctZOO|Syl }et cox,Cy fSydect2 Cae PARTICIPANT yes|No {assa es re lyes|No {ass}_|yes|No {ass}|ves|No [ass|_fyes|No |ass| ALASKAENERGY AUTHORMY [oT 11 LT]Mtl]CLD)Coo)Cr ANCH MUN.LIGHT&POWER POT:Boo Cor Coo)OCT ALASKA ELECTRICG&T Ivy?|J}Let |Jttst tT |}Cl]J Lt]|Ltt | CHUGACH ELEC.ASSOC.PET)Po Boo:ood Cod oo | FAIRBANKS MUN.UTIL SYS.("LT ]4 CL]MLO]CLOLI1CLeL!]Cle GOLDENVALLEYeLecassoc [MT 1]WELT]PLL]Chl)CordiCre ACTION ACTION ACTION ACTION ACTION ACTION [o0-| [oo-] [00-] [oo-|[00-] [oo-] PARTICIPANT lyes|No {ass|yes|no |ass}[ves|No jass}|ves|No jass|[yes|No lass}[yes|No [ass| ALASKAENERGY AUTHORITY j{{|||{||[||Lettie}Litt |]ttt j Let | ANCH MUN.LIGHT&POWER Lt ft Jttet tt |}LEL|}ECL)EL!|Ltt J ALASKA ELECTRICG&T Lt tt }LE t_Jt1tt ||Ltt |}Ltt }LCL Tt 4] CHUGACH ELEC.ASSOC.Ly |}EPL tj}ECE?Jttt |j}LLt|}Let I FAIRBANKS MUN.UTIL SYS.L ||Lt t |}Ltt}}LCL Jt1tttit |} _t ft 4| GOLDENVALLEYELECASSOc [||||L_|{||L_][||L_[[|]L{[|Jil]|J stan\userdata\utl\iocvote1.xis ALASKA INTERTIE FY 2001 Proposed BUDGET O April 25,2000 APPROVED PROPOSED Budget Budget FY 2000 FY 2001 5/20/99 REVENUES GVEA 563,280 1,271,480 MLP 22,920 28,824 CEA 34,541 43,656 AEGT 34,134 45,947 FMUS 0 0 INTEREST 0 0 TOTAL REVENUES 654,875 1,389,907 EXPENSES FERC 561 -Load Dispatching GVEA Northern Controller 0 0 MLP Southern Controller 0 0 AFI Other , 0 0 0 0 FERC 582 -Station Operation Expenses GVEA-substation electricity usage 7,500 7,500 0 0 7,500 7,500 FERC 563 -Overhead Line Expenses GVEA -Weather monitoring equipment 220,000 220,000 220,000 220,000 FERC 565 -Transmission of electricity by others MEA Wheeling -Holly Rd to Douglas 32,000 154,145 32,000 154,145 FERC 566 -Miscellaneous transmission expense SCADA&voice circuits (SOA)199,600 220,000 Cell phones for weather monitoring 10,000 10,000 Weather monitoring maintenance 20,000 60,000 Weather Monitoring Support Contract 60,000 60,000 229,600 290,000 4/25/00/2:12 PM Page 1 NOTES: Revenues include full year capacity billing Wheeling charges at Contract rate. Intertie Communications Circuits AT&T through 1/16,Mactel Charges through 2/16 Replacement of batteries and add cameras Dryden and LaRue Contract h:all\elaine\akil\file:AIFYO1 Budget.xis\ws:FY99 AKI BR O ALASKA INTERTIE FY 2001 O OProposedBUDGET April 25,2000 APPROVED PROPOSED Budget Budget FY 2000 FY 2001 5/20/99 NOTES: FERC 567 -Transmission Expenses -Rents Rents -Alaska Railroad 600 600|Annual lease payment. MEA-Talkeetna Storage 7,200 7,200)Annual lease payment. 7,800 7,800 FERC 570 -Maintenance of station equipment GVEA -Healy Cantwell,Goldhill 64,828 66,797 |Routine CEA Teeland Substation 410,000 18,000 {Routine MEA-Douglas substation 10,000 10,000 |Routine Extraordinary maint -GVEA 0 0 Extraordinary main -CEA 0 0 Extraordinary maint -MEA 0 0 84,828 94,797 FERC 571 -Maintenance of overhead lines Maintenance of Overhead Lines -Other 0 0 GVEA Northern Maintenance 61,132 62,355 {Routine MEA Southern Maintenance 31,500 60,000 jRoutine Extraordinary Maintenance -GVEA 0 0 Extraordinary Maintenance -MEA 0 0 MEA-Landing Pads 0 40,000 GVEA-Landing Pads 45,000 45,000)Rebuild and/or clear GVEA-Tighten Guys 30,000 30,000}Routine GVEA-Moody Creek Slide Study 0 0 GVEA-Northern ROW clearing 20,000 20,000}Routine MEA-Southern ROW clearing 25,000 60,000)Routine 212,632 317,355 4125/00/2:12 PM Page 2 h:all\elaine\aki\file:AIFYO1 Budget.xIs\ws:FY99 AKI BR ALASKA INTERTIE FY 2001 Proposed BUDGET April 25,2000 FERC 920 -AEA Administrative Costs Personal Services,travel and other costs FERC 920 -IOC Administrative Costs Legal Expense 1OC -Gen Prof Services FERC 924 -Property Insurance AF Intertie -Insurance Risk Management Fee Line of Credit Fee TOTAL EXPENSE SURPLUS (SHORTAGE) 4/25/00/2:12 PM O APPROVED PROPOSED Budget Budget FY 2000 FY 2001 5/20/99 60,000 58,000 60,000 §8,000 25,000 25,000 0 0 25,000 25,000 82,000 82,000 6,200 6,200 0 0 88,200 88,200 997,560 1,292,797 (342,685)97,110 Page 3 4 67 h:all\elaine\aki\file:AIFYO1 Budget.xls\ws:FY99 AKI BR ALAS FISCAL YEAR 2001 ENERGY PROJECTIONS TERTIE FMUS GVEA AEG&T CEA ML&P MON TOTAL FMUS MONTH MWH MWH MWH MWH (IN GVEA) Jui-00 0 35,000 864 0 0 35,864 $0 Aug-00 0 36,000 864 0 0 36,864 $0|Sep-00 0 38, 00 403 0 0 38,403 $0 Oct-00 0 40,000 43 0 0 40,043 7 $0 Nov-00 0 41,C00 43 0 0 41,043 $0|Dec-00 0 42,000 43 0 0 42,043 $0 Jan-01 0 40,000 43 0 0 40,043 $0 Feb-01 0 33,000 43 0 0 33,043 $0 Mar-01 0 35,000 43 0 0 35,043 $0 Apr-01 0 30,000 403 0 0 30,403 $0 May-01 0 33,600 864 0 0 33,864 $0 Jun-01 0 35,000 864 0 0 35,864 $0 FY 01 TOTAL 0 438,000 4,522 0 0 442,522 $0 TOTAL INTERTIE FROJECTED ENERGY USAGE FOR FY 2001 442,522;MWH Useage estimate reduced by 1/12 of Total for rate calculations 405,645,MWH Section 8.2.2 MINIMUM USEAGE CONTRACT VALUE 183,960;MWH UTILITY FY 01 EY 01 AEG&T 31.88%22.316,MW ML&P 27.09%18.963;MW CEA 41.03%28.721|MW FMUS 0.00%0.000 MW GVEA 100.00%70.000|MW Alaska Intertie FY 01 Usage Projections 42400.xIs 4/25/00 ALAS TERTIE FISCAL YEAR 2001 ENERGY PROJECTIONS GVEA AEG&T FMUS GVEA AEG&T [ML&P CEA CASH FLOW ENERGY CAPACITY TOTALS $93,100 $2,298 $0 |$106,400 $33,920 $28,824 $43,656 $308,198 $95,760 $2,298 $98,058 $101,080 $1,073 $102,153 $106,400 $115 $106,515 $109,060 $115 $109,175 $111,720 $115 $111,835 $106,400 $115 $106,515 $87,780 $115 $87,895 $93,100 $115 $93,215 $79,800 $1,073 $80,873 $87,780 $2,298 $90,078 $93,100 $2,298 $95,398 $1,165,080 $12,027 $0 |$106,400 $33,920 $28,824 $43,656 $1,389,907 TOTAL MWH REVENUE $1,389,907 O&M BUDGET FY 01 $1,292,797 DIFFERENCE $97,110 Alaska Intertie FY 01 Usage Projections 42400.xIs 4/25/00 MINIMUM INTERTIE T FISCAL YEAR 2001 SFER CAPABILITY RIGHTS (MITCR)DETERMINATION FOR O |_| Annual System Demand 97-98 98-99 99-00 3 YR AVE. APPROVED APPROVED AML&P 149.0 151.0 150.0 150.0 |[MW 5/20/99 | CEA 220.4 231.1 230.1 227.2;MW UNITS FY 01 FY 00 AEG&T 176.6|MW HEA 74.8 77.1 79.2 USEAGE KWH 405,645,000 183,960,000 MEA 93.1 103.8 101.7 BUDGET $1,292,797 $1,027,560 MITCR KW 140000 140000 TOTAL 553.8 |MW ENERGY $.000/KWH $0.00266 $0.00466 NORTHERN UTILITY PARTICIPANTS (MW)ENERGY 0.266 cents 0.466 cents FMUS CAPACITY $/KW $1.52 $1.21 GVEA 168.8 175.5 182.0 175.4;MW TOTAL 175.4;|MW MITCR DETERMINATION FY 01 AEG&T 31.88%22.319 |MW AML&P 27.09%18.961 |MW {CEA}08%28.720)MW FMUS 0.00%0.000 {MW GVEA 100.00%70.000 a | 140.00 |MW AFMITR2001.xIs 4/25/00 INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 1 of 8 O ALASKA INTERTIE OPERATING COMMITTEE MEETING MINUTES THURSDAY,JANUARY 20,2000 AEESP Board Room Present:- Bob Day,Chair Anchorage Municipal Light &Power s Hank Nikkels Anchorage Municipal Light &Power fant Stan Sieczkowski Alaska Energy Authority ie John Cooley Chugach Electric Association,Inc. Ray Morgan Matanuska Electric Association Bob Drake Matanuska Electric Association Don Stead Homer Electric Association O The meeting of the Alaska Intertie Operating Committee was called to order at 10:00 a.m. Chair Day advised that per the 1985 agreement,election of officers was supposed to be conducted at the first meeting in January of each year.However,he noted that election of officers has been conducted at the annual March meeting in recent years. <After brief discussion,there was a consensus of the Committee to hold election of officers at the next meeting. I.ADOPTION OF PRIOR MEETING MINUTES A.August 24,1999 MOTION:Mr.Cooley moved to approve the minutes of the August 24, 1999,meeting.Seconded by Mr.Sieczkowski.There being no objection,the August 24,1999,meeting minutes were approved as presented by unanimous consent. Il.APPROVAL/MODIFICATION OF AGENDA Chair Day added "Reporting Mechanism for Outages"to the agenda as Agenda©Item V1.1.The Committee concurred. O INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 2 of 8 CooleyMOTION:Mr.moved to approve the agenda as revised. Seconded by Mr.Sieczkowski.There being no discussion,a voice vote was taken,and the motion was unanimously approved. COMMITTEE REPORTS AND CORRESPONDENCE A.Dispatch Subcommittee Mr.Evans was not present,and there was no report from the Dispatch Subcommittee. Chair Day noted that the spinning reserve issues would be discussed during the work session. B._Reliability/Protection Subcommittee There was no report from the Reliability/Protection Subcommittee. C.Machine/Rating Subcommittee Chair Day reported that the Machine/Rating Subcommittee had met in November and toured Chugach Electric's fuel cell facility at the airport.He said they had discussed a number of issues,including standards for devices that would provide interconnectivity to the utility.He said Gilbert had reported that Chugach had been working on the standards issue internally.Mr.Cooley added that the Subcommittee had also reviewed and updated the handbook.Discussion was heard regarding the standards. D.SCADA/Metering/Communications Subcommittee There was no report from the SCADA/Metering/Communications Subcommittee. E.Budget Subcommittee Mr.Sieczkowski reported that the Budget Subcommittee had not met since the last IOC meeting.He said the financial report he had distributed today would be discussed during the work session.Mr.Sieczkowski said he would be scheduling a meeting of the Budget Subcommittee in the near future for the primary purpose of reviewing and verifying bills. INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 3 of 8 O F.Maintenance Subcommittee There was no report from the Maintenance Subcommittee. G.__Intertie Status Report There was no intertie status report. In response to a question,Chair Day stated that the snow monitoring equipment was still out of commission. Chair Day noted that there had been an outage on the intertie at Tower 241 up by Gold Creek which had lasted for a couple of days.He said helicopter surveillance had revealed that static wires were the cause of the outage. Mr.Cooley gave a chronology of the events leading to the outages,and discussion was heard. H.Correspondence Received O Mr.Sieczkowski reported that he had received a note from the Chair requesting information regarding election of officers and _utility representation on the IOC and subcommittees.Chair Day briefly addressed the status of his request for information.In particular was the issue of FMUS's representation vis-a-vis Golden Valley's ability to have two votes on the Committee.Chair Day recapped his org chart that was contained in the meeting packet.Discussion was heard regarding which representatives and utilities have a vote on the IOC. Chair Day said Randy Johnson had developed a pilot web site for the purpose of reporting information so that everyone with an interest would have equal and immediate access to it.He said if there was enough interest in the project,a proposal which reflects the cost of developing and maintaining such a web site would be developed and presented to the Committee.Discussion was heard regarding who would design,develop, host,and maintain the web site. <There was a consensus of the Committee that the proposal should be prepared for presentation to the IOC. There was no other correspondence. O IV.VISITORS'COMMENTS RELATED TO ITEMS ON AGENDA O O INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 4 of 8 Vi. There were no visitor comments. RECESS There was a consensus of the Committee to defer the recess and continue working on through to the end of the meeting. WORK SESSION A.Dispatch Subcommittee 1)Spinning Reserves Issues Chair Day said there were multiple points of view on the issue of spinning reserves,but as they begin to look at independent power producers and other significant resources coming on line,they need to address the assessment and allocation of pro rata shares of spin requirement based on the actual usage of the various users.Chair Day distributed a proposal from the General Manager of ML&P,and he addressed the inequities that result from the contract governing the allocation of spinning reserves despite the physical reality of how the electrical system is structured.He explained the concept for determining spinning reserve outlined in the General Manager's proposal,and discussion was heard. In response to a question,Chair Day said this issue had been reviewed by an attorney,and upon counsel's advice,they felt a resolution to the contract that was passed by the IOC to clarify the language in Addendum 1 would be sufficient to implement the proposal.He said the |OC members would need to discuss it and have it approved by their various managers and/or boards before presenting a resolution to the 1OC for adoption. General discussion was heard. B._Reliability/Protection Subcommittee There were no issues for discussion on this item. C.Machine/Rating Subcommittee O INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 5 of 8 1)Joint Maintenance Labor and Spare Parts Agreement Update Mr.Nikkels said they were still working on some of the joint maintenance issues.He said one thing they were supposed to do was share a list of current contractors and consultants who provide various services related to the power plant.He said they are still in the process of implementing the Spare Parts Agreement. With respect to the agreement,Mr.Nikkels said the person at ML&P who would sign the agreement did not have the authority.He said it would be ML&P's preference to implement a blanket agreement that would be reciprocal with the other utilities. D.SCADA/Metering/Communications Subcommittee 1)Bradley Lake ICCP Mr.Day said there were a number of tasks to be assigned to the Bradley Lake ICCP. pine A PA areest Ine Chair asked if he had anything to reportunderAgendaItemIIL.A.,Committee Reports and Correspondence -Dispatch Subcommittee.Mr.Morgan said the Dispatch Subcommittee had met,but he had no report. E.Budget Subcommittee FY '99 Budget 1)FY 99 Fourth Quarter Report Mr.Sieczkowski said the financial report had been distributed to the Committee members.He said he could respond to questions,or anyone with questions could call him or Elaine.He said he would be scheduling a Budget Subcommittee meeting within the next two weeks. F.Maintenance Subcommittee .zk1)Quarterly Maintenance Reports oll At 4 (be (Mr.Cooley reported that the Maintenance SQhaemrftte has been meeting on the first Friday of each month.He said he had faxed a list to everyone,and he briefly recapped some of the items on the list. INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 6 of 8 O Discussion was heard regarding the status of maintenance at specific locations. G.Alaska Intertie Trip Report Discussion was heard regarding a report of a recent under-frequency load shed at MEA and other outage issues. H.[OC Legal Issues Chair Day said the only possible legal issue was the IOC voting membership.Mr.Cooley said they needed to get a copy of the signed Golden Valley assignment agreement from FMUS.Mr.Sieczkowski recommended that the Chair write a letter to Golden Valley requesting clarification of the legal issues pertaining to this matter.Discussion was heard. Mr.Sieczkowski advised the Committee that MEA had reactivated its lawsuit against AEA regarding the wheeling charge issue.He reported thatOMEA's attorney had presented oral argument the previous day regarding the recent claim.Mr.Sieczkowski said he would like to meet with ML&P and Chugach following the meeting today so he could provide them with a draft document regarding the lawsuit.He said he had been advised that the draft document was not to be provided to AEG&T,MEA,or HEA. I.Reporting Mechanism for Outages There was no discussion on this item. VIL.FORMAL OPERATING COMMITTEE ACTIONS/RECOMMENDATIONS A.Action on the Letter From the ML&P General Manager Regarding Assessment and Allocation of Spinning Reserves Chair Day asked that the Committee acknowledge their interest or disinterest in further consideration of the ML&P General Manager's proposal for the assessment and allocation of spinning reserves.Action No. 00-002 <There was a consensus of the Committee that the members would present the proposal letter to their utility representativesOforfeedbackatthenextIOCmeeting.Chair Day said it should INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 7 of 8 be included in the next meeting's agenda. VIII.SUBCOMMITTEE ASSIGNMENTS A.Dispatch Subcommittee 1.|Review the ML&P General Manager's spinning reserves proposal and present their findings and recommendations to the IOC at its next meeting. B._Reliability/Protection Subcommittee 1.Review implementation of the re-closure scheme C.Machine/Rating Subcommittee 1.Continue work on present projects. D.SCADA/Metering/Communication Subcommittee 1.Conduct regular quarterly meetings and begin addressing the issues contained in the August 24th,1999,meeting minutes. 2.Review the status of electronic data-sharing since the transition to the new SCADA systems. E.Budget Subcommittee 1.Continue work on present projects. F.Maintenance Subcommittee 1.Continue work on present projects. IX.AGENDA FOR NEXT MEETING The next meeting was scheduled for Thursday,March 30,2000,at 10:00 a.m.at Golden Valley. INTERTIE OPERATING COMMITTEE Thursday,January 20,2000 MEETING MINUTES Page 8 of 8 Chair Day said the spinning reserves issue would be included in the next meeting's agenda. X.ADJOURNMENT MOTION:Mr.Sieczkowski moved to adjourn. There being no objection and no further business of the Committee,the meeting was adjourned. APPROVED: Chairman of |lOC ) Date O Mitcr99.xls 04/25/2000 CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska Determination of Minimum Intertie Transfer Capability Rights 1999/2000 System Peak:12/15/99 @ Hour Ending 19:00 Hourly AEG&T Utility 18:15 18:30 18:45 19:00 Average MEA 101.9 101.5 101.8 101.7 101.7 HEA 79.5 79.3 78.8 79.2 79.2 180.9 Chugach Electric System Peak 411.0 Less:AEG&T Coincident Peak 180.9 Total (MW)230.1 1998/1999 System Peak:02/04/99 @ Hour Ending 19:00 Hourly AEG&T Utility 18:15 18:30 18:45 19:00 Average MEA 103.3 104.0 103.8 103.9 103.8 HEA 76.7 76.9 77.4 77.4 77.1 180.9 Chugach Electric System Peak 412.0 Less:AEG&T Coincident Peak 180.9 Total (MW)231.1 1997/1998 System Peak:01/05/98 @ Hour Ending 19:00 Hourly AEG&T Utility 18:15 18:30 18:45 19:00 Average MEA 93.0 92.4 93.6 93.2 93.1 HEA 75.3 74.9 74.8 74.3 74.8 167.9 Chugach Electric System Peak 388.3 Less:AEG&T Coincident Peak 167.9 Total (MW)220.4 CALCULATION OF MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS ML&P Peak Demands: 1997 149 1998 151 1999 150 Average Last 3 Years 150 Usage: 2000 None 1999 January 39 MWh May 38 MWh 1998 August 143 MWh INTERTIE FY2000 we |STATUS REPORT REVENUES GVEA MLP CEA AEGT INTEREST TOTAL REVENUES EXPENSES FERC 561 -Load Dispatching GVEA Northern Controller MLP Southern Controller AFI Other FERC 562 -Station Operation Expenses GVEA-substation electricity usage FERC 563 -Overhead Line Expenses GVEA -Weather monitoring equipment O FERC 565 -Transmission of electricity by others MEA Wheeling -Holly Rd to Douglas FERC 566 -Miscellaneous transmission expense SCADA &voice circuits (GOA) Cell phones for weather monitoring Weather monitoring maint (batteries) 4!11/00/5:15 PM FY2000 BUDGET BUDGET ACTUALS APPROVED YTD YTD OVER 5/20/99 2/29/00 4/5100 (UNDER) 563,280 340,357 |994,662.86 654,306 22,920 22,920 22,920.00 0 34,541 34,541 34,541.00 0 34,134 32,222 44,854.80 12,633 5,838.77 5,839 654,875 430,040 |1,102,817.43 672,777 -0 -0 -0 0 0 :0 7,500 5,000 3,377.40 (1,623) 7,500 5,000 3,377.40 (1,623) 220,000 146,667 |145,816.00 (851) 220,000 146,667 |145,816.00 (851) 32,000 21,333 76,394.08 55,061 32,000 21,333 76,394.08 55,061 199,600 133,067]158,848.83 25,782 10,000 6,667 3,135.01 (3,532) 20,000 13,333 (13,333) 229,600 153,067 |161,983.84 8,917 Page 1 NOTES: Billed through 2/29/00. Billed through 2/29/00. Billed through 2/29/00. Billed through 2/29/00. Repo interest thru 2/29/00. Paid through 2/00. Paid through 2/00. Paid through 2/00. Paid thru 3/00. Paid through 2/00. h:all\elaine\alaska intertie\ file:FY2000AKI.xIs\ws:FY2000 AKI BR 0400 A NTERTIE FY2000 BUDGCT STATUS REPORT FERC 567 -Transmission Expenses -Rents Rents -Alaska Railroad MEA-Talkeetna Siorage O GVEA -Healy Cantwell,Goldhill CEA Teeland Substation MEA -Douglas substation Extraordinary maint -GVEA Extraordinary main -CEA -CB &Transfor Extraordinary maint -MEA-batteries FERC 570 -Maintenance of station equipment FERC 571 -Maintenance of overhead lines Maintenance of Overhead Lines -Other GVEA Northern Maintenance MEA Southern Maintenance Weather monitoring equipment maintenan GVEA-Landing Pads GVEA-Tighten Guys GVEA-Northern ROW clearing MEA-Southern ROW clearing FERC 920 -AEA Administrative Costs Personal Services,travel and other costs FERC 920 -!OC Administrative Costs Legal Expense IOC -Gen Prof Services 4/11/00/5:15 PM FY2000 BUDGET BUDGET ACTUALS APPROVED YTD YTD OVER 5/20/99 2/29/00 4/5100 (UNDER) 600 400 500.04 100 7,200 4,800 4,800.00 0 7,800 5,200 5,300.04 100 64,828 43,219 32,937.05 (10,282) 10,000 6,667 48,600.77 41,934 10,000 6,667 56.12 (6,611) 0 0 -0 0 0 -0 0 0 -0 84,828 56,552 81,593.94 25,042 0 0 10,092.66 10,093 61,132 40,755 41,076.40 322 31,500 21,000 45,478.67 24,479 60,000 40,000 18,067.28 (21,933) 45,000 30,000 -(30,000) 30,000 20,000 -(20,000) 20,000 13,333 2,264.80 (11,069) 25,000 16,667 (3,925.09)(20,592) 272,632 181,755 |113,054.72 (68,700) 60,000 40,000 24 452.83 (15,547) 60,000 40,000 24,452.83 (15,547) 25,000 16,667 7,978.10 (8,689) 0 0 -0 25,000 16,667 7,978.10 (8,689) Page 2 ARR Permit fee prepaid for 1 year. Billed thru 2/00. Includes $12,346 of FY99 invoices. Billed thru 2/00. No GVEA maint bill since 12/98. Dryden $6,289 Evaluate and design repairs for Structures 274 and 297,CEA $2,571 snowload &line patrol. Includes $19,950 of FY99 invoices. Billed through 1/00. Billed through 2/00. Includes $1,102 of FY99 invoices. FY99 Accrual reversal Billed thru 1/00. h:all\elaine\alaska intertie\ file:FYZQ00AKI.xIs\ws:F¥2000 AKI BR 0400 X)INTERTIE FY2000BUULGETSTATUSREPORT FERC 924 -Property Insurance AF Intertie -Insurance Risk Management Fee TOTAL EXPENSE 4111/00/5:15 PM SURPLUS (SHORTAGE) O FY2000 BUDGET BUDGET ACTUALS APPROVED YTD YTD OVER 5/20/99 2/29/00 4/5/00 (UNDER) 82,000 82,000 81,181.42 (819) 6,200 6,200 1,215.00 (4,985) 88,200 88,200 82,396.42 (5,804) 1,027,560 714,440 |702,347.37 (12,093) (372,685)(284,400)|400,470.06 684,870 Page 3 h:all\elaine\alaska intertie\ file:FY2ZO00AKI.xIs\ws:FY2000 AKI BR 0400 4/1 1/00/5:16 PM ALASKA INTERTIE FY2000 REVENUES MWH ACTUAL USAGE Jul-99 Aug-99 Dec-99 MWH GV .; 4s 35,671 {YTD.VARIANCE MLP ; ==.«©° CURRENT VARIAN CEA .>°.° |CURRENT VARIANCE ACTUAL REVENUES Sep-"99 Oct-99 Nov-99 _Dec-99 Jan-00 Feb-00 -Rate per MWH 4860.$cc,4.060 | GVEA Energy Charges $97,953 $46,362 $$4,545 $70,455 $126,030 $166,227 $175,011 $173,380 GVEA Capacity Charges $84,700 YTD Actuals $182,653 $229,016 $283,561 $354,015 $480,045 §$646,272 $821,283 $994,663 #,.YTD Variance Spar ecg $&$pS eis ¢83,888.55 $vive 197,938 $56 95:340,868 $9 492,576.$5 ss 654,3065 MLP Energy Charges $°$:$-$-$©$©$-$° MLP Capacity Charges $22,920 YTD Actuals $22,920 $22,920 $22,920 $22,920 $22,920 $22,920 $22,920 $22,920 iu¥TOVariance.fa dik ic a8 abies ie atide CEA Energy Charges $°$-$:$°$.$°$-$- CEA Capacity Charges $34,541 YTD Actuals $34,541 §$34,541 §$34,541 $34,541 §34,541 §34,541 §$34,541 AEG&T Energy Charges $3,942 $3,933 $3,905 $1,533 $°$2,102 $1,906 $294 AEG&T Capacity Charges $27,240 YTD Actuals $34,182 $_35,415 $39,020 $40,554 $40,554 §42,655 $44,561 $ i.YTD,Variance s.r cic SOTS MO,643,.0,$sie 1 1,894 3 $cc40,662 58 20 5,291,832),$92,806 S54 TOTAL ENERGY CHARGES $101,896 $50,295 §$58,450 $71,988 $126,030 $168,329 $176,917 $173,674TOTALCAPACITYCHARGES$169,401 $- $- §$- $- $- §- $: _Y7TD TOTAL REVENUES $271,297 $321,592 $_380,042 $578,060 §$746,388 §$923,305 $1,096,979 a TAL.VARIANC 483,32 O27 $os 208,600...$952,697:$s.605,382:$.0 5 666,939) Page 1 hiall\elaine\alaska intertie\ file:FY2000AKI.xls\ws:Revenue Variance Report 0400 O MEMBERS COMMITTEE MEMBERS INTERTIE OPERATING COMMITTEE Bob Day John Cooley Bob Drake Brad Evans Don Stead Stan Sieczkowski DISPATCH SUBCOMMITTEE UTILITY PHONE Brad Evans Doug Hall John Cooley Ray Morgan Don Stead 263-5295 762-4540 761-9383 451-5655 235-3336 269-3024 451-5655 263-5453 762-4789 761-9318 235-3336 January 20,2000 Chairman Vice Chairman Secretary Chairman RELIABILITY/PROTECTION SUBCOMMITTEE Luke Sliman Larry Hembree Ray Morgan Doug Ritter 762-7602 263-5243 235-3303 761-9318 451-5658 MACHINE RATING SUBCOMMITTEE Steve Gilbert Alex Gajdos Hank Nikkels Bob Zacharsky Stan Sieczkowski 762-4446 451-5654 263-5329 235-3304 269-3024 Chairman Chairman ALASKA INTERTIE OPERATING COMMITTEE FDUMMRC2A SCADA/METERING/COMMUNICATION SUBCOMMITTEE Mary BattenSmith Paul Johnson Ray Morgan BUDGET SUBCOMMITTEE GVEA ML&P CEA HEA MEA Stan Sieczkowski John Cooley Brent Johnson Bob Drake Brad Evans AEA CEA ML&P MEA HEA GVEA 451-5655 263-5263 762-4447 235- 761-9318 269-3024 762-4789 263-5413 761-9283 235-3303 451-5655 MAINTENANCE SUBCOMMITTEE Monte Ervin Doug Hall Paul Rissee Stan Sieczkowski Bob Drake Jim Husky GVEA ML&P CEA AEA MEA HEA 451-5686 263-5453 762-7661 269-3024 761-9283 235-3303 Chairman Chairman Chairman kk Municipal Light &Power GENERAL MANAGER 1200 East First Avenue €nchorage Alaska 99501-1685 phone 907.263.5201 fax 907.263.5204 email Ov [|P A Lt Tt Y Oo F f N €H O R A G E Rick Mystrom =Mayor January 20,2000 \ Ow, Alaska Electric Generation and Transmission Cooperative ayChugachElectricAssociation Golden Valley Electric Association NTHomerElectricAssociationvMatanuskaElectricAssociation& Fairbanks Municipal Utility System Alaska Energy Authority Re:Responsibility for Spinning Reserves under the Intertie Agreement Gentlemen: For some time,ML&P has been providing more than its fair share of spinning reserves for the Railbelt.This disproportionate allocation of spinning reserve obligations can only lead to contention and litigation.It is in the interests of all Utility Participants in the Intertie Agreement that the responsibility for spinning reserves be assigned in a manner that is equitable to all. When the Intertie Agreement was being finalized,five Utility Participants owned and operated the generating resources and maintained operating (including spinning)reserves. It was anticipated that the Utility Participants would continue to operate in this manner. Under such circumstar he apportionment of obligations for spinning reserves based on a single unit for each ,.uerating utility produced reasonable results.Spinning reserve obligations were typically apportioned among the Utility Participants in approximately the following amounts: Retail Load Spin Obligation AEG&T (HEA)66.5 MW 14.0 MW Chugach (+MEA)260 MW 32.7 MW FMUS 22 MW 6.7 MW GVEA 88 MW 20.0 MW ML&P 148 MW 36.7 MW Seward 8 MW 0 MW Since the Intertie Agreement was signed,many of the Utility Participants have materially altered the manner in which generating resources are used to serve their retail loads.This has resulted in claims that the contractual relation of a Utility Participant to generating resources controls the amount of spinning reserves they are obliged to provide.As a consequence,even though the same generating resources are serving load today as were in service in 1985,there has been a substantial shift in the responsibility for spinning reserves among the Utility Participants.For example,during 1998 spinning reserves were provided approximately as follows: O IOC Participants January 20,2000 Page 2 of 2 Retail Load Spin Provided AEG&T (HEA)80 MW 0 MW Chugach (+MEA)290 MW 40 MW FMUS 26 MW 0 MW GVEA 171 MW 25 MW ML&P 138 MW 45 MW Seward 8 MW 0 MW This distribution of responsibility for spinning reserves is inequitable,and is inconsistent with the intent of the Intertie Agreement.The changes in the electric utility industry since 1985,and the advent of non-utility generators,require that the apportioning of responsibility for spinning reserves be re-examined in light of current practices and likely future developments. To address these issues,attached to this letter is a proposal for an interpretation of Addendum No.1 which addresses both the equitable allocation of spinning reserves and the treatment of non-utility generating resources.It does so within the context of the existing language of Addendum No.1 by interpreting the phrase "utility system”to mean control area and by interpreting generation contingency on a utility system to mean all of the connected generation on the utility system.By doing so,it allocates the responsibility for spinning reserves based on generating resources that are integrated into one of the three control areas (CEA,GVEA and ML&P). Four things are accomplished by these changes.First,all generating resources that serve Railbelt load are taken into account in computing spinning reserve obligations,regardless of ownership.Second,non-utility generating resources are apportioned their fair share of spin,and are deprived of a free ride at the expense of the Utility Participants.Third,the incentive to play contractual games to reduce spinning reserve obligations is eliminated. And fourth,the utilities with the responsibility for meeting loads minute to minute are vested with the responsibility to ensure that the generating resources in their control areas are providing adequate spinning reserves to support the system. The time has come to address the issue of responsibility for spinning reserves in a forthright and equitable manner.I strongly suggest that we work together to eliminate these inequities as soon as possible. Sincerely, Vere ooQvMeeraKohler General Manager ATTACHMENT 1 PROPOSAL FOR APPORTIONING SPINNING RESERVES UNDER ADDENDUM NO.1 Spinning Reserve obligations for the Intertie System will be determined pursuant to Section B-2.2.1.1 of Addendum No.1,using the generating unit with the largest generating unit capability in operation on the interconnected systems of the Utility Participants during each hour. .The generating unit capability for Operating Reserve Obligations will be calculated pursuant to Section B-2.2.2 of Addendum No.1,using the maximum amount of load (MW)that the unit is capable of continuously supplying for a two hour period.Such unit capability shall be determined for each unit on the interconnected systems prior to the start of each month,using the forecast average ambient temperature for such month in the zone in which the generating unit is located. .Operating Reserve Obligations apportioned pursuant to Section B-2.3.1 of Addendum No.1 will only be allocated to Utility Participants that operate a control area (CEA, GVEA and ML&P). .For purposes of calculating Operating Reserve Obligations pursuant to Section B- 2.3.1.1 of Addendum No.1,a Utility Participant will be interpreted to include only those utilities that operate a control area.The generating resources included in the calculation of the Operating Reserve Obligation for each such utility will include all generating resources that are integrated into the control area of such utility,regardless of who owns,operates or receives the output from the generating resource. .The Operating Reserve Obligation of each Utility Participant shall be the product of the Operating Reserve Requirement of the intertie system multiplied by a ratio whose numerator is the total of the generating capacity integrated into the Utility Participant's control area,and whose denominator is the total of the generating capacity integrated into the intertie system. .At the end of each month,the utilities that operate control areas will exchange information showing the generation units that were on line in their control areas during each hour of the preceding month.If any such utility has operated in any hour a generating resource with a larger generating unit capability than the resource declared by the utility as the largest resource to be operated in the next hour,the other two utilities that operate control areas will be entitled to reimbursement,pursuant to Section B-2.4.7.The reimbursement will be based on the difference between the Spinning Reserves they provided based on the generating resource declared by such utility and the amount of Spinning Reserves they would have provided had the other utility declared the larger generating resource that actually ran during the hour. O O ML&P Power Management Alaska Intertie,Southern Operator,Quarterly Reliability Report Web-Site Project Description November 3,1999 The Alaska Intertie Agreement contains standards for operation of the Alaska Intertie which include the production of a Quarterly Reliability Report by the Alaska Intertie Southern Operator which is submitted to the Intertie Operating Committee (IOC).As Southern Operator of the Alaska Intertie,it is the responsibility of ML&P Power Management to collect and summarize data for preparation of the |OC Quarterly Reliability Report.The lOC Quarterly Reliability Report summarizes system events that occur on the Alaska Intertied electric system. When system events occur on the Alaska Intertied electric system that exceed certain IOC guidelines,the participants in the Alaska Intertie Agreement,the intertied utilities,collect data on those system events.Using this data,ML&P Power Management produces the lOC Quarterly Reliability Report for submission to the IOC. Current System: The database for producing the |OC Quarterly Reliability Report is currently maintained in an Excel format. System event data is collected by each intertied utility and entered into a spreadsheet at the individual utility dispatch centers.It is then either faxed or e-mailed to ML&P Power Management where the data is again entered into a spreadsheet.Data is extracted from this spreadsheet to produce the IOC Quarterly Reliability Report. Disadvantages of Current System: This method of e-mail and faxes creates data entry at ML&P;in most cases,redundant data entry,which produces increased opportunity for entry error and/or misplaced data sheets.Once the data is entered into the Excel spreadsheet,it is cumbersome to do sorts, searches,summaries,and reports.As well,since the other intertied utilities do not have access to the compiled data,any inquiries they have must be processed through ML&P staff. Because of the cumbersome,inconvenient,and time consuming nature of this system,the event can become stale/old news before the data collection process is completed.The more "stale”the data becomes,the less likely the event data collection process will be completed.In general,this process is inefficient,inconvenient,and time consuming for ML&P staff as well as the other intertied utilities'staff. ML&P Power Management Alaska Intertie,Southern Operator,Quarterly Reliability Report Web-Site Project Description November 3,1999 Page 2 Proposed Web-site System: ML&P would like to build a secured,limited access web-site which would be linked to an Access database.Each utility would be able to enter data directly into the database through an online Access entry form.The data would feed directly into the Access database.Reports Including the IOC Quarterly Reliability Report would be automatically created using queries and macros. Advantages of Proposed Web-site System: Simplification of data collection and entry for ML&P staff Elimination of redundant data entry and/or misplaced data sheets Elimination of need for multiple e-mails and faxes Direct entry of data into utility-specific data entry forms by each participating utility Reduction of error rate Reduction of time required for data entry/production of summaries and reports Direct access by each utility to compiled data for utility-specific reporting purposes Automated macros for building summaries and reports Expedient/Timely data collectiorr,analysis,and dissemination of data Convenient and easy to use Development of Proposed Web-site System: The following features would need to be developed in order to implement the proposed web-site system for producing the |OC Quarterly Reliability Report: e Database e Web Site with Limited Access to Utility-Specific Data Entry Forms and Report Production Capability Security Data Protection Software Product Specific Training Cost Savings Potential: In time savings alone this web-site system,for production of the 1|OC Quarterly Reliability Report,would more than pay for itself in less than a year. MUNICIPAL LIGHT &POWER POWER MANAGEMENT MEMORANDUMMEP DATE:May 25,1999 TO:10C Dispatch Subcommittee Members . FROM:ML&P,Southern Operator,Alaska Intertie SUBJECT:Quarterly Reliability Report,January Through March 1999 REF:Ref.General Managers Agreement,December 15,1994 This report is in two parts. PART 1 -EXECUTIVE SUMMARY 1.Atthe March 15,1995 meeting,the 1OC established by unanimous vote the reporting criteria to be used for the Quarterly Reliability Report as directed in the December 15,1994 Agreement. These are listed below: a.All events which cause frequency excursions greater than +or -.2 Hz. b.All unit trips,and trips of transmission lines or transmission facilities greater than 69 kV.c.Spinning reserve deficiencies which are in excess of 20%of a utility's requirement or SMWwhicheverislessforatleast3consecutivehoursformorethan2daysoranysystematic pattem of abuse. d.Any event which a Dispatch Subcommittee Member or 1OC Member determines should be investigated. PART 2 -EVENT SUMMARY 1.During this quarter there were no scheduled interruptions on the Alaska interconnected system. 2.During this quarter,the Kenai tripped open 2 times,for a total of 5 hours and 15 minutes. 3.During this quarter there were 35 reported disturbances caused by 29 unit trips,5 transmission line outages,and 1 from other causes.These disturbances resulted in 8 SILOS operations,2 Load Shed operations,and 12 Protective Relay operations. PAGE 1 January -March i99u PART 2 EVENT SUMMARY QTR.1 EVENT NUMBER NAMNaWN=1999 DATE TIME EVENT DESCRIPTION Quartz Creek Bkr 1036 trip Healy Unit t trip AML&P Unit 6 tripQuartzCreekBkr1036 trip Ft.Knox trip AML&P Unit 5 trip AML&P Unit 7 trip GVEA Healy Unit 2 trip AML&P Unit 7 trip AML&P Unit 1 trip AML&P Unit 4 trip Healy Unit 2 trip North Pole Unit 1 trip Healy Unit 1 trip Healy Unit 2 trip Healy Unit 1 trip Healy loses Mill,Then Healy Unit 2 trips Load Shed on restart of Healy Unit 2 Soldotna Bkr 246 lockout Healy Unit 1 trip CEA Beluga Unit §tripAMLPUnit§tripPeninsulaopened Healy Unit 2 trip Healy Unit 2 trip North Pole Unit 1 trip Healy Unit 2 trip Healy Unit 2 trip Healy Unit 2 trip AMLP Unit 2 trip Healy Unit 2 trip Daves Creek-University 115kV line trip Cooper Lake Unit 1 trip Healy Unit 2 trip Healy Unit 2 trip FREQUENCY EXTREME (Hz) 59.99 59.75 59.93 59.98 no data 59.87 §9.01 59.94 §9.25 59.90 59.71 59.35 59.40 59.75 59.76 59.80 59.56 60.22 59.97 59.90 59.65 59.76 60.26 59.95 59.81 59.28 59.53 59.93 59.32 59.89 59.85 59.85 no data 59.62 59.74 INTERTIE KENAI UNIT LINE LOAD OPENED OPENED TRIP TRIP ATTRIP SHED . LOAD SILOS OTHER RELAYS (Mw)xx=o>o>©o*x«KK27.70 no data mKmKKKKOKOKKOKOKnN™<<15.20 27.90 x x 32.20 x 18.00«KKxXxKKOKOOKgxxCOMMENTS Bkr 1036 trip 69kV,to open Bkr 146 at Soldonta Electrical problems Gimpile valve problem Bkr 1036 trip 69kV,to open Bkr 146 at Soldonta Cause unknown,Ft.K drops 10MW Bearing oil supply high temp Cause unknown,AMLP Load Shed 3.2MW,GVEA SILOS 15.1MW,ULF.7.4MW,Other Relays 1.1MW. Cause unknown Cause unknown,GVEA SILOS 31.8 MW,Other Relays 6.3MW Control problems Control problems,GVEA shed 0.9 MW on Other Relays 0.9MW Cause unknown,GVEA SILOS 8.3MW,Other Relay 1.2MW Cause unknown,GVEA shed Other Relays 1.2MW Trip due to F.D.fan trouble No automatic drum level control,drum level tripped unit Fault on 24.9 system,Unit trips,GVEA sheds 3.2MW Other Relays Plant -throttle control problems,GVEA shed Other Relays 1.2MW Load Shed saw an open Generator Bkr.,GVEA Load Shed 24.9MW Cause unknown Mill loaded then unloaded,lost seal air fan Cause unknown,GVEA SILOS 6.5MW,Other Relays 1.2MW Cause unknown Daves Creek 826-University 2002 tripped,nothing found Open 3hrs 56min. Cause unknown Cause unknown Fire in load tunnel,GVEA SILOS 30.1MW,Other Relays 1.5 Cause unknown GVEA SILOS 3.0MW,Other Relays 1.2MW Cause unknown Cause unknown,GVEA SILOS 2.9MW,Other Relays 30.6MW Unit trip during testing Cause unknown Avalanche at mile 60.No line damage.line placed back in service Unit trip after Kenai islands.Open 1 hr.19min. Caused by slag fall in fumace area.GVEA SILOS 11.7MW, Other Relays 1.1 Slag fall and fan trouble control MUNICIPAL LIGHT &POWER POWER MANAGEMENT MEMORANDUMMEP DATE:November 16,1999 TO:1OC Dispatch Subcommittee Members FROM:ML&P,Southem Operator,Alaska Intertie SUBJECT:Quarterly Reliability Report,April Through June 1999 REF:Ref.General Managers Agreement,December 15,1994 This report is in two parts. PART 1 -EXECUTIVE SUMMARY 1.Atthe March 15,1995 meeting,the lOC established by unanimous vote the reporting criteria to be used for the Quarterly Reliability Report as directed in the December 15,1994 Agreement. These are listed below: a.All events which cause frequency excursions greater than +or -.2 Hz. b.All unit trips,and trips of transmission lines or transmission facilities greater than 69 kV. Cc.Spinning reserve deficiencies which are in excess of 20%of a utility's requirement or SMWwhicheverislessforatfeast3consecutivehoursformorethan2daysoranysystematic pattern of abuse. d.Any event which a Dispatch Subcommittee Member or [OC Member determines should be investigated. PART 2 -EVENT SUMMARY 1.During this quarter there were 2 scheduled interruptions on the Alaska interconnected system. 2.During this quarter,the Intertie tripped open 1 time. Healy B-12 trip,Healy SVS trip.Cause unknown.GVEA shed 3.4 MW,other relays. 3.During this quarter there were 43 reported disturbances caused by 30 unit trips,4 transmission line outages,and 3 other causes.These disturbances resulted in no Load Shed operations,9 SILOS operations,and 5 Protective Relay operations. PAGE 1 April -June 1999 PART2 EVENT SUMMARY QTR.2 1999 :ere EVENT EVENT FREQUENCY INTERTIE KENAI UNIT LINE LOAD LOAD SILOS OTHER COMMENTS NUMBER DATE TIME DESCRIPTION EXTREME OPENED OPENED TRIP TRIP ATTRIP SHED RELAYS (Hz)(MW) 36 17-Apr 22:16 Healy Unit 2 trip §9.28 NO NO x 57.80 xX Cause unknown GVEA SILOS 3.3MW,Other Relays 30.7 37 18-Apr 06:48 Healy Unit 2 trip 59.67 NO NO x 24.70 Cause Unknown 38 19-Apr 12:58 CHS B1 and CHS B13 trip 59.98 NO NO x Cause unknown 39 21-Apr 07:10 Healy Unit 2 trip 59.37 NO NO x 58.00 x Furnace draft problem,GVEA SILOS 2.6MW,Other Relays 32.8MW 40 22-Apr 03:02 CHS 1B13 Open 59.97 NO NO x Open on high voltage relay,no load lost 41 24-Apr 10:39 Healy Unit 2 trip 59.18 NO NO x 57.90 x Cause unknown,GVEA SILOS 2.3MW,Other Relays 30.7MW 42 01-May 2:01 North Pole Unit 2 trip §9.08 NO NO xX §1.30 x Cause unknown,GVEA SILOS 22.5MW,Other Relays 1.2MW 43 07-May 9:24 CEA Belagu #3 230kV line trip 59.92 NO NO x Contamination on insulator string,B phase 14 miles from Beluga4411-May 13:19 AMLP Unit 6 trip 59.92 NO NO x 40.50 High drum level 45 12-May 14:49 AMLP Unit 6 trip 59.91 NO NO x 5.20 High drum level 46 14-May 11:00 Healy Unit 2 trip 59.90 NO NO Xx 5.60 Cause unknown 47 17-May 5:24 Douglas B1 open,C phase fault 60.10 YES NO x 0.40 C phase fault 10.5 miles north of Teeland Sub 48 17-May 7:26 Healy Unit 2 trip 59.60 NO NO x '32.00 x Cause unknown GVEA SILOS 5.0MW 49 17-May 16:44 Ft.Knox trouble 59.77 NO NO Cause unknown,frequency drop5019-May 8:05 AMLP Unit 7 trip 59.11 NO NO x 52.80 x Loss of instrument air,GVEA SILOS 9.4¢MW 51 19-May 20:40 Bradley Lake Load Rejection Test 59.90 NO NO x 11.40 Load RejectionTesting 52 19-May 21:11 Bradley Lake Load Rejection Test .59.78 NO NO x 29.60 Load RejectionTesting 53 19-May 21:36 Bradley Lake inadvertent trip,Unit 1 §9.63 NO NO x 29.60 x Inadvertent emergency trip GVEA SILOS 3.1MW5419-May 22:17 Bradley Lake Load Rejection Test 59.79 NO NO "xX 29.60 Load RejectionTesting 55 19-May 23:09 Bradley Lake Load Rejection Test 59.64 NO NO x 50.00 Load RejectionTesting5620-May 0:09 Gradiey Lake Load Rejection Test 69.66 NO NO x 52.70 Load RejectionTesting §7 20-May 0:47 Bradley Lake Load Rejection Test 59.66 NO NO x 50.00 Load RejectionTesting 58 20-May 12:12 Bradley Lake Load Rejection Test 59.59 NO NO x Load RejectionTesting 59 20-May 12:51 Bradley Lake Load Rejection Test 59.28 NO NO x Ne 90.20 Load RejectionTesting6020-May 17:34 Bradley Lake inadvertent trip 59.63 NO NO xX '42.50 x Inadvertent emergency trip,GVEA SILOS 1.5MW 61 20-May 21:09 Healy Unit 2 trip 59.50 NO NO x 58.00 x Cause unknown,GVEA sheds 30.3MW on Other Relays6225-May 6:20 CEA Beluga Unit 8 trip-230kV line trip 59.48 NO NO x 45.30 Cause unknown 63 27-May 7:02 AMLP Unit §trip 59.84 NO NO x 18.20 Trip on high vibration 64 29-May 20:42 Healy Unit 2 trip §9.32 NO NO x 57.90 x 4 Slag drop,GVEA SILOS 14.7MW,Other relays Tie over load 1.2MW 65 03-Jun 11:27 Healy Unit 1 trip 59.80 NO NO x 25.20 x |.D.fan controler problem,which initiated a load shed due to a Intertie overload.GVEA Shed 15.7MW Other Relays 66 03-Jun 8:47 Bernice Unit 3 trip 59.83 NO NO x 16.00 SCADA locked up 67 09-Jun 6:43 AMLP Unit 6 trip 59.71 NO NO x 16.00 Cause Unknown 68 10-Jun 11:25.Intertie open,replace insulators Tower 43 §9.98 YES NO Schduled maintance,Closed 17:50 69 10-Jun 22:15 Bradly Lake Unit 1 trip 59.89 NO NO x Cause unknown 70 14-Jun 9:46 Intertie Open,Goldhill to Nenana 59.99 YES NO Schduled,replacing insulators 71 18-Jun 2:14 Beluga-MacKenzie #2 230kV line trip 59.76/60.19 NO NO x Wire down between structures 21/3 and 21/4 72 18-Jun 23:34 FT.Knox trip 59.77/60.18 NO NO Cause unknown 73 22-Jun =8:22,Bernice Unit 3 trip 59.88 NO NO x 10.50 Control voltage problem 74 22-Jun 11:56 Bernice Unit 3 trip 59.68 NO NO x 16.80 x Cause unknown,GVEA SILOS 11,.3MW 75 26-Jun 5:25 Healy B-12 trip,Healy SVS trip 59.89 YES NO x x Cause unknown,GVEA Shed 3.4MW Other Relays 76 27-Jun 17:50 Lightning in area,GVEA 60.30/59.70 NO NO Lightning 77 27-Jun 19.25 Lightning in area,GVEA 59.75/60.09 NO NO ;Lightning 78 30-Jun 14:15 Baxter-Debarr 34.5kV line trip 60.28 NO NO x Cause unknown MUNICIPAL LIGHT &POWER POWER MANAGEMENT MEMORANDUMMEP DATE:January 19,2000 TO:1OC Dispatch Subcommittee Members FROM:ML&P,Southern Operator,Alaska Intertie SUBJECT:Quarterly Reliability Report,July Through September,1999 REF:Ref.General Managers Agreement,December 15,1994 This report is in two parts. PART 1 -EXECUTIVE SUMMARY 1.Atthe March 15,1995 meeting,the 1OC established by unanimous vote the reporting criteria to be used for the Quarterly Reliability Report as directed in the December 15,1994 Agreement. These are listed below: a.All events which cause frequency excursions greater than +or -.2 Hz. b.All unit trips,and trips of transmission lines or transmission facilities greater than 69 kV. c.Spinning reserve deficiencies which are in excess of 20%of a utility's requirement or SMWwhicheverislessforatleast3consecutivehoursformorethan2daysoranysystematicpatternofabuse.- d.Any event which a Dispatch Subcommittee Member or |OC Member determines should be investigated. PART 2 --EVENT SUMMARY 1.During this quarter there were no scheduled interruptions on the Alaska interconnected system. 2.During this quarter,the Kenai tripped open 0 times. The Intertie tripped opened 3 times for a total of 1 hours and 35 minutes. 3.During this quarter there were 36 reported disturbances caused by 21 unit trips,13 transmission line outages,and 0 from other causes.These disturbances resulted in 13 SILOS operations,1 Load Shed operations,and 7 Protective Relay operations. PAGE 1 July -September 1999 PART2 EVENT SUMMARY QTR.3 1999 EVENT EVENT FREQUENCY INTERTIE KENAI UNIT LINE LOAD LOAD SILOS OTHER COMMENTS NUMBER DATE TIME DESCRIPTION EXTREME OPENED OPENED TRIP TRIP ATTRIP SHED RELAYS (Hz)(MW) 79 O1-Jul 11:36 Beluga Unit 6 trip no data NO NO x 56.20 x x GVEA Sheds,SILOS 19.1MW,Other Relays 1.1MW 80 01-Jul 11:45 CEA Cancels sales due to Beluga 6 trip 59.09 NO NO 'x GVEA sheds on Other Relays 17.9 Bt O1-Jul 13:16 Arctic Cs 3414 trip 60.12 NO NO x Inadvertant by workmen 82 03-Jul 21:40 GVEA North Pole Unit 1 trip 59.60 NO NO x 32.50 xX Bang,fire system dump,panel blown out GVEA SILOS 1.2MW 83 05-Jul 9:09 Beluga-MacKenzie #2 230kV line trip 60.01 NO NO x Cause unknown 84 08-Jul 16:21 Beluga Unit 3 trip 59.33 NO NO xX 56.70 x Cause unknown,GVEA SILOS 8.1MW 85 08-Jul =17:42 Beluga Unit 3 trip 59.14 NO NO x 42.80 x Differential relay and loss of excitation,GVEA SILOS 4.1MW 86 10-Jul 9:31 HLP Unit 1 trip 59.95 NO NO x 15.30 Cause unknown 87 13-Jul.17:10 AMLP Unit 7 trip 59.51 NO NO x Unit 7 backs off line then trips 88 13-Jul.17:36 Bradley Lake Units 1 &2 trip 59.30 NO NO x x Cause unknown,GVEA SILOS 3.3MW 89 14-Jul 3:06 +=AMLP #8 Trouble 260.00 NO NO Problem with Unit 8 Control System 90 18-Jul.23:37 HCC trip 59.78 NO NO x 20.00 Cause Unknown 91 20-Jul.=10:23.AMLP Unit 7 Trip no data NO NO x 69.00 AMPL Unit 7 Trip,Data Incomplete 92 28-Jul =8:26 +=AMLP Unit 6 Trip 59.66 NO NO x '24.60 x Lost Unit 7 Boiler,GVEA SILOS 4.9 MW 93 28-Jul 10:52 AMLP Unit 6 Trip 59.66 NO NO xX 24.20 x Modifications to Baily Controls,Lost MLP Unit 7 Boiler,GVEA SILOS 5.1 MW 94 30-Jul 6:55 Cooper 1 and 2 backed off line 60.00 NO NO xX 6.70 Event just before fault on Tower #60 between Douglas and Teeland B-Phase Ground Fault near tower 60,DGS-TLS 138 trip,Intertie opened at 95 30-Jul 6:55 Teeland-Douglas 138 Trip 60.69/59.00 YES NO xX x xX Teeland BKR 538 and Douglas 138-B1,GVEA SILOS 19.7 &UF Load Shed 96 30-Jul.=14:13.AMLP Unit 6 &7 Trip 59.27 NO NO x 63.50 x x GVEA SILOS 43.6 MW,Other Relays 16.7 MW 97 30-Jul =14:16 AMLP Unit 6 &7 backed off line 59.74 NO NO x 12.40 x GVEA SILOS 98 02-Aug 12:56 Eklutna #1  Trip-GV manually sheds loa <59.50/>59.00 NO NO x 32.70 x GVEA sheds on other relays 10.4 MW 99 03-Aug 15:17 HLS T7 Relayed out HLP 813,B12,B11 and 59.66 NO NO x 27.70 x x Gvea Sheds,Silos 12.6 MW,Other Relays 1.2 MW 100 08-Aug 2:17 Intertie Trip,B-Phase to Ground,Tower 64 60.27 YES NO x intertie opened at Douglas 138-81 and Teeland 538,Suspect Rain Storm 101 08-Aug 14:12 Beluga Unit 8 Trip 59.69 NO NO x 29.60 x No Load Shed in Anchororage Bowl,GVEA SILOS 2.0 MW 102 10-Aug 17:34 Douglas B41 Trip no data YES NO X x B-Phase to Ground Fault,GVEA sheds on other relays .6 MW 103 16-Aug 10:04 Beluga-Pt.McKenzie #2 230 Line Trip =60.00 NO NO x B-Phase to Ground,7.6 Mi.Beluga 33.2 Mi.From Pt.McKenzie 104 19-Aug 14:52 GVEA Lost Fairbanks Plant 59.80 NO NO x 105 20-Aug 10:04 Beluga-Pt.McKenzie #3 230 Line Trip =60.00 NO NO x B-Phase to Ground 106 25-Aug 14:10 Teeland-Douglas 138 kV Line Trip,B-Phase »60.00 NO NO x x x GVEA SILOS 6.9,Shed Load on other relays 3.9 MW 107 03-Sep 18:43 Soldotna-Diamond Ridge 115 Line Trip 60.00 NO NO x 108 11-Sep 0:23 HCC trip <59.50/>59.00 NO NO x.52.00 MLP Sub 14,Fdr 6 trip on UF Load Shed 109 17-Sep 1:31 Daves Creek 926 Tripped 260.00 NO NO x Seward Outage 6 MW 110 17-Sep 11:26 Daves Creek 926 Tripped 60.00 NO NO xX Seward Outage 8 MW 11 17-Sep 15:30 TLS 1010 Trip '260.00 NO NO x MEA Lost Load 112 20-Sep 19:09 Beluga Unit 8 Trip 59.80 NO NO x 21.30 113 21-Sep 0:30 Soldotna Diamond Ridge 115kV Line Trip 260.00 NO NO x 114 21-Sep 14:21 Bradley Unit 2 Trip 59.76 NO NO x -10.00 Reverse Power Relay MUNICIPAL LIGHT &POWER POWER MANAGEMENT MEMORANDUM MEP DATE:January 19,2000 TO:IOC Dispatch Subcommittee Members FROM:ML&P,Southern Operator,Alaska Intertie SUBJECT:Quarterly Reliability Report,October Through December,1999 REF:Ref.General Managers Agreement,December 15,1994 This report is in two parts. PART 1 --EXECUTIVE SUMMARY 1.At the March 15,1995 meeting,the IOC established by unanimous vote the reporting criteria to be used for the Quarterly Reliability Report as directed in the December 15,1994 Agreement. These are listed below: a.All events which cause frequency excursions greater than +or -.2 Hz. b.All unit trips,and trips of transmission lines or transmission facilities greater than 69 kV. c.Spinning reserve deficiencies which are in excess of 20%of a utility's requirement or SMWwhicheverislessforatleast.3 consecutive hours for more than 2 days or any systematic pattern of abuse., d.Any event which a Dispatch Subcommittee Member or IOC Member determines should be investigated. PART 2 --EVENT SUMMARY 1.During this quarter there were no scheduled interruptions on the Alaska interconnected system. 2.During this quarter,the Kenai tripped open 1 time,for a total of 5 hours and 15 minutes. The Intertie tripped opened 1 time for a total of 0 hours and 20 minutes. 3.During this quarter there were 18 reported disturbances caused by 13 unit trips,3 transmission line outages,and 0 from other causes.These disturbances resulted in 8 SILOS operations,1 Load Shed operation,and 6 Protective Relay operations. PAGE 1 Uvlovel -Veecinbet tyuy PART 2 EVENT SUMMARY QTR.4 EVENT NUMBER 1999 DATE TIME EVENT DESCRIPTION AMLP Unit 8 Trouble Bradley #1 trip GVEA lost 138kV Line,Healy to Goldhilll Bradley lake Trip CEA Splits Kenai Beluga-Pt Mackenzie #3 230 kV Line trip North Pole #1 Trip CEA Beluga #5 Trip CEA Beluga #5 Trip CEA Beluga #5 Trip CEA Beluga #5 Trip Ektutna 1 trip AMLP Unit 8 Trip Eklutna 1 Trip GVEA Unit 1 Trip HCC trip MEA opened TS200 at Stevens Sub Eklutna Plant Trip FREQUENCY INTERTIE KENAI UNIT LINE LOAD LOAD SILOS OTHER EXTREME OPENED OPENED TRIP TRIP ATTRIP SHED RELAYS (Hz)(MW) 59.83 NO NO 259.83 NO NO x 12.99 no data NO NO x x X xX §9.62 NO NO x 55.90 x §9.85 NO YES x x =60.00 NO NO x §9.62 NO NO x 49.90 x xX §9.39 NO NO xX 60.12 Xx x §9.14 NO NO xX 63.98 x xX <59.50/>59.00 NO NO x 60.18 x x 59.84 NO NO x 15.00 59.83 NO NO x *12.00 59.40 NO NO x 54.00 x Xx §9.85 NO NO x 12.00 §9.83 NO NO Xx 10.00 59.87 NO NO x 15.00 59.95 NO NO 59.88 NO NO x =10.00 oePane 2 COMMENTS #8 went into lean-lean neg.at 65 MWs,9 MWs of SILOS armed,Load 110 MW Camp Station Service Fire and Ground targets on 13.8 Bus,No Load Shed C-Phase Ground Fauit,Relays Open,GVEA SILOS 35.9,UF Load Shed 16.2, Other Relays 6.3 Gate closed at Inlet,GVEA SILOS 3.4 MW CEA Peninsula Line Tripped Open,GVEA SILOS 10.5 MW C-Phase to ground.Line patrol found nothing. Accidental trip by fire system inspectors,GVEA SILOS 3.2 ,Other relays 1.2MW GVEA SILOS 8.6 MW,Other Relays 1.2 MW GVEA SILOS 22.1 MW,Shed by other relays 1.3 MW GVEA SILOS 12.3 MW,shed by other relays 1.2 MW Unit 8 Control Problems,GVEA SILOS 5.2 MW,Other Relays 1.2 MW While work was being done on AMLP Unit 2,a circuit opened Unit tripped while being taken off line because of bad fuel pump Transducer Problem O O O ALASKA INTERTIE OPERATING COMMITTEE MEETING MINUTES TUESDAY,AUGUST 24,1999 ALASKA INDUSTRIAL DEVELOPMENT AND EXPORT AUTHORITY BOARD ROOM sent: Bob Day,Chair Municipal Light &Power John Cooley Chugach Electric Association,Inc. Brian Hickey Chugach Electric Association,Inc. Bob Drake Matanuska Electric Association Ray Morgan Matanuska Electric Association Brad Evans By Telecon Golden Valley Electric Association,Inc. Sam Matthews By Telecon Home Electric Association Stan Sieczkowski AIDEA/AEA Elaine McCambridge AEA Shauna Dean AEA The meeting of the Alaska Intertie Operating Committee was called to order at 10:00 a.m. I.ADOPTION OF PRIOR MEETING MINUTE A.May 20,1999 The following corrections to the May 20,1999,meeting minutes were noted: With respect to Item A.,Right-of-Way Clearing -MEA,on page6 of 8,it was clarified that some clean-up work remained to be done and the contractor would not be fully paid until that was completed,which would be when the ground freezes.It was noted that the job would still be within budget once the clean-up work had been accomplished.The third sentence was revised to read:"The majority of the work has been accomplished within budget." With respect to the first paragraph under Item 1.on page 5 of 8,Mr.Morgan asked how it had been determined that MEA had not met the commitments under which Stevens Sub was constructed.Discussion was heard regarding individual Committee members' recollections,and there was a consensus that the first sentence should be revised to read:"Many Committee members felt that MEA has not met the commitments under which Stevens Sub was constructed." Mr.Matthews advised that he had not received a copy of the May 20,1999 meeting minutes.The Chair directed Ms.Dean to fax Mr.Matthews a copy of the minutes. MOTION:Mr.Cooley moved to approve the minutes of the May 20,1999 meeting as revised.Seconded by Mr.Drake.There being no objection,the May 20,1999,meeting minutes were approved as amended by unanimous consent. Executary Court Reporting 2199AIDA.1OC:esc (10/28/99) O O INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 2 of 9 II.APPROVAL/MODIFICATION OF AGENDA It was proposed that the RCA presentation replace Agenda Item VI.H.as Item H.was supposed to have been omitted from this agenda.The Committee concurred. There were no further additions or corrections to the agenda,and it was adopted by unanimous consent as amended. Ih.MM REP ND CORRESPON A.Di h Subcommi Mr.Evans reported that the Intertie Assignment Agreement letters for FMUS were sent out by the City of Fairbanks in January of 1998 for approval signatures.He said Seward, ML&P,and AIDA have signed off;CEA,HEA,and AEG&T have not signed.He said he would follow up on this with Ron,and a copy would be faxed to the Committee members for review during the Work Session portion of the meeting. B._-Reliability/Protection Subcommitt There was no report from the Reliability/Protection Subcommittee. Chair Day advised that the Dispatch and Reliability/Protection Subcommittees still have not held a joint meeting to discuss several outstanding issues.He directed the two subcommittees to schedule a joint meeting for this purpose. C.Machine/Ratin mimitt Mr.Cooley reported that the Machine/Rating Subcommittee had met August 6,1999,in Kotzebue.He said Alex Gajdos,Hank Nikkels,and Steve Gilbert had attended that meeting.He briefed the Committee on some of the highlights of that meeting and noted that the draft minutes were contained in the meeting packets. D.ADA/Meterin mmunication mmitt There was no report from the SCADA/Metering/Communications Subcommittee. E.Budget Subcommittee There was no report from the Budget Subcommittee. F.Maintenance Subcommittee Mr.Evans said he would have Mo call Monte Irvin to see if there was any report on this item.There was a consensus of the Committee to defer this item until later in the meeting. G.-Interti Executary Court Reporting 2199AIDA.1OC:csc (10/28/99) INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 3 of 9 Mr.Evans said they had had an outage about a week ago and flipped some bundles.He reported that there had been several outages in the section between Douglas and MEA. He deferred to Mr.Morgan to provide the specifics of those outages. Mr.Morgan reported that there had been two trips the last week of July.The approximate locations were 14 miles north of Teeland and 12 miles south Douglas.He said they had patrolled by air twice and had done climbing inspections on several towers in that area but found nothing.He noted that there are still raptors nesting on Structure 64.He said it was his understanding the nests could be removed after the birds leave.Mr.Morgan said ospreys were nesting in the tower outside of Douglas but had never caused a problem.It was suggested that raptor barriers be installed on the problem structures. H.rr nden iv There was no correspondence. IV.VISITORS'COMME.ELA ITEM END There were no visitor comments. V.RECESS There was a consensus of the Committee to defer the recess until later in the meeting. O VI.WORK IONA.ispatch mmitt 1)Spinning Reserve Issues Mr.Day said they have been conducting a review of the legal contractual requirements for spinning reserves,and they have discussed initiating studies to determine appropriate technical requirements.He said the attorney's report regarding the legal contractual requirements had been received,but the Dispatch Subcommittee has not yet reached any conclusions on these issues.Mr.Day noted that these issues were interrelated with the FMUS Intertie Assignment Agreements discussed by Mr.Evans earlier. Mr.Evans said he had a copy of the Agreement,and it states that FMUS assigned its rights for the intertie to Golden Valley,but until the assignment has been approved by the other participants,FMUS had designated Mike Kelly or his designee to vote on City of Fairbanks rights issues under the Intertie Agreement. Mr.Evans reiterated that he would follow up to find out who had signed the Agreement and who had not. With respect to the switches at Stevens,Mr.Day said he had not yet talked with Vance Cordell regarding improving the functionality of the com link in and out of Stevens.Mr.Morgan reported that the modem in Chulitna is not functional,which isOwhyStevensisnotfunctional. Executary Court Reporting 2199AIDA.1OC:csc (10/28/99) O O INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINU Executary Court Reporting TES Page 4 of 9 Mr.Day advised that the old ML&P RTU needs to be removed.He said since they both use similar systems,they could share a single RTU with one channel,bring the channel back,and then split the channel.He said CEA's existing RTU would remain when the ML&P RTU was removed,and it would suffice as a shared RTU. He said the Taehas RTU was supposed to be configured with everyone's protocols. The Chair directed the Communications Subcommittee to meet to discuss the Stevens RTU. liability/Pr ion mmmitt 1)4th Stage Load Shedding Mr.Day summarized the issue on the 4th stage load shedding regarding the relay setting of 57.7 at Eklutna.He said this was an action item,and approval by the Intertie Operating Committee was required for the relay to be set at 57.7.He noted that it opens 362 and 462 for the purpose of plant isolation and generation protection.Discussion was heard regarding the 57.7 relay setting. Machine/Ratin ommi 1)Joint Maintenance Labor and Spare Parts Agreement Update Mr.Day said ML&P is continuing to review the legal aspects of the Joint Maintenance Agreement. ADA/Meterin mmunications Subcommitt 1)|Communications Reliability Mr.Day said continuation of past assignments for this subcommittee had been discussed earlier in the meeting.He added that scheduling a meeting of the subcommittee would be an action item later in the agenda. et Subcommittee FY!e 1)|FY 99 Fourth Quarter Report Mr.Sieczkowski distributed an updated budget.He noted that the final numbers were being compiled and another update would be forthcoming.He said he did not have a chance to fax this update to Messrs.Evans and Matthews,but he would send them the next update.Mr.Sieczkowski said the budget update distributed today contains actual year-to-date numbers as of 6/30/99,and it reflects a shortage of $87,557.58 as of that date.He advised everyone to send in their outstanding bills so the updated report would contain the accurate figures. Mr.Sieczkowski said as soon as he received updated budget information,a Budget Subcommittee meeting would be scheduled sometime after September 15th. 2199AIDA.IOC:ese (10/28/99) O O INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 5 of 9 In response to a question,Mr.Sieczkowski said he had developed the Budget Subcommittee's mission and goals at the request of ML&P.He said he was also requested to compile a list of the Subcommittee members,and he distributed the list at this time.He requested |OC member feedback on any updates or corrections to the list.He suggested that email addresses could be added to the list for those who wanted them.Chair Day advocated the inclusion of email addresses. SVS Fund Custodian Agreement Mr.Matthews said he had the Agreement and would be completing it as soon as possible.He noted that it would be complete with AEG&T's approval. F.Maintenan mmi 1) 3) Executary Court Reporting 2199AIDA.IOC:esc (10/28/99) Quarterly Maintenance Reports Mr.Sieczkowski said he had received an update from Golden Valley,but he had not received any reports from MEA or Chugach.However,Mr.Willis had informed him verbally that everything has been accomplished and had provided him a summary. Mr.Sieczkowski reported that the ROW has been cleared up to the Talkeetna River;however,there are five to eight miles on the other side of the Talkeetna River that still remain to be cleared.He said he would present that issue to the Maintenance Subcommittee for discussion and recommendations as well as budget approval.Mr.Sieczkowski advised that clearing has been started on the helicopter pads but has not been completed.He added that the review and fly-over had been satisfactory. Mr.Sieczkowski said on-site inspections of the switch yards had been conducted. He said he had not been able to get inside Douglas but had viewed it from the outside,and it appeared to be neat and clean.He reported that his inspection of Cantwell revealed a 20-foot evergreen tree growing inside the substation.He said he had spoken to Monte about it,and the tree is scheduled to be removed,and the entire yard will be cleaned up.He reported that the alders at Healy were high,and they had to work their way through to the switches.He said Healy was scheduled for cleanup as well.Mr.Sieczkowski said they had also checked the maintenance records,i.e.,the dielectric and oil samples,at Golden Valley and found nothing unusual.He said he had requested this information from Ray but had not yet received it. Snow Load Monitoring Battery Replacement -MEA In response to Mr.Drake,Mr.Sieczkowski said he thought he had received the memo from Victor with the replacement schedule.Mr.Drake explained that the report from Dryden LaRue had indicated that a two-year rotation on battery replacements would be more appropriate than their current schedule. Foundation Problems at #251,274,and 297 O O INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 6 of 9 Mr.Sieczkowski recapped the history of the foundation problems since the late '80s.He said Dryden LaRue had been contracted to survey #274 and #297 this spring and report back on their findings.He said that during the course of the survey,it was discovered that the footings on Structure #251 were also leaning.He said Dryden LaRue was finalizing their report and he hoped to be able to distribute it prior to the next meeting of the IOC Committee. Y2K Issues and Updates Mr.Day reported that he has seen a marked increase in customer interest and concern regarding potential Y2K problems.He advised that the Y2K drill would be held on September 8-9,1999. Mr.Cooley outlined the schedule of events and what the utilities were supposed to do during the two-day drill,and discussion was heard regarding the expense and the extent of the IOC's participation.Mr.Cooley noted that the ASCC,during its last meeting,had decided to form a joint utility Y2K committee to plan a joint tabletop exercise,but it was unclear whether the Y2K committee had actually been implemented.Mr.Cooley gave a recap of the April 9th drill and said that it would be his proposal to go through some of the same exercises from that drill on September 8-9 and determine whether the problems discovered in April had been corrected. Discussion was heard regarding some of the problems encountered during the April 9th drill.There was a consensus that communications and transition command structure were issues to be addressed in the September 8-9 drill.End-of-year contingency planning was also discussed,including having another service wagon crew available and limiting key employee vacations during that time. The Committee concurred that a daytime exercise would be conducted on September 8th,and they would repeat some of the exercises from the April drill.Mr.Cooley said he would distribute the materials prior to the drill. RCA Presentation Mr.Day said he had received an email from Paul Morrison,Regulatory Commission of Alaska (RCA,formerly the Alaska Public Utilities Commission),requesting a presentation to the RCA by the Intertie Operating Committee or its affiliates.Mr.Morrison requested that the presentation be non-utility specific and suggested that the following topics would be educational for the Commission:(1)physical layout of the system and service areas, (2)generation locations and ownership,(3)load locations,(4)transmission layout, (5)contro!areas,dispatch centers,and coordination of reliability coordination,(6)energy (gas)supply contracts,(7)wholesale energy contracts,(8)economy energy contracts, and (9)other topics deemed important by the IOC for the education of the RCA. Mr.Day said he had responded to Mr.Morrison's letter,stating he would be happy to have the opportunity to make a presentation to the RCA;however,he would be unavailable during the month of August.He said he had suggested a date in late September for the presentation.Mr.Morrison had responded that they would like to schedule the IOC presentation to be given at the 9/22 RCA public meeting. Executary Court Reporting 2199AIDA.IOC:csc (10/28/99) e O O INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 7 of 9 Mr.Day emphasized that this was an opportunity to inform and educate the new Commissioners of the RCA of various Railbelt utility issues.Mr.Day requested IOC member input and suggested utility collaboration and/or development of individual utility information such as background,functions,and responsibilities and how they tie into the overall picture.It was suggested that a coordinated presentation by two or three people be developed. Mr.Day expressed concern regarding logistics with respect to input.He suggested using email for collaboration on the presentation project.Mr.Matthews said he felt the presentation should be scheduled not for a public meeting,but as a private briefing of the RCA.He noted that there would be a large amount of technical information,and the RCA should be briefed in a setting that would allow them to focus on the information and give them time to digest it without being cluttered by other issues that they deal with in their regular course of business at a public meeting.He added that the ASCC had felt they should develop the presentation and have it reviewed by their Executive Committee prior to being presented to the RCA. At Mr.Matthews request,Chair Day said he would distribute the letter from Mr.Morrison to the |OC members.There was a consensus that factual information could be obtained easily,and that a PowerPoint presentation could be emailed back and forth for collaboration. VIL.RMAL OP IN MMITTEE ACTI MMENDATION A.Approval of 57.7Hz Relay Setting at Eklutna MOTION:Mr.Matthews moved to approve 57.7 Hz for the Eklutna relay settings. Seconded by Mr.Evans.A voice vote was taken,and the motion passed unanimously. Action No.__00-001 VII.MMI IGNME Chair Day said the Subcommittee assignments contained in the May 20,1999 meeting minutes still stand as is,and he urged everyone to get them completed.The Subcommittee assignments are as follows: A.Dispatch Subcommittee 1.Prepare brief to state charter and mission. 2.Meet and review spinning reserves calculation and allocation;present reporting method that contains sufficient detail. 3.Meet with Reliability/Protection Subcommittee regarding operation of switches at Stevens/comm link problem;report on present practices and status and make recommendations. Executary Court Reporting 2199AIDA.IOC:csc (10/28/99) O INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 8 of 9 B.-Reliability/Protection Subcommittee -_ 4. Prepare brief to state charter and mission. Review relay settings at Eklutna (57.7)for 4th stage load shed and present to IOC for formal approval (this item was completed earlier in today's meeting). Meet with Dispatch Subcommittee regarding operation of switches at Stevens/comm link problem;report on present practices and status and make recommendations. Review relay problem on Douglas breaker and assess trip scheme. C.Machine/Rating Subcommittee 1. 2. 3. Prepare brief to state charter and mission. Continue work on present projects. Conduct regular quarterly meetings. D.SCADA/Metering/Communication Subcommittee ODNAARWN>Prepare brief to state charter and mission. Review Bradley (ICCP);Bob Day to go to Bradley O&D. Evaluate communications alternatives (GVEA). Review datalink agreement. Review Stevens Sub switch operation/comm link. Recommend reporting procedures during SCADA change-outs. Draft procedure to define use of satellite phones. Assess availability of satellite phones during crisis. Conduct regular quarterly meetings. E.Budget Subcommittee 2. 3. Prepare brief to state charter and mission. Prepare line item adjustment. Conduct regular quarterly meetings. F.Maintenance Subcommittee 1. 2. 3. 4. IX.END Prepare brief to state charter and mission. Submit Quarterly Maintenance Reports (CEA and MEA). Continue work on present projects. Conduct regular quarterly meetings. N MEETIN Chair Day said the agenda for the next meeting would be the same as for this meeting,and if anyone had any additions or deletions to forward them to Mr.Sieczkowski for inclusion in the next meeting's agenda. The next meeting was scheduled for Thursday,November 18,1999,at 10:00 a.m.in the AEG&T Anchorage office on C Street. Executary Court Reporting 2199AIDA.IOC:csc (10/28/99) -- INTERTIE OPERATING COMMITTEE Tuesday,August 24,1999 MEETING MINUTES Page 9 of 9 O x.ADJOURNMEN MOTION:Mr.Drake moved to adjourn. There being no objection and no further business of the Committee,the meeting was adjourned at 11:30 a.m. APPROVED: Chairman of 1!OC Date O Executary Court Reporting 2199AIDA.IOC:csc (10/28/99) * * *ALASKA INDUSTRIAL DEVELOPMENT «=AND EXPORT AUTHORITY <_ mes @@ =ENERGY AUTHORITY x 480 WEST TUDOR ANCHORAGE,ALASKA 99503 907 /269-3000 FAX 907 /269-3044 Facsimile Transmittal TO:Alaska Intertie Operating Committee Members COMPANY:Refer to attached List of Members Fax #:()Refer to attached list From:Stan Sieczkowski Date April 18,2000 Time:0900 Odumnver of pages inciuding cover page:12 Transmittal Contents: 1OC Agenda and January 20,2000 draft minutes for meeting at 10:00 AM,April 27,2000 at Golden Vaiiey Electric Assoc.Boardroom Comments: Notice:This facsimile may contain confidential information that is being transmitted to and is intended only for the use of the recipient named above.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,(907)269-3000. O DATE: SECRETARY.ry oa ;ly PARTICIPANT ALASKA ENERGY AUTHORITY ANCH MUN.LIGHT &POWER ALASKA ELECTRIC G&T CHUGACH ELEC.ASSOC. FAIRBANKS MUN.UTIL SYS. GOLDEN VALLEY ELEC ASSOC PARTICIPANT ALASKA ENERGY AUTHORITY ANCH MUN.LIGHT &POWER ALASKA ELECTRIC G &T CHUGACH ELEC.ASSOC. FAIRBANKS MUN.UTIL SYS. GOLDEN VALLEY ELEC ASSOC stan\userdata\utl\iocvote1.xls ALASKA wre lOC MEETING OLOCATIONLvchoeng 2 ACTION ACTION ACTION ACTION ACTION ACTION (0-60,][0-07][-005][-| [oo-] [oo- ae £4,$? lyes|No Jass||yves|No Jass|[yves|no [ass]lyes|No {ass}fyes|No Jass|-fyes|No |aBs| Let ||Let |}LL} LEtL|! Ltetl)} EtLtl |al LT dttid ft}LL}EL!|LL}LCLe | tet ||}tet tditt ||} CEtL|!CLE?!Ltt } Cr)Pho)Coo Cor)Cor)Coo POOI Pho)Coo)Coo:Coo)Coo Lo L "i |J}tL ft |}LEE}!CLI}CEE Jitt tf 4} ACTION ACTION ACTION ACTION ACTION ACTION [00-j} [20-j [00-j [00-j [00-|[00-| lyes|wo |ass||yes|no {ass}[yes|no Jass||yes|No Jass|_fyes{No Jass|_-fyes|No |ass| Lt}|} Ct_tl?|} LEt} LEtt} tt}}Lt] L |tf Jtt |tt |}Ltt}Let I Let |] _ttl J {Lfft| OoO-I-20-92. «a0 Elton. | poticy _A/LIC 7 eye.if Cc,zo CU JO eer-oan tenses F CLee4y oe); ALASKA INTERTIE OPERATING COMMITTEE AGENDA Thursday,January 20,2000 10:00 a.m. Alaska Electric Generation &Transmission Cooperative,Inc Conference Room 3380 C St.,Suite 110 Anchorage,Alaska (907)561-1030 Chairman -Bob Day Members Utility Phone Fax Email John Cooley CEA 762-4789 762-4540 |Johncooley@chugachelectric.comBobDrakeMEA761-9283 761-9328 Brad Evans evt|GVEA 451-5655 451-5657 BWEvans@qgvea.com Don Stead HEA 235-3336 235-3313 Bob Day,Chair.ML&P 263-5295 263-5441 Dayrh@ci.anchorage.ak.us Stan Sieczkowski AEA 269-3024 269-3044 ssieczkowski@aidea.org I.Adoption of Prior Meeting MinutesOA.August 24,1999 Il.Approval /Modification of Agenda Hl.Committee Reports and Correspondence Dispatch Subcommittee Brad Evans,GVEA 451-5655 No Reliability/Protection.Subcommittee Luke Sliman,CEA 563-7494 yo Machine /Rating Subconimittee Steve Gilbert,CEA 762-4446 7 SCADA/Metering/Communication Sub BobDay;ML&P 263-5295 KRARRm&ABudget Subcommitteefo ee WwSIntertieMyMb=¢oreittee Correspondence Received ch ful IV.Visitor's Comments Related to Items on AgendaO Stan Sieczkowski,AEA 269-3024 Monte Ervin,GVEA 451-5686 O « O VIL. Vill. Recess Work Session A.Dispatch Subcommittee 3)Spinning Reserve Issues2)Intertie Assignment Agreement-GVEA 3)Stevens Substation Operation Procedures 4)Committee Charter and Mission 7a Reliability /Protection Subcommittee1.)4"Stage Load Shedding 2.)Committee Charter and Mission Machine /Rating Subcommittee 1.)Joint Maintenance Labor and Spare Parts Agreement Update 2.)Committee Charter and Mission SCADA/Metering /Communications Subcommittee 1.)Bradley Lake ICCP 3)Project SCADA Communications Committee Charter and Mission OO rel SubcommitteeFinancialReport2}Committee Charter and MissionraMaintenanceSubcommittee1.)Quarterly Maintenance Reports 2.)Snow Load Monitoring Battery Replacement -MEA3.)Committee Charter and Mission Alaska Iniertie Trip Report Information from UtilityfiML&P Quarterly Report for Intertie Outagesa.1999 Events b,2000 Events .for Ov lane RepokinyXMIOCLegalIssuesyAIOCCommitteeMembersList Formal erating Committee Actions /Recommendations -WL Subcommittee Assignments A.Dispatch SubcommitteeVovuuro Qoftin & X. B.Reliability/Protection Subcommittee __tan gleme Clann om FOC, C.Machine /Rating Subcommittee D.SCADA/Metering /Communication S O77beat-Coee ate 2E.Budget Sebo Mitts . MLA Maintenance SubcommitteeCRrusstedly Rep _- Determine Agenda for Next Meeting Meeting Location:S cA Date:J aa Time:]O 'OOwaAE,weal,on feo fo A¢. h:\allisdean\stan\ioc\agenda.doc Stan Sieczkowski rom:John Cooley [John_Cooley@chugachelectric.com] nt:Wednesday,January 12,2000 3:29 PM :ssieczkowski@aidea.org;DayRH@ci.anchorage.ak.us;BPDrake@gci.net;Donald SteadCe:halldw@ci.anchorage.ak.us;Brad W.Evans Subject:AK Intertie Trip Report z) 99 outage overview.xis As agreed by the IOC the utility responsible for a trip of a unit,transmission line or under frequency event sends out a trip report,other utilities are to fill in the information for their system and return.Juvy,Chugach's PowerControlDataTechniciankeepsanotebookwitheachevent.ML&P,as southern controller,was to keep the records and send everyone a "final"copy. Juvy faxes the forms to Ray Morgan at MEA,Joe Steele at ML&P and Sam Matthews at HEA and Brad Evans at GVEA. GVEA appears fairly prompt in returning the forms but the remainder are very slow at returning forms.Some could becharacterizedasalmostnever.Attached is an index of 1999 events,a blank or N in the "final"column indicates that data is missing.The last FINAL was MAY 1,1999 and five are incomplete prior to that data. Please get in the missing data.Also please let me know if some other person at your utility should be getting the faxes so we can bug them about responses.Thanks. We also need to get to work on the 2000 events.ML&P''s quarterly reports are also way behind based on the lack of input data. Let's talk about this at the IOC meeting next week. O Municipal Light &Power POWER MANAGEMENT 1200 East First Avenue Anchorage Alaska 99501-1685 phone 907.263.5450 fax 907.263.5441 O December 27,1999 Mr.Norm Story,Operations Mgr. AEG&T 3977 Lake Street Homer,AK 99603 Mr.Stan Sieczkowski AIDEA 480 West Tudor Road Anchorage,Alaska 99503-6690 ©H OF R A G@ E\E CEIVE rn anton =H JAN -3 1999 Alaska Industrial Development Mr.Eugené Bjormstad*GeAgei'Manager Chugach Electric Association,Inc. P.O.Box 196300 Anchorage,Alaska 99519 Mr.George Kitchens,General Manager Golden Valley Electric Association,Inc. P.O.Box 71249 Fairbanks,AK 99707 Mr.Jeff Brunsdon Chief Financial Officer City of Fairbanks 800 Cushman Street Fairbanks,Alaska 99701 SUBJECT:Intertie Operating Committee Representation and Vote " Dear Sirs: One of the Intcrtie Agreement contractual requirements is to elect a new Chair at the first meeting of the new year.To ensure that the interest of each utility is properly represented, please reply to the following questions before January 10,2000: 1.Who represents you on the Intertie Operating Committee? 2.Who represents you on the various IOC Subcommittees? 3.What is your understanding of who votes for you on the Intertie Operating Committee? Please send your responses to Robert Day,1200 E.First Avenue,Anchorage,Alaska 99501. Sincerely, <0 Robert H.Day Chair,Intertie Operating Committee RHD/pjc ce:Mr.Wayne D.Carmony,General Manager Matanuska Electric Association,Inc. P.O.Box 2929 Palmer,Alaska 99645-2929 16 any DATE time {|COMPANY UNIT/LINE REPORTED PROBLEM LOAD SHEDISILOS Cause FINAL 3 5 €H2Ezgsiak5iy=fe <8 5 ge2g55fev)¢|sé 33$3 °§|332 s 3 2 <é _-.amiap}emus |GVEA |HEA &£i:§:a 5 gt &§3 2 gg 1/1/99 1:06 |CEA Quartz Creek QUARTZ CREEK 1036 BREAKER TRIP 69KV TO OPEN BREAKER 146 AT SOLDOTNA Y. 1/6/99 16:58]GVEA HEALY UNIT 4 TRIP Y 1/7/99 11:05|ML&P UNIT 6 TRIP Y 1/9/99 11:18/CEA BREAKER 1036 TRIP 69KV TO OPEN BREAKER 146 AT SOLDOTNA Y 1/16/99 10:09|GVEA FT KNOX TRIP Y. 1/18/99 5:51 |ML&P UNIT 5 TRIP.Y. 1/18/99 10:15|ML&P.UNIT 6 &7 TRIP.3.2 23.6 Y 1/18/99 18:011|GVEA HEALY TRIP NO LOAD SHED Y 1/19/99 16:45|ML&P UNIT 7 TRIP,LOSS OF 25MW'S ON UNIT 6 Y 1/19/99 17:50|ML&P UNIT 1 ML&P UNIT 1 TRIP Y. 1/19/99 17:55|ML&P.UNIT 4 TRIP 0.09 Y. 1/20/99 7:23 |GVEA HEALY TRIP 9.5 Y 1/20/99 8:45 |GVEA NORTH POLE TRIP 1.2 ¥ 1/20/99 12:01|GVEA UNIT1 HLP UNIT 1 TRIP DUE TO F.D.FAN TROUBLE -NO LOAD WAS SHED Y 1/21/99 20:05|GVEA HEALY HCP TRIPS OFF.STOICHEMETRY CONTROLS TOOK FIRST MILL OFF,NO AUTOMATIC DRUMLEVEL TQ 1.2 Y 1/23/99 6:32 |GVEA HEALY FAULT ON 24.9 SYS HLS 3.2 Y 1/25/99 4:59 [GVEA HEALY HCP LOSSES MILLS THEN TRIPS PLANT THROTTLE CONTROL PROBLEMS 1.2 Y 1/25/99 7:57 |GVEA HEALY LOAD SHED ON RESTART OF HCCP RTU LOAD SHED PROGRAM SAW AN OPEN GENERATOR BREAK 24.9 Y. 1/30/99 4:10 |CEA SOLDOTNA BKR 240 LOCKOUT Y 2/9/99 17:51;GVEA HEALY UNIT 1 TRIPS,MILLS LOADED THEN UNLOADED,LOST SEAL AIR FAN 2/10/99 6:06 [CEA BELUGA UNIT 5 TRIP 77 2/12/99 8:52 |ML&P.UNITS TRIP 2/15/99 8:00 |CEA DCSS/UVSS KENAL PENINSULA OPENS.DAVES CK826-UNIV 2002 TRIPPED -NOTHING FOUND 2/23/99 6:19 |GVEA HEALY UNIT 2 TRIP WITH 13 MW 3/3/99 4:46 |GVEA HEALY TRIP Y 3/3/99 18:58/GVEA NORTH POLE #1 TRIP ON FIRE IN THE LOAD TUNNEL.NSP OPEN AT 18:59:CLOSED AT 19:39 31.6 Y 3/6/99 13:04}GVEA HEALY UNIT 2 TRIP Y 3/6/99 16:00|GVEA HEALY UNIT 2 TRIP Y. 3/8/99 22:05|GVEA HEALY UNIT 2 TRIP Y. 3/12/99 12:35|ML&P UNIT 2 TRIP Y 3/15/99 1:19 |GVEA HEALY TRIP Y. 3/25/99 14:06|CEA DCSS/UVSS 115KV LINE TRIP.AVALANCHE AT MILE 60.NO LINE DAMAGE.LINE PLACED BACK IN SERVICE Y 3/25/99 14:07/CEA COOPER LAKE COOPER LAKE UNIT 1 TRIPPED AFTER KENAI ISLANDED Y 3/30/99 12:08iGVEA HEALY TRIP-CAUSED BY SLAG FALL IN FURNACE AREA 12.8 Y 3/31/99 §:07 |GVEA HEALY TRIP-CAUSED BY SLAG FALL AND FAN CONTROL TROUBLE Y. 4/47/99 22:16|GVEA HEALY UNIT 2 TRIP 33.9 Y 4/18/99 6:48 |GVEA HEALY UNIT 2 TRIP Y. 4/19/99 12:58]GVEA CHS Bt AND B13 Y 4/21/99 7:10 |GVEA HEALY TRIP,FURNACE DRAFT PROBLEM 34.8 Y 4/22/99 3:02 |GVEA CHS CHS 1B13-1B1 OPEN ON HIGH VOLTAGE RELAY,NO LOAD WAS LOST Y 4/24/99 10:39]GVEA HEALY UNIT 2 TRIP 33 Y S/1/99 2:01 {GVEA NP.UNIT 2 TRIP 23.7 Y 5/7199 9:22 |CEA BEL-PT MAC CEA BELUGA-PT MACKENZIE 230 LINE #3 TRIPPED,B PHASE TO GROUND.14 MILES FROM BEL 1950 AMPS N 5/11/99 13:19|ML&P UNIT 6 TRIPPED N 5/12/99 14:49)ML&P UNIT 6 TRIPPED N 5/13/99 19:02]GVEA CNS CNS B2 OPEN SEL 121 TOWER 33-5 3.7 N $/14/99 11:00|GVEA HEALY UNIT 2 TRIPPED N S/17/I99 §:24 |CEA DOUGLAS-TEEL DOUGLAS 81 OPEN,C PHASE FAULT TO 10.5 MILES NORTH OF TEELAND N 5/47/99 7:26 |GVEA HEALY TRIPPED 5 N 547199 16:44;GVEA FT KNOX TRIPPED N 5/19/99 8:05 |ML&P UNIT 7 TRIPPED 94 N $/19/99 20:40|/CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N $/19/99 21;11;/CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N 5/49/99 21:36|CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING 3.1 N 5/19/99 22:17{CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N 99 outage overview.xis Page 1 19 ny DATE TME_|COMPANY UNIT/LINE REPORTED PROBLEM LOAD SHED/SILOS Cause FINAL §H 2 3E:El tel feel |i§:=265 <=3s rade|5,|555]€|zs|2 |32282.2 3 E=<iccea_|amuse}emus |oven |Hea |MEA i £|é £z Fd 5 és z 5 g|8 gg 5/19/99 23:09|CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N 5/20/99 0:47 |CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N 5/20/99 12:12/CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N 5/20/99 12:51;CEA BRADLEY BRADLEY LAKE LOAD REJECTION TESTING N 5/20/39 17:34]CEA BRADLEY BRADLEY LAKE TRIP TESTING 1.5 N 5/20/99 21:091GVEA HEALY TRIPPED -LOSS OF GENERATION SHED 30.3 N §/25/99 6:20 |JCEA BELUGA CEA BELUGA UNIT 8 TRIPPED N 5/25/99 6:20 |JCEA 230 KV CEA 230KV LINE TRIPPED N 5/27/99 7:02 |ML&P UNIT 5 TRIPPED,VIBRATION PROBLEMS N §/29/99 20:42|GVEA HEALY UNIT 2 TRIPPED 15.9 N 6/3/99 8:47 JCEA BERNICE BERNICE LAKE #3 TRIPPED.SCADA LOCKED-UP.N 6/3/99 11:47|GVEA HEALY GVEA HEALY CCP TRIP DUE TO ID FAN CONTROLLER PROBLEM WHICH INITIATED A LOAD SHED DUG 15.7 N 6/18/99 2:14 |CEA BEL-PT MAC BEL-PTMAC #2 230KV LINE TRIPPED.WIRE DOWN BETWEEN STRUCTURES 21/3 &21/4 N 6/22/99 8:22 |CEA BERNICE BERNICE LAKE #3 TRIPPED.VOLTAGE CONTROL PROBLEMS N 6/22/99 11:52|CEA BERNICE BERNICE #3 TRIPPED 113 N 6/26/99 §:24 |GVEA HEALY HLS B12 OPEN 3.4 N 6/30/99 14:16|CEA BAXTER-DEBARR 34.5 KV LINE FAULT N TAI99 11:36{CEA BELUGA BELUGA #6 TRIPPED 10.2 20.2 5 9.2 N TA99 13:16}CEA ARCTIC ARCTIC CS 3414 TRIPPED.INADVERTANT BY WORKMEN N 7/3/99 21:40|GVEA NP.NP GT 1 TRIPPED,BANG FIRE SYSTEM DUMP,PANEL BLOWN OUT 1.2 N 7/5/99 9:09 |CEA BELUGA-PTMACK__|BELUGA-PT MACK #2 230 KV LINE TRIPPED N 7/8/99 16:21|CEA BELUGA UNIT 3 TRIPPED.DIFFERENTIAL FAULT AND LOSS OF EXCITATION 8.1 N 7/8/99 17:42|CEA BELUGA UNIT 3 TRIPPED.DIFFERENTIAL FAULT AND LOSS OF EXCITATION 41 N 7H10/99 9:33 |GVEA HEALY TRIPPED N 7H13/99 17:10/ML&P UNIT 7 TRIPPED N THA3/99 17:36/CEA BRADLEY UNITS 4 &2 TRIPPED 33 5 N TH14/99 3:06 |ML&P UNIT 8 TRIPPED N 7/20/99 10:23|ML&P UNIT 7 TRIPPED N 7/28/99 8:26 |ML&P Unit #6 TRIPPED 49 N 7/28/99 10:52|ML&P Unit #6 TRIPPED 5.1 N 7130/99 6:55 ICEA DOUGLAS-TEEL FAULT NEAR TOWER 60 36.1 N 7/30/99 6:55 [CEA COOPER LAKE UNITS 1 AND 2 BACKED OFF LINE N 7/30/99 6:55 |CEA DOUGLAS-TEEL 138 TRIPPED 36.1 7/30/99 14:16]ML&P UNITS 6 &7 BACKED OFF LINE 60.3 N 7/30/39 22:54)ML&P ML&P.ML&P LOST UNIT #6 AND UNIT #7.99 MW TOTAL.70.1 N 8/2/99 12:56|ML&P EKLUTNA EKLUTNA TRIPPED -GVEA MANUALLY SHEDS LOAD 10.4 N 8/3/99 15:17}GVEA HEALY.T7 RELAYED PUT HLP B13,B12,B11 ANS SVS 13.8 N 8/8/99 2:17 |CEA DOUGLAS-TEEL DOUGLAS-TEELAND 138 KV LINE TRIP N 8/8/99 14:12/CEA BELUGA UNIT 8 TRIP 2 N 8/10/99 17:34|CEA DOQUGLAS-TEEL TEELAND DOUGLAS 138 KV LINE TRIP.14 MILES FROM TEELAND.B PHASE TO GROUND.0.6 N 8/16/99 10:04}CEA BELUGA-PT MAC BELUGA-PT MACKENZIE #2 230 LINE TRIP.B PHASE TO GROUND 7.6 BELUGA 33.2 FR PT MAC N 8/20/99 10:04|CEA BELUGA-PT MAC BELUGA-PT MACKENZIE #3 230 KV LINE TRIPPED.B PHASE TO GROUND N 8/25/99 14:10/CEA DOUGLAS-TEEL 138 KV LINE TRIPPED B PHASE N 9/3/99 18:43|CEA SOLD-DIAMOND SOLDOTNA-DIAMOND RIDGE 115 KV LINE TRIPPED HRA LOST LOAD N 9/11/99 0:23 |GVEA HCCP TRIPPED 33.8 6 N 9/17/99 1:31 |CEA DAVES CREEK DAVES CREEK 926 TRIPPED SEWARD OUTAGE 6 MW.N 9/17/99 11:261CEA DAVES CREEK DAVES CREEK 926 TRIPPED SEWARD OUTAGE 8 MW.N 9/17/99 15:30/CEA TEELAND TEELAND BREAKER 1010 TRIPPED,MEA LOST LOAD N 9/20/99 19:09]CEA BELUGA UNIT 8 TRIPPED N 9/21/99 0:30 JCEA SOLD-DIAMOND 115 KV LINE TRIPPEO A-PHASE TO THE GROUND N 9/21/99 14:21|CEA BRADLEY UNIT 2 TRIPPED N 10/9/99 15:46|/CEA BRADLEY BRADLEY #1 TRIPPED CAMP STATION SERVICE FIRE AND GROUND TARGETS ON 13.5 BUS N 10/15/99 8:52 (GVEA HEALY HLS GHS 138 KV LINE RELAYS OPEN ON "C"PHASE TO GROUND FAULT $8.4 N 10/17/99 21:261CEA BRADLEY BRADLEY #1 &2 TRIPPED.INLET GATE VALVE CLOSED 34 N 10/19/99 15:18|/CEA KENAI-PORTAGE KENAI ISLANDED AT PORTAGE.INADVERTANT BY RELAY TECHNICIAN 10.5 N 10/19/99 17:30}CEA BELUGA-PTMACK ||BELUGA-PT MACKENZIE #3 230 KV LINE TRIPPED.C PHASE TO GROUND.LINE PATROL FOUND NOTHING N 40/22/99 14:58|GVEA NORTH POLE NORTH POLE #1 TRIPPED ACCIDENTALLY BY THE FIRE SYSTEM INSPECTORS 44 N 99 outage overview.xls Page2 Cd DATE TIME _|COMPANY UNIT/LINE REPORTED PROBLEM LOAD SHED/SILOS Outage Type Cause FINAL ::z g[<ja &z é z§53 a54saoSr|§z |2st}¢|as Se 5 3 a 23 5 5a -zg 2 2£2 |8 ££2 |858]2 BS |3 B's .ee oe ee .CEA |amcap|FMUS |GVEA |HEA [|MEA |O¢£5 58 sé a 83 £s2 10/27/99 13:50|CEA UNITS TRIPPED 9.8 N 10/31/99 15:20|CEA BELUGA UNIT 5 TRIPPED 23.4 N 11/3/99 [21:59[CEA BELUGA UNIT 5 TRIPPED.13.4 N12/6/99}14:26{ML&P__|UNIT8 TRIPPED 6.4 N 99 outage overview.xls Page 3 1/12/00 Jan 12 00 O02:30p Clive Herrington SectioB Wednesday,January 12,2000 GVEA can't find cause . of outages By AL SLAVINStaffWriter . Golden Valley Electric Associ-ation officials still aren't sure what caused a power line south of _Healy to trip on Monday evening,triggering two power outages. .Steve Haagenson,GVEA's vicepresidentoftransmissionand distribution,said the utility was waiting to hear from Matanuska Electric Association,which main- tains the line between Healy anAnchorage.: The problem area has beennarrowedtoasteep,sloping area near Curry's Ridge in the foot- hills north of Talkeetna.The in- tertie is owned by Alaska Industrial Development and Ex- port Authority.GVEA maintainsthenorthernhalfoftheline. Haagenson said GVEA will continue relying upon powerfromHealyGeneration,twogenerators"in North Pole that supply 125 megawatts of power,and two 20-megawatt generators at its Illinois Street facility.Inaddition,Aurora Energy is sup-plying the Interior-based electric co-operative with 19 megawatts of power.Haagenson seid-power usagepeakedTuesdayat.172 mega-watts.Peak power usage for lastyearwast82megawattsDec.30. 1 9307 683 2955 Vi. Recess A.Dispatch Subcommittee 1.)Spinning Reserve Issues B.Reliability/Protection Subcommittee 1.)4"Stage Load Shedding C.Machine /Rating Subcommittee 1.)Joint Maintenance Labor and Spare Parts Agreement Update Dz.SCADA/Metering /Communications Subcommittee 1.)Communications Reliability he oACEBtLe SloveesE.Budget Subcommittee 1.)FY 99 Fourth Quarter Report 2.)SVS Fund Custodian Agreement F.Waintenance SubcommitteeRQuarterlyMaintenance ReportsSnowLoadMonitoringBatteryReplacement -MEA f Foundation Problems at #251,274,and 297 G.Y2K Issues and Updates H._MEAteportfor Déc-tS-intertie-Outage REA Formal ratin mmi Actions /Recommendations Subcommittee Assignments Determine Agenda for Next Meeting Meeting Location:Date:Time: Adjournment h:\all\sdean\stan\ioc\agenda.doc ALASKA INTERTIE OPERATING COMMITTEEOAGENDA Tuesday,August 24,1999 10:00 a.m. Alaska Industrial Development and Export Authority Alaska Energy Authority Board Room Anchorage,Alaska (907)269-3000 Chairman -Bob Day Members Utility Phone Fax Email John Cooley CEA 762-4789 762-4540 |Johncooley@chugachelectric.com Bob Drake MEA 761-9283 761-9328 Brad Evans GVEA 451-5655 451-5657 BWEvans@avea.com Sam Mathews HEA 235-3303 235-3313 Smathews@xyz.net Bob Day ML&P 263-5295 263-5441 Dayrh@ci.anchorage.ak.us Stan Sieczkowski AEA 269-3024 |269-3044 ssieczkowski@aidea.org (Gloire MCebrgge.AEA -t l.Adoption of Prior Meeting MinutesOA.May 20,1999 IL.Approval!/Modification of Agenda Il.mmittee R san rr nden A.Dispatch Subcommittee Brad Evans,GVEA 451-5655 B.Reliability/Protection Subcommittee Luke Sliman,CEA 563-7494 C.Machine /Rating Subcommittee Steve Gilbert,CEA 762-4446 D.SCADA /Metering /Communication Sub =Bob Day,ML&P 263-5295 E.Budget Subcommittee Stan Sieczkowski,AEA 269-3024 F,Maintenance Subcommittee Monte Ervin,GVEA 451-5686 G.Intertie Status Report H._Correspondence-Received-DN ' "IV.Visitor's Comments Related to Items on Agenda O O NMACHINE RATING SUBCOMMITTEE MEETING MINUTES Hosted by Kotzebue Electric Tour of Wind Plant August 6,1999 .Call to order:Meeting was called to order at 9:35 am by Chairman Steve Gilbert. .Rolleall:Alex Gajdos,GVEA Hank Nikkels,AML&P Steve Gilbert,CEA Review and approval of meeting minutes for 5/14/99. Minutes were approved as presented by the Chairman. Any new comments on handbook,Volumes I &II. CEA reported that having the handbook was quite useful in answering performance questions from DOE. .Issues and Items for Discussion. a.Discussion of use of maintenance planning consultants.The committed discussed assembling a list of consultants and contractors that each has used for power plant maintenance. b.Discussion of spare main unit transformer for joint owner ship in the Railbelt.AML&P provided a draft specification for discussion and review.The Chairman will distribute it to the MSRC. c.Update on projects: 1. 4. AML&P Eklutna control system upgrade update by Hank Nikkels.Project is under way in two phases.First phase is to install electronics and second is to replace mechanical governors. GVEA North Pole /MAPCO-Williams heat recovery project-update by Alex Gajdos. Feasability study is complete and costing study is now under way.The project economics appear favorable at this time. CEA #6&7 upgrades andfuel cell project-update by Steve Gilbert.Chugach has ordered the upgrades for Beluga 6 and 7 and design is now under way for the turbine,combustor and control systems upgrades.Unit #6 is scheduled to begin in spring of '00.Installation of the fuel cell project is scheduled for September/October.The first four fuel cells have been delivered to Chugach. Additional discusion: Hank Nikkels suggested exploring putting the handbook on a web page.Updates and accessability would both be easier. AML&P also reported that they would be reporting performance changes to unit #5 boiler and unit #7. Also discussed opening purchase orders between companies to not only include parts but also hiring of technical services. ML&P also indicated that they will be doing robotic generator inspection of unit #7. Assignments for the next MRSC meeting. 1.Chairman will distribute specification of transformer for review and consideration. 2.Chairman will research cost analysis ofjointly held main unit transformer. 3.Chairman will assemble list of consultants and contractors used for power plant work by Railbelt utilities. 4.Chairman will research putting MRSC handbook on a website. Schedule for next meeting,date and location. November 12,1999 Soloman Gulch,Alyeska Terminal Generation Plant Motion for adjournment. Meeting was adjourned at 10:55 am. Respectfully Submitted Steve Gilbert,MRSC Chairman O ALASKA INTERTIE FY99 BUDGET STATUS REPORT CEA AEGT INTEREST TOTAL REVENUES EXPENSES FERC §61 -Load Dispatching GVEA Northern Controller MLP Southern Controller AFI Other FERC 562 -Station Operation Expenses GVEA-substation electricity usage FERC 563 -Overhead Line Expenses GVEA -Weather monitoring equipment FERC 565 -Transmission of electricity by others MEA Wheeling -Holly Rd to Douglas FERC 566 -Miscellaneous transmission expense SCADA&voice circuits (SOA) Cell phones for weather monitoring Weather monitoring maint (batteries) 8/19/99/5.40 PM rt BUDGET BUDGET BUDGET ACTUALS APPROVED REVISED YTD YTD OVER 5/28/98 1/26/99 6/30/99 6/30/99 {UNDER) 510,031 510,031 510,031 515,435.65 5,405 25,720 25,720 25,720 26,853.00 1,133 38,242 38,242 38,242 39,869.40 1,627 33,725 33,725 33,725 35,853.20 2,128 0 0 0 10,293.03 10,293 607,718 607,718 607,718 |628,304.28 20,586 0 -0 0 -0 0 -0 0 0 0 -0 7,500 7,500 7,500 6,023.85 (1,476) 7,500 7,500 7,500 6,023.85 (1,476) 220,476 220,476 220,476 |215,607.00 (4,869) 220,476 220,476 220,476 |215,607.00 (4,869) 31,029 31,029 31,029 32,082.78 1,054 31,029 31,029 31,029 32,082.78 1,054 131,300 131,300 131,300]131,574.16 274 8,000 8,000 8,000 3,937.48 (4,063) 20,000 20,000 20,000 (20,000) 159,300 159,300 159,300 |135,511.64 (23,788) O NOTES: See deficiency allocation below. See deficiency allocation below. See deficiency allocation below. See deficiency allocation below. h:all\elaine\aki\file:Fy99aki\ws:eo)BR A ALASKA INTERTIE FY99 BUDGET STATUS REPORT BUDGET BUDGET BUDGET ACTUALS APPROVED REVISED YTD YTD OVER §/28/98 1126/99 6/30/99 6/30/99 (UNDER) FERC 567 -Transmission Expenses -Rents Rents -Alaska Railroad 541.71 542 MEA-Talkeetna Storage 7,200 7,200 7,200 7,200.00 0 7,200 7,200 7,200 7,741.71 542 FERC 570 -Maintenance of station equipment GVEA -Healy Cantwell,Goldhill 50,000 50,000 50,000 4,918.37 (45,082) CEA Teeland Substation 10,000 10,000 10,000 11,320.37 1,320 MEA -Douglas substation 10,000 10,000 10,000 1,189.76 (8,810) Extraordinary maint -GVEA 0 0 0 -0 Extraordinary main -CEA -CB &Transfor 23,600 23,600 23,600 -(23,600) Extraordinary maint -MEA -batteries 6,500 6,500 6,500 -(6,500) ,100,100 100,100 100,100 17,428.50 (82,672) FERC 571 -Maintenance of overhead lines Maintenance of Overhead Lines -Other 0 0 0 333.04 333 GVEA Northern Maintenance 50,000 50,000 50,000 38,477.40 (11,523) MEA Southern Maintenance 21,500 21,500 21,500 65,225.70 43,726 Weather monitoring equipment maintenan 60,000 60,000 60,000 19,968.15 (40,032) MEA-Landing Pads 45,000 31,000 31,000 8,407.75 (22,592) GVEA-Tighten Guys 30,000 30,000 30,000 -(30,000) GVEA-Moody Creek Slide Study 30,000 30,000 30,000 -(30,000) GVEA-Northern ROW clearing 20,000 20,000 20,000 -(20,000) MEA-Southern ROW clearing 78,000 92,000 92,000 94,895.18 2,895 334,500 334,500 334,500 227,307.22 (107,193) 8/1 "@) wy NOTES: Annual lease payment. Billed only through 12/98 Billed only through 12/98 R.G.Wiiliams -Line Maintenance Billed through 12/98 Billed only through 12/98 Billed only through 12/98 Billed only through 12/98 h:all\elaine\aki\file:Fy99aki\"CO BR ALASKA INTERTIE FY99 BUDGET STATUS REPORT FERC 920 -AEA Administrative Costs Personal Services,travel and other costs FERC 920 -|OC Administrative Costs Legal Expense 10C -Gen Prof Services FERC 924 -Property Insurance AF Intertie -Insurance Risk Management Fee .Line of Credit Fee TOTAL EXPENSE SURPLUS (SHORTAGE) TRUE-UP DUE FROM UTILITIES E-501-47000-331 GVEA E-501-47000-332 MLP E-501-47000-333 CEA E-501-47000-334 AEGT 8/1 'CO os BUDGET BUDGET BUDGET ACTUALS APPROVED REVISED YTD YTD OVER 5/28/98 1/26/99 8/30/99 6/30/99 (UNDER) 76,300 76,300 76,300 65,703.22 (20,597) 76,300 76,300 76,300 55,703.22 (20,597) 75,000 75,000 75,000 577.70 (74,422) 35,000 35,000 35,000 -(35,000) 110,000 110,000 110,000 577.70 (109,422) 80,000 80,000 80,000 16,644.24 (63,356) 6,200 6,200 6,200 1,234.00 (4,966) 1,200 1,200 1,200 -(1,200) 87,400 87,400 87,400 17,878.24 (69,522) 1,133,805 1,133,805 1,133,805 715,861.86 (417,943) (526,087)(526,087)(526,087)(87,557.58)438,529 438,529 ALLOCATED MITCR (MW)=MITCR(%)=DEFICIENCY 70.000 50.00%(43,779.10) 19.195 13.71%(12,004.86) 28.537 20.38%(17,847.49) 22.267 15.91%(13,926.13) 139.999 100.00%(87,557.58) eo) LOC discontinued. h:ail\elaine\aki\file:Fy99aki\ws:&KI BR O DRAFT ALASKA INTERTIE OPERATING COMMITTEE MEETING MINUTES THURSDAY,MAY 20,1999 MUNICIPAL LIGHT &POWER-COMMISSION ROOM Present: «Stan Sieczkowski AIDEA/AEA "John Cooley,Chair Chugach Electric Association,Inc. Brad Evans By Teleconf.Golden Valley Electric Association,Inc. Sam Matthews Homer Electric Association _Bob Drake Matanuska Electric Association Ray Morgan Matanuska Electric Association Bob Day Municipal Light &Power Hank Nikkels Municipal Light &Power The meeting of the Intertie Operating Committee was called to order at 10:25 a.m. ADOPTION OF PRIOR MEETING MINUTES A.February 18,1999 The following corrections to February 18,1999 meeting minutes were noted: Page 3:Replace the first sentence of the first paragraph of VI.A.2.with the following sentence:"Brian Hickey reported that at their last meeting,Ray Morgan said that he found the wiring such that only MEA can operate the circuit switchers.” Page 3:In the heading of VI.C.1.,change "JOIN”to "JOINT.” The minutes were unanimously approved as modified. APPROVAL/MODIFICATION OF AGENDA The Agenda was unanimously approved as submitted. COMMITTEE REPORTS AND CORRESPONDENCE A.DISPATCH SUBCOMMITTEE No Report. RELIABILITY/PROTECTION SUBCOMMITTEE No Report.Subcommittee has not met.Ray Morgan reminded everyone that a joint Dispatch Subcommittee and Reliability/Protection Subcommittee meeting needs to occur to discuss operation of switches at Stevens and the comm link problem.They should report to the IOC on present practices and status,and make recommendations to remedy the problems. MACHINE/RATING SUBCOMMITTEE O O Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 2 of 8 Hank Nikkels reported that they have met twice since the last IOC meeting,addressing the Handbook and the Sharing Agreement.Steve Gilbert is in the process of making changes to the Handbook. Parts Sharing Agreement:ML&P has no problems with letter of agreement and is willing to exchange common parts lists and parts from various parts systems.There are issues with identifying the parts. Joint Labor:There are severe logistic and labor problems with this concept.Labor is covered in other agreements.We will share lists of consultants and professional services to see if there is a common denominator. ML&P is exploring the potential for a jointly-owned generation step-up transformer that could cover most equipment.They are looking for a used one to dry store,nominally a 13.8/115-138kV spare transformer that could be used anywhere.Hank Nikkels is exploring information on styles and sizes. SCADA/METERING/COMMUNICATION SUBCOMMITTEE Subcommittee has not met due to time demands of new SCADA systems at CEA & ML&P. John Cooley reported that CEA is using the new system for switching.It is working for the most part,but they are still trying to get the generation control portion working. BUDGET SUBCOMMITTEE Budget Subcommittee met yesterday. Stan Sieczkowski reviewed the FY 1999 budget.As of 5/17/99 there is a_shortfall of $79,578.80.The ending budget shortfall will be approximately $500,000.There will be a mid year correction to the utilities.Monthly invoices are available for review. SVS Agreement:Subcommittee reviewing actions to be taken. 1.FY 2000 BUDGET Revisions to the FY 2000 Budget were made.Budget will be presented in Work Session. MAINTENANCE SUBCOMMITTEE The Maintenance Subcommittee met May 12.GVEA submitted their Quarterly Reports; CEA and MEA have not.Stan stated the need to receive reports in a more timely manner. INTERTIE STATUS REPORT MEA tower flashover on Monday,5/17/99 at 5:30 a.m.,C phase to ground.The line was taken out of service at 10:00 a.m.today for repair. There is a need for future work to be done on foundation problems on structures 297 and 284 located on Chulitna Ranch.Visually,the foundations on towers do not appear to have moved but need to be investigated.GVEA Engineering has no time.Stan is going to have a consultant investigate and submit a report in July. h:\all\stan\ioc\minutes\1999\May 20,1999 O Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 3 of 8 Vi. H.CORRESPONDENCE RECEIVED John Cooley received a letter from ML&P stating that Robert Day is now ML&P's |OC representative,replacing Tim McConnell.Hank Nikkels will serve as alternate. VISITOR'S COMMENTS RELATED TO ITEMS ON AGENDA None. RECESS AND LUNCH WORK SESSION A.DISPATCH SUBCOMMITTEE ML&P will submit the Quarterly Reliability Report very soon. 1.Spinning Reserves Issues Hank Nikkels stated that ML&P is concerned about the current contract and practices being to ML&P's disadvantage,and ML&P requests the contract and practices be formally reviewed by the Dispatch Subcommittee.He stated that what was envisioned at the time of signing has changed,and the present formula is no longer applicable.He added that the current contract and practices are being misapplied to ML&P's further disadvantage.He stated that the entire group needs to cooperatively incorporate a new set of rules that would include provisions for independent producers to have some responsibility for spin when they are on the system.He also stated that ML&P has begun a study on contractual and technical issues and will push this through as a responsible move for ML&P Rate Payers. Bob Day stated that an on-line recording system is needed to monitor what is on line and how much spin is available in order to ensure that everyone is playing by the same set of rules. Brad Evans requested a list of issues in writing.Hank Nikkels stated that the present formula is seriously flawed and that ML&P is willing to take the lead on this issue,since ML&P has the most to gain.He requested that Brad Evans, Steve Hammond,and Doug Hall meet and document how spin is presently calculated. After some discussion,John Cooley stated that spinning reserves will be reviewed by the Dispatch Subcommittee and a recommendation submitted to the IOC.The Subcommittee should review present practice and report on the following:a)how spin is presently calculated,b)what reports are presently submitted,c)understanding of current rules and developing methods to assure adherence,d)developing effective reporting methodology,and e)addressing and resolving questions,e.g.1)Does GVEA still use SILOS trips?and 2)If an IPP connects,what are the spin responsibilities of that IPP? John Cooley also stated that important aspects for the Subcommittee to consider are:1)Appropriate level of spin and how to allocate and 2)Financial considerations. h:\all\stan\ioc\minutes\1999\May 20,1999 O 0 Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 4 of 8 Hank Nikkels questioned FMUS's status.Brad Evans will get a clarification on FMUS's status regarding voting privileges/spin obligation. Bob Day stated that we have a reporting mechanism to use during the interim until the Dispatch Subcommittee meets and develops spin reports with sufficient detail. ACTION:Dispatch Subcommittee to meet and report on the above. Line Switching Restrictions and Recommendations The question was posed,"who is going to operate switches at Stevens?” MEA controls TS-200 and TS-201;ML&P controls TS-100.There is no sync check on TS-100,and we do not know if it is a loadbreak.Ray Morgan stated that the MOD switch is under ML&P control,but should not be used to close in the Intertie.ML&P does have technical control of the MOD;however, communications reliability does not allow physica!contro!from ML&P--no control or status monitoring.ML&P has to call MEA to request they physically go out to check status and/or to open.Bob Day stated that the IOC previously agreed to have adequate communications for ML&P to monitor. Bob Day wants to get Vance Cordell to make recommendations for improvements on comm fink to bring it back to functional. ACTION:Bob Day and Vance Cordell to check out Comm Link. B.RELIABILITY/PROTECTION SUBCOMMITTEE 1.4"Stage Load Shedding Relays at Eklutna (57.7)are in,but are waiting for an |OC recommendation to set them. A coordinated 4"stage load shed may have prevented the last total black out. The hardware is in place to do some improvements by simple Subcommittee recommendations.Luke Sliman has information on pre-sets.Sam Matthews stated he thought set points had been determined,but that further refinement other than set points is needed.The Subcommittee should meet to formalize what they have already started,pursue it to conclusion,and present the settings recommendation/scheme for the IOC to formally approve. Cc.MACHINE/RATING SUBCOMMITTEE No form 1. al recommendations.!1OC recommends continuation of present projects. Joint Maintenance Labor And Spare Parts Agreement Update See Machine Rating Subcommittee Report. D.SCADA/METERING/COMMUNICATION SUBCOMMITTEE 1.Stevens Sub Communications Reliability h:\allstan\ioc\minutes\1999\May 20,1999 OQ Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 5 of 8 E. F. "MEA has not met the wontnamenk under which Stevens Sub was constructed. With Div Com cost increases,the Subcommittee needs to seek an alternative. The Subcommittee also needs to discuss the final agreement for exchanging Bradley data.Issues include:1)Dec Net terminal replacement,2)Incomplete RTU data,3)Data sharing methods,and 4)Replacement or expansion of system. Bob Day questioned whether the data available under the new system would be adequate.Stan suggested that Bob Day attend the next Bradley O&D Committee meeting.The Bradley 0&D Committee had previously reported that the data available would be adequate. Satellite Phones:John Cooley stated that the satellite phones are not working correctly.It is a simplex system with 2-4 second delay.During a disaster, availability is an issue. The IOC needs a simple procedure for use of satellite phones.Hank Nikkels and Bob Day are going to formulate a recommendation. BUDGET SUBCOMMITTEE 1.FY 99 Quarterly Report Budget Subcommittee met yesterday.Revisions to the FY 2000 Budget were made. SVS Fund Custodian Agreement Funds from the G.E.settlement with State of Alaska on SVSs were used to fix roofs on SVS buildings.Almost $90,000 is left over in a trust with Key Bank. Key Bank charges $1,000/year to hold in account.AIDEA has offered to keep the funds for the IOC to save $1,000 per year but needs ML&P and AEG&T to sign Agreement.All other utilities signed two months ago.This agreement would make AIDEA Trustee of the money.Stan is to get another copy to ML&P. Sam Matthews stated AEG&T has copy and will sign and return. FY 2000 Budget Stan Sieczkowski reviewed the Alaska Intertie FY 2000 Budget of $1,027,560 with a shortfall of ($372,685). Ray Morgan stated that MEA will not be able to order the batteries this year.Ray will submit detail of change,and Subcommittee will do line item adjustment to FY 1999 Budget. Need formal actions to approve Budget and MITCR. MAINTENANCE SUBCOMMITTEE 1.Quarterly Maintenance Reports Stan requested that MEA and CEA submit Quarterly Maintenance Reports. Contracts h:\all\stan\ioc\minutes\1999\May 20,1999 O OQ Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 6 of 8 A a.ROW Clearing -MEARightofwayclearing contract has foe initiated this year.Helio padwasClearedwithadditional$9,000."Work has been accomplished within budget.A 2-3 mile area beside the Talkeetna River still needs to be cleared. b.Snow Load Monitoring -MEA Snow load monitoring was better this year.Batteries are ready.Dryden LaRue still needs more data to complete study. G.Y2K ISSUES AND UPDATES John Cooley handed out the April 9 Drill Guide.It was noted that the April 9 drill was satisfactory,some improvement was noted. Clinton is announcing a nation-wide community program to encourage local groups to work on the Y2K issues. ML&P will be asking people to be available on New Years Eve and is trying to encourage key employees to have their own preparedness plan. CEA met with the gas and oil companies to ensure gas is available.John Cooley stated that CEA is planning to have their loop wagon people working on New Years Eve from 2200 to 0400 so that CEA can check any contingency(s)to evaluate source. NERC has proposed that all utilities have Contingency Plans ready by June 30 and that every utility participate in a night-time Y2K drill on September 8-9. The IOC agreed to participate in the September 8-9 drill.Bob Day suggested sharing contingency plans.All utilities have agreed to have extra staff and helicopters available that night. H.MEA REPORT FOR DEC.15 INTERTIE OUTAGE Ray Morgan reported that there was a phase-to-ground fault outside Douglas Substation. No fault studies were done when the 115 Transformer was installed.The event damaged 15 turtle meters.There was a relay problem with Douglas Breaker;it hadn't tripped since replaced.It was miswired.Transfer trip works,but local did not trip.This has been corrected,as the breaker tripped under fault some time ago after remedial work was done.Ray Morgan stated that it is an unusual trip scheme which should be addressed by the Reliability/Protection Subcommittee. VIL FORMAL OPERATING COMMITTEE ACTIONS/RECOMMENDATIONS Stan Sieczkowski made the motion to approve the Alaska Intertie FY 2000 Budget of $1,027,560 with a shortfall of ($372,685).Sam Matthews seconded the motion.The FY 2000 Budget was approved unanimously.Action No.99-002 John Cooley made the motion to approve the MITCR of 0.466 cents with a Capacity Charge of $1.21/KW.Sam Matthews seconded the motion.The motion passed unanimously. Action No.99-003 h:\all\stan\ioc\minutes\1999\May 20,1999 OQ Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 7 of 8 VI. Bob Day made the motion to participate locally in a January 1,2000 contingency plan drill test the night of September 8-9,1999.Stan Sieczkowski seconded the motion.The motion was approved unanimously.Action No.99-004 ELECTION OF OFFICERS Brad Evans nominated Bob Day as Chair.Ray Morgan seconded the nomination.Sam Matthews moved to cast a unanimous ballot for Bob Day for Chair.Hearing no objections,Bob Day was unanimously approved as Chair. Sam Matthews nominated John Cooley for Vice Chair.John Cooley Seconded the nomination. Sam Matthews asked that the Chair cast a unanimous ballot for John Cooley as Vice Chair. Hearing no objections,John Cooley was unanimously approved as Vice-Chair. Stan Sieczkowski continues as Secretary. SUBCOMMITTEE ASSIGNMENTS A.DISPATCH SUBCOMMITTEE 1.Prepare brief to state charter and mission. 2.Meet and review spinning reserves calculation and allocation;present reporting method that contains sufficient detail. 3.Meet with Reliability/Protection Subcommittee regarding operation of Switches at Stevens/Comm Link problem;report on present practices and status and make recommendations. B.RELIABILITY/PROTECTION SUBCOMMITTEE 1.Prepare brief to state charter and mission. 2.Review relay settings at Eklutna (57.7)for 4°Stage Load Shed and present to IOC for formal approval. 3.Meet with Dispatch Subcommittee regarding operation of Switches at Stevens/Comm Link problem;report on present practices and status and make recommendations. 4.Review relay problem on Douglas Breaker and assess trip scheme. Cc.MACHINE /RATING SUBCOMMITTEE1.Prepare brief to state charter and mission. 2.Continue work on present projects. 3.Conduct regular quarterly meeting. D.SCADA/METERING /COMMUNICATION SUBCOMMITTEE Prepare brief to state charter and mission. Review Bradley (ICCP);Bob Day to go to Bradley O&D. Evaluate communications alternatives (GVEA). Review datalink agreement. Review Stevens Sub switch operation/comm link. Recommend reporting procedures during SCADA change outs. Draft procedure to define use of satellite phones. Assess availability of satellite phones during crisis. Conduct regular quarterly meeting.OANAnNRWN>E.BUDGET SUBCOMMITTEE 1.Prepare brief to state charter and mission. 2.Prepare line item adjustment. 3.Conduct regular quarterly meeting. h:\all\stan\ioc\minutes\!999\May 20,1999 QO Alaska Intertie Operating Committee Minutes Thursday,May 20,1999 Page 8 of 8 F,MAINTENANCE SUBCOMMITTEE 1.Prepare brief to state charter and mission. 2.Submit Quarterly Maintenance Reports (CEA and MEA) 3.Continue work on present projects. 4.Conduct regular quarterly meeting. X.DETERMINE AGENDA FOR NEXT MEETING The Agenda for the next meeting will be the same as this meeting minus the MEA Report on December 15,1998 Outage.Due to schedule conflicts,the third Thursday of the Quarter is not available,so the next meeting will be held at 10:00 a.m.on Tuesday,August 24,1999 at AIDEA. XI.ADJOURNMENT MOTION:Stan Sieczkowski moved to adjourn. There being no objection and no further business of the Committee,the meeting was adjourned at 1:25 p.m. APPROVED: Chairman of |OC Date h:\all\stan\ioc\minutes\1999\May 20,1999 O ALASKA INTERTIE OPERATING COMMITTEE COMMITTEE MEMBERS Auqust 23,1999 MEMBERS UTILITY PHONE INTERTIE OPERATING COMMITTEE Bob Day ML&P 263-5295 <&--Chairman John Cooley CEA 762-4540 47 8°F Vice Chairman Bob Drake MEA 761-9383 Brad Evans GVEA 451-5655 Sam Matthews HEA 235-3303 Stan Sieczkowski AEA 269-3024 €-Secretary DISPATCH SUBCOMMITTEE Brad Evans GVEA 451-5655 Chairman Doug Hall ML&P 263-5453 John Cooley CEA 762-4789 Ray Morgan MEA 761-9318 Don Stead HEA 235-3336 RELIABILITY/PROTECTION SUBCOMMITTEE Luke Sliman CEA 762-7602 Chairman Larry Hembree ML&P 263-5243 Sam Matthews HEA 235-3303 Ray Morgan MEA 761-9318 Steve Haagenson GVEA 451-5647 ** MACHINE RATING SUBCOMMITTEE Steve Gilbert CEA 162-4446 Chairman Alex Gajdos GVEA 451-5654 Hank Nichols ML&P 263-5329 Sam Matthews HEA 235-3303 Stan Sieczkowski AEA 269-3024 _e&-MAt C bpdenrke ©6.ned SCADA/METERING/COMMUNICATION SUBCOMMITTEE Brad Evans GVEA 451-5655 Mary Battensmith ML&P 263-5263 Paul Johnson CEA 762-4447 Sam Matthews HEA 235-3303 Ray Morgan MEA 761-9318 BUDGET SUBCOMMITTEE Stan Sieczkowski AEA 269-3024 John Cooley CEA 762-4789 Bob Day ML&P 263-5295 Bob Drake MEA 761-9283 Sam Matthews HEA 235-3303 MAINTENANCE SUBCOMMITTEE Monte Ervin GVEA 451-5686 Doug Hall ML&P 263-5453 Paul Rissee CEA 762-7661 Stan Sieczkowski AEA 269-3024 Bob Drake MEA 761-9283 **.NEED TO VERIFY Chairman Chairman Chairman ek ke O 10. 11. ALASKA INTERTIE INVOICE POLICY July 31,1996 The Budget Subcommittee shall meet quarterly and review the summary report of invoices paid to verify the proper coding and amounts.The Utilities shall provide the committee with a quarterly summary showing %spent,authorized amount,and line item balance. All invoices submitted to AEA shall have the proper backup to verify charges.The backup shall consist of payroll sheets,documented contract payments,copies of paid invoices for material and equipment,approved vehicle charges,and line item budget codes. Invoices paid by Utilities for Intertie approved items shall be submitted to AEA within 60 days after the Utility month end closing in which the payment was made.The Utilities shall provide the budget committee a quarterly report describing the non-routine projects that have been performed. The Utility that has incurred or made a firm commitment to incur an expense for the Intertie that will cross over the fiscal year end,shall notify the Budget Subcommittee by June 30.The notification shall identify the expense,the estimated amount,and the approximate time payment will occur. No invoice shall be paid by AEA if the IOC budget line item amount approved is exceeded until authorized by the Budget Subcommittee. The Budget Subcommittee shall have the authority to modify line item amounts if the total Intertie budget is not exceeded by 5%. All invoices shall be processed in the order received;however,non-Utility invoices shall be processed first. AEA shall provide quarterly reports by the 15"working day following the end of the fiscal year quarter to the Budget Subcommittee.Revenues,energy projections and use,line item expenses,investments,adjustments and any other pertinent data shall be reported. The budget shall be tied as close as practicable to the maintenance schedule. An audit may be conducted in accordance with Section 10.5 of the Alaska Intertie Agreement. Line item emergency expenditures or modifications,in addition to the approved IOC budget,require Budget Subcommittee review and IOC approval within 90 days of the action. h:\allistan\lOC\Invoice Policy\Alaska Intertie Invoice Policy -July 31,1996 O ALASKA INTERTIE OPERATING COMMITTEE AGENDA Thursday,May 20,1999 10:00 a.m. Municipal Light and Power Anchorage,Alaska (907)279-7671 Or Members Utility Phone Fax Email John Cooley CEA 762-4789 762-4540 Johncooley@chugachelectric.com Bob Drake MEA 761-9283 761-9328 Brad Evans GVEA 451-5655 451-5657 BWEvans@gvea.com Sam Mathews HEA 235-3303 235-3313 Smathews@xyz.net Bob Day ML&P 263-5295 263-5441 Dayrh@ci.anchorage.ak.us Stan Sieczkowski AEA 269-3024 269-3044 Ssieczkowsk@aidea.org I.Adoption of Prior Meeting Minutes A.February 18,1999 Ul.Approval /Modification of Agenda ll.Committee Reports and Correspondence IV.Visitor's Comments Related to Items on Agenda Dispatch Subcommittee Reliability /Protection Subcommittee Machine /Rating Subcommittee SCADA /Metering /Communication Sub Budget Subcommittee Maintenance Subcommittee Intertie Status Report Correspondence Received V.Recess Brad Evans,GVEA Luke Sliman,CEA Steve Gilbert,CEA Bob Day,ML&P Stan Sieczkowski,AEA Monte Ervin,GVEA 451-5655 563-7494 762-4446 263-5295 269-3024 451-5686 O ” Vil. Work Session 2D fINV= PF Dispatch Subcommittee a7)Spinning Reserve IssuesP)Line Switching Restrictions and Recommendations on .ge \.Reliability /Protection Subcommittee C Jee1.)4 Stage Load Shedding - Machine /Rating Subcommittee 1.)Joint Maintenance Labor and Spare Parts Agreement Update SCADA /Metering /Communications Subcommittee 1.)Stevens Sub Communications Reliability -Budget Subcommittee ItesAYFY99QuarterlyReportyy WRAY2,SVS Fund Custodian Agreement =4 PRCOVE . (25 FY 2000 Budget Maintenance SubcommitteeAY.Quarterly Maintenance ReportsPoContracts'ROW Clearing-MEA .)Snow Load Monitoring-MEA &Y2K Issues and Updates v4 MEA report for Dec.15 Intertie Outage Formal Operating Committee Actions /Recommendations A.Election of Officers <WITO e- BS B Nov Lian .verb lap dae,Subcommittee Assignments Ohececes .SEA ' Determine Agenda for Next MeetingMeetingLocation:AE Af INEAN Date:bog Time:|Q);OOAW Adjournment Y AFiasbley Stan Sieczkowski m:Hail,Doug W.[HallDW@ci.anchorage.ak.us]OC:Monday,May 17,1999 12:58 PM :'ssieczkowski@aidea.org' Subject:Trip 5/17/99 On 5/17/99 at 0524 the Teeland/Douglas line tripped when Bkr 538 opened at Teeland and B1 opened at Douglas.The Teeland relays showed a "C”phase to ground fault located 10.2 miles from Teeland.We had difficulty interrogating the Douglas relay's and were finally successful on the 3rd attempt.They showed a fault 611 miles from Douglas.1 out of the last 3 faults which were less than 1000 amps as measured at Teeland displayed useful data from the Douglas relay.|asked Ray Morgan of MEA to check into this and also check in the relay since we had a difficult time accessing that relay. |requested Vic Willis of MEA to do an aerial patrol of the line north of Hollywood road to try to determine what caused the trip. Doug Hall O ©MINIMUM INTERTIE nO ER CAPABILITY RIGHTS (MITCR)DETERMINATION SOUTHERN UTILITY PARTICIPANTS (MW) AML&P CEA AEG&T HEA MEA TOTAL NORTHERN UTILITY PARTICIPANTS (MW) FMUS GVEA TOTAL MITCR DETERMINATION AEG&T 31.90% AML&P 27.29% CEA 40.81% FMUS 0.00% GVEA 100.00% AFMITR2000.xis FOR FISCAL YEAR 1999 Annual System Demand 96-97 97-98 98-99 3 YR AVE. 150.0 145.0 151.0 220.7 220.4 79.4 74.8 97.6 93.1 540.5 MW 134.1 168.8 175.5 159.5 MW 159.5 MW FY 00 22.332 MW 19.103 MW 28.564 MW 0.000 MW 70.000 MW 140.00 MW PROPOSED UNITS FY 00 USEAGE KWH BUDGET $ MITCR KW ENERGY $.000/KWH : ENERGY 0.436 cents CAPACITY $/KW 5/19/99 .®)MINIMUM INTERTIE nOER CAPABILITY RIGHTS O (MITCR)DETERMINATION FOR FISCAL YEAR 1999 APPROVED APPROVED APPROVED 5/28/98 5/28/97 9/26/96 FY 99 FY 98 FY 97 REV.FY 97 FY 96 FY 95 FY 94 183,960,000 224,200,000 287,000,000 300,000,000 342,000,000 356,640,000 311,800,000 $1,133,805 $1,365,410 $1,142,662 $980,662 $1,272,704 $1,068,893 $1,402,776 440,000 140,000 140,000 140,000 140,000 140,000 140,000 5.146E-03 5.085E-03 3.324E-03 2.730E-03 3.11E-03 2.50E-03 3.76E-03 0.515 cents 0.509 cents 0.332 cents 0.273 cents .311 cents .25 cents .376 cents $1.34 $1.61 $1.35 $1.16 $1.50 $1.26 $1.65 AFMITR2000.xIs ataskQ rere FISCAL YEAR 1999 ENERGY PROJECTIONS FMUS AEG&T CEA ML&P MON TOTAL MONTH MWH MWH MWH (IN GVEA) Jul-99 Aug-39 Sep-99 Oct-99 Nov-99 Dec-99 Jan-00 Feb-00 Mar-00 Apr-00 May-00 S|Ol/O;o/Ololo'alaials!sJun-00 SIO/O(/S/alala\o/oalalo\oS/O;O/S/SO!SGiaiolaloloa\oFY 00 TOTAL 0 93,387 0 TOTAL INTERTIE PROJECTED ENERGY USAGE FOR FY 00 93,387 MWH {|__||| Section 8.2.2 MINIMUM USEAGE CONTRACT VALUE 183,960 MWH Alaska Intertie FY OO Usage Projections 51999.xis 1 5/19/99 O atas Qreene O FISCAL YEAR 1999 ENERGY PROJECTIONS FMUS GVEA AEG&T FMUS GVEA AEG&T |ML&P CEA CASH FLOW ENERGY CAPACITY TOTALS $0 $20,276 $0 $0 $79,100 $25,162 $21,689 $32,249 $178,476 $0 $63,500 $0 $63,500 $0 $80,154 $0 $80,154 $0 $41,160 $0 $41,160 $0 $12,863 $0 $12,863 $0 $25,725 $0 $25,725 $0 $25,725 $0 $25,725 $0 $12,863 $0 $12,863 $0 $10,290 $0 $10,290 $0 $41,160 $0 $41,160 $0 $36,015 $0 $36,015 $0 $110,746 $0 $110,746 $0 $480,476 $0 $0 $79,100 $25,162 $21,689 $32,249 $638,676 TOTAL REVENUE FROM APPROVED MWH $638,676 O&M BUDGET FY 00 $962,000 DIFFERENCE|($323,324) Alaska Intertie FY OO Usage Projections 51999.xls 2 5/19/99 O £7 ton gfeofe =fygen alategpdoxebm an ao o b-Sie at reaees. Ake Mee beeete TiWor.en ete bo!WEB mm Wes yd BS Teel i,_fave sfo AY PPLE LESD-, _evet 2Emus TEE.EZ,Wig:Look =GLEE EeshaREeneTahlyNatlaneteat.-Leeteed taf then fea M TO: CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska May 19,1999 Intertie Operating Committee Members FROM:John S.Cooley,Manager,Power Control &Fuel Manageme SUBJECT:Report of April 9,1999,Alaska Intertie Y2K Drill On April 9,1999,Chugach,ML&P,GVEA and HEA conducted a Y2K drill as authorized at the February 1999 meeting of the IOC.The drill was conducted using the attached drill guide.Operation without normal communications between Chugach and Bradley Lake and between ML&P and Eklutna were conducted between 0900 and 1100.Operation without AGC was exercised between 1230 and 1430.Chugach exercised operation of the Beluga power plant without normal communications between 1500 and 1700.All operations were satisfactory and no system disturbances occurred as a result of the drill.The drill demonstrated the utilities ability to operate satisfactorily with reduced communications facilities. Copies of participant evaluation questionnaires are attached.The following is a brief summary of areas for improvement: There is no SCADA indication when a Bradley Lake unit is placed in local control.Neither is there any alarm to indicate that a Bradley Lake unit is not responding to remote control. Local/remote status should be sent via SCADA. The HEA operator in Homer was not familiar with the location of the backup radio-phone to Bradley Lake and therefore it was not tested during the drill. The satellite phone has a significant time delay in it.Procedures and training are required for it to be of use in an emergency.It cannot be used as a regular phone. During operation without AGC,generation loading changes were made without telling the dispatcher to have them evaluate the need to alter the "interchange.”Frequency was satisfactorily maintained by the plant operators.Dispatchers should have discussed the desired changes for the interchange schedule prior to implementing them.Control was satisfactory but the inadvertent was unnecessarily increased. Distribution May 19,1999OReportofApril9,1999,Alaska Intertie Y2K Drill 2 Hourly accumulated generation values reported by Bradley Lake did not agree with SCADA reported values. 99JSC027.DOC Attachment:April 9,1999,Alaska Intertie Y2K Drill Guide (6 pages) Completed Participant Evaluation Questionnaire (11 pages) cc:Jim Borden File,RF O 99JSC027.DOC 5/19/99 O O April 9,1999 Alaska Intertie Y2K. Drill Guide At its February 1999 meeting,the Alaska Intertie Operating Committee agreed to conduct a Railbelt Y2K on April 9,1999.The Railbelt drill is not connected with NERC,which is conducting a nationwide Y2K drill on the same day. The primary purpose of the drill is to test backup communications and procedures for operating the interconnected Railbelt system with limited voice and data communications and reduced EMS/SCADA functionality.The following four main objectives were taken from the NERC Y2K Contingency Planning Task force: Review existing internal procedures to maintain critical data and voice information exchange in the event of the loss of one or more critical telecommunications facilities; Identify critical voice and data telecommunications channels and determine the information requirements necessary to continue operation;- According to procedures,personnel identify,obtain,and communicate key operating information sufficient to monitor and operate the system; Use alternative backup communications systems for data and voice communications. Participants: Drill Coordinator,John Cooley,Vice Chairman,IOC Chugach Dispatch Center AML&P Dispatch Center GVEA Dispatch Center Homer Office (HEA personnel) Bradley Lake Plant Operators (HEA personnel) Eklutna Plant Operators (MEA and AML&P personnel) Beluga Plant Operators (Chugach personnel) Plant Two Plant Operators (AML&P personnel) North Pole Plant Operators (GVEA personnel) Critical Cell Phone Numbers John Cooley,242-1404 Doug Hall,244-7048 Brad Evans,322-3816 Don Stead,399-1249of"1447 Drill Termination Criteria 1.If any utility suffers a major outage (loss of a substation or more of load)or feels that the weather or other conditions would significantly increase the risk of an outage if the drill were to continue,they are to contact the drill coordinator who will stop the drill. 2.Ifsystem frequency falls below 59.75 Hz or raises above 60.25 Hz each dispatch center shall immediately restore AGC control in the "flat frequency”mode.The dispatch supervisors shall consult with each other to decide how to restore interchange schedules. 3.During the drill,any communication regarding a real outage or emergency should be prefaced by "THIS IS NOT A DRILL.” Basic Procedures: 1.Communications starting a drill or to non-participants should be prefaced with "The Railbelt Utilities are conducting a Y2K Drill.” 2.Unit governors should remain operable to respond to frequency disturbances.They may be set for local control rather than remote AGC control. Overall Schedule for April 9,1999 0800 Drill Coordinator checks with each utility to verify that there are no reasons not to conduct the drill scenarios. 0900 0900 1200 1230 1430 1500 1501 1502 1800 AML&P Dispatch Center conduct Eklutna Drill Scenario Chugach Dispatch Center conduct Bradley Lake Drill Scenario Complete critique forms for 0900 drills Commence No AGC Drill Scenario Complete critique forms for 1230 drill Chugach Dispatch Center conduct Beluga Plant Drill Scenario AML&P Dispatch Center conduct local drill scenario GVEA Dispatch Center conduct local drill scenario Complete critique forms for 1500 drills O O Loss of DivCom Microwave Link to Bradley Lake Scenario Communication Interfaces: Chugach Dispatch to Bradley Lake Critical Circuits: Chugach RTU at Bradley Lake AGC of units Phone circuits at Bradley Lake Communications with operator Participants: Chugach Dispatcher Bradley Lake Operator HEA headquarters personnel Initial Conditions Bradley Lake units on-line,in remote,Chugach AGC control Chugach AGC in "tie-line bias”mode,other units in normal control Bradley Lake operator in control room HEA headquarters personnel available to use backup radio to Bradley Lake O Time Expected actions0900Simulatecommunication failure alarm indicating a loss of BLRTU signals and BL Ringdown capability,Bradley Lake operator places units in local 0915 Chugach dispatcher contacts HEA headquarters and requests HEA to establish backup communication contact with BL operator 0930 HEA establishes contact with BL via local radio and reports back to CEA 0940 CEA passes unit output schedule for remainder of day 0950 HEA confirms unit output schedule for remainder of day 1005 HEA confirms units at new schedule for hour 1015 HEA reports unit/plant outputs (MWh)for previous hour 1030 CEA changes schedule mid hour 1040 HEA reports completing schedule change 1105 HEA confirms units at new schedule for hour 1115 HEA reports unit/plant outputs (MWh)for previous hour 1130 Normal communications restored,units returned to remote 1140 Participants fill out post drill critique forms Additional Details: Loss of BL RTU: Unit governor set point would not change except by operator action Oo Panic AGC action is not available to assist with disturbances Loss of DivCom Microwave Link to Eklutna Scenario Communication Interfaces: AML&P Dispatch to Eklutna Critical Circuits: AML&P RTU at Eklutna AGC of units Participants: AML&P Dispatcher Eklutna Plant Operator AML&P Eklutna Maintenance Supervisor Initial Conditions Eklutna units on-line,in remote,AML&P AGC control AML&P AGC in "'tie-line bias”mode,other units in normal control Eklutna operator in control room Time Expected actions 0900 Simulate communication failure alarm indicating a loss of Eklutna RTU signals,Eklutna operator places units in local 0915 AML&P dispatcher contacts Eklutna operator via radio or phone 0940 AML&P dispatcher passes unit output schedule for remainder of day 0950 Eklutna confirms unit output schedule for remainder of day 1005 Eklutna confirms units at new schedule for hour 1015 Eklutna reports unit/plant outputs (MWh)for previous hour 1020 AML&P passes hour ending data to Chugach 1030 AML&P dispatcher changes schedule mid hour 1040 Eklutna reports completing schedule change 1105 Eklutna confirms units at new schedule for hour 1115 Eklutna reports unit/plant outputs (MWh)for previous hour 1130 Normal communications restored,units returned to remote 1140 Participants fill out post drill critique forms Additional Details: Loss of Eklutna RTU: Unit governor set point would not change except by operator action Panic AGC action is not available to assist with disturbances O System Operation without AGC Systems Scenario Communication Interfaces: AML&P Dispatch to Chugach Dispatch to GVEA Dispatch AML&P Dispatch to Plant Two Chugach Dispatch to Beluga Participants: AML&P Dispatcher Chugach Dispatcher GVEA Dispatcher Chugach Beluga Plant Operator AML&P Plant Two Operator Initial Conditions Additional Spinning reserves provided by Beluga 3 or 5 GVEA SILOS disabled All units in normal control from AGC Normal interchange flows and schedules in place Time Expected Actions 12:45 Dispatchers establish phone contact with plant operators and alert them that the system will be controlled manually from 1300-1400 12:45 AML&P establish satellite conference call among GVEA/CEA/ML&P dispatchers 13:00 Turn off AGC,Chugach control frequency,GVEA/ML&P control tie flow 13:30 ML&P assume frequency contro!,GVEA/CEA control tie flow 14:00 Resume AGC control,incorporate differences between scheduled and actual interchange as inadvertent 14:20 Participants fill out post drill critique forms Additional Details: Dispatchers have to manually perform the AGC function Calculate Area Control Error (ACE) Direct plants to raise or lower output in coordination with others Loss of Communications Link to Beluga Scenario Communication Interface: Chugach Dispatch to Beluga Power Plant Critical Circuits: Chugach RTU at Beluga Power Plant AGC of units Phone circuits at Beluga Power Plant | Communications with plant operator Participants: Chugach dispatcher Beluga Power Plant Operator Initial conditions: Beluga units on-line in remote with AGC control Chugach AGC in "tie-line bias”mode,other units in normal control Beluga Plant operator,ready to control units Time Expected Actions 1515 Simulate communication failure alarm resulting in loss of Beluga Plant RTU signal and Beluga Plant Ringdown capability.Beluga Plant operator places units in local 1520 Chugach Dispatch contacts Beluga Plant via radio,directs Beluga to maintain unit output,Dispatch maintains frequency/schedule with Bernice ,Cooper Lake and Bradley Lake units 1530 Chugach dispatch passes unit output schedule for remainder of day 1540 Plant operator confirms unit output schedule for remainder of day 1605 Plant operator confirms units at new schedule for hour 1615 Plant operator reports unit/plant outputs (MWh)for previous hour 1630 Dispatch changes schedule mid hour 1640 Plant operator reports completing schedule change 1705 Plant operator confirms units at new schedule for hour 1715 Plant operator reports unit/plant outputs (MWh)for previous hour 1730 Normal communications restored,units returned to remote 1740 Participants fill out post drill critique forms Additional Details: Loss of Beluga Plant RTU Units would control to whatever set point was in effect No panic AGC is available to assist in disturbances Changes in set point must be done by operator Operate Beluga to a schedule,regulate with other plants PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us prepare better exercises in the future, 1.Please rate the j3e lug cx Scenario exercise on the scale below: <2) 1 2 3 4 5 6 7 (3 9 10 Very Poor Very Good 2.Compared to previous drills,this was:lia 1 2 3 4 5 6 7 8 9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 6 7 @/9 10 Unprepared Very Prepared 4.The drill scenario needs to be modified to include the following: - 5.Please add any comments or criticisms on the following linefUOLA-Agr Le npteat TOMS wWere_leurbcefter-cen As 2ateba 5 oye CF 6.How do you think this process /procedure could be improved? - 7.How would you improve the pre-drill training? -_- 8.How could your participation in the drill have been more effective? 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us Opreparebetterexercisesinthefuture,+©9%a1.Please rate the |res S Scenario exercise on the scale below: 1 2 3 4 5 6 7 8 9 Very Poor Very Good 2.Compared to previous drills,this was:(Sv Dypri /Mok beeoge 1 2 3 #4 5 6 7 &)9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 6 7 8 ()10 Unprepared Very Prepared 4.The drill scenario needs to be modified to include the nakedLLTERLypegSOnw,Cham uss VU vu Lol rb wu wv err @ 5.Please add any comments or criticisms on the following line O 6.How do you think this Process /procedure could be improved?WMogy Presets Imuorninw Aur (0 Phacech 7.How would you improve the pre-drill training? 8.How could your participation in the drill have been more effective? 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? O | PARTICIPANT EVALUATION QUESTIONNAIREOPleasetakeafewmomentstofilloutthisform.Your opinions and suggestions will help uspreparebetterexercisesinthefuture, 1.Please rate the als Acker Scenario exercise on the scale below: 1 2 3 4 5 6 7 8&8 C&R 10 Very Poor Very Good 2.Compared to previous drills,this was: 1 2 3 4 5 6 7 8 9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 #5 6 7 (8 9 10 Unprepared Very Prepared 4.The drill scenario needs to be modified to include the following:Sty LS erased TS befé Ct Late lie 4. "prc lus A ne (cen p>bhnd A T=)fe charge.<bsccy.Dee ee Sl. 5.Please add'any comments or criticisms on the following lineKvcedeApecpe.Les az Ay bhngice in <eh Fate coo dun bendy pe,at Cerachrel(we, f-re ff.Ov pavbere Ona vee :f 6.How do you think this process /procedure could be improved? 7.How would you improve the pre-drill training? 8.How could your participation in the drill have been more effective? 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? drrtvec Coie 5.prop 7 id O PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us OpreparebetterexercisesintheAeCinefas|1.Please rate the 19 ad)ey Scenario exercise on the scale below: ( 1 2 3 4 5 6 7 8 C9;10 Very Poor Very Good 2.Compared to previous drills,this was: © Much Worse Ce Much Bettér 3.How well prepared for the drill were you: 1 2 3 4 +«=5 6 7 8 S&S 10 Unprepared ¥Prepared 4.The drill scenario needs to be modified to include the seeNAwbw=end ye?Ars{<>7D aA 'Ye.a+LG weedies) {-'wee i t 5.Please add any emgem's or criticisms on the piowns line OV2le.wi o.td port Lact ACY LybeadedSQCOL,ci \Wau s usd roy 6.How do you think this process /procedure could be improved? 7.How would you improve the pre-drill training? 8.How could your participation in the drill have been more effective? 9,What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation?. QL fod Xrest,C Weeses O PARTICIPANT EVALUATION QUESTIONNAIRE O Please take a few moments to fill out this form.Your opinions and suggestions will help uspreparebetterexercisesinthefuture, (oelug ©1.Please rate the (ze fe.|Scenario exercise on the scale below: 1 2 3 4 5 6 7 8 @ 10 Very Poor Very Good 2.Compared to previous drills,this was: i 2 3 4 #5 6 7 8 (9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 6 7 8 9D 10UnpreparedVeryPrepared 4.The drill scenario needs to be modified to include the following: O 5.Please add any comments or criticisms on the following lineVepukeCasaayyork22>fv Wve.LL bn baw.>tye 3,' 6.How do ie think this process /procedure could be improved?-Cone VEC e 7.How would you improve the pre-drill training?Lunidecote pec We,at A ractralitmes ved #styty.2)A LCA tref Pree pa te ir Cevtign 8.How could your participation in the drill have been more effective? pak éoe Wie 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? ale ce [An MSE ->ea d cl iP 7 yee cy ; )4 O PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us prepare better exercises in the future, 1.Please rate the Bu Scenario exercise on the scale below: 1 2 3 4 CG)6 7 8 9 10 Very Poor Very Good 2.Compared to previous drills,this was: 1 2 3 4 5 6 7 8 9 10 MLA Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 CJ 7 8 9 10 Unprepared Very Prepared 4.The drill scenario needs to be modified to include the following: 7 sve Or Whe MIP CEA pha dule chews oe oe ; 5.Please add any comments or criticisms on the following line 6.How do you think this process /procedure could be improved? 7.How would you improve the pre-drill training? 8.How could your participation in the drill have been more effective? 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? ooN.w9 to at DA gran Sarin y 74 2?youd Ain bde.ror U PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us prepare better exercises in the future, fy .1.Please rate the No AGC Scenario exercise on the scale below: 1 2 3 4 5 (64 7 8 9 10 Very Poor Very Good 2.Compared to previous drills,this was: 1 2 #3 4 +5 (6)7 8 9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 (6)7 8 9 10 Unprepared Very Prepared 4.The drill scenario needs to be modified to include the following: 4.aYeodATOercrenaeyPbwockehes |bed dn ansee. \.T 5.Please add any comments or criticisms on the following line Sh suo 0 Cy,Auras 2.£0 anh fy ot\}. 6.How do you think this process /procedure could be improved?Shox a9 Anve Spr.Jrnc8)abe iun ma fou,Cu,Po ane Ay dete 7.How would you improve the pre-drill training?\I TLR pe VeeerngisancareCoyalsitaaoa)'ot hea Coma Oa 68a Saw S| 8.How could your participation in the drill have been more effective? 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? 04-09-89 14:36 From-GVEA ENERGY SUPPLY 9074515697 Jr097 P.UZ/UZ =m sH3 GOLDEN VALLEY ELECTRIC ASSOCIATION OPARTICIPANTEVALUATIONQUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us prepare better exercises in the future, _1.Please rate the _4-9-99 Scenario exercise on the scale below: 1 2 3 4 5 ©)7 8 9 10 Very Poor Very Good 2.Compared to previous drills,this was:N/A 1 2 3 4 5 6 7 8 9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 6 7 8 C9 )10 Unprepared Very Prepared 4.The drill scenario needs to be modified to include the following: Add GVEA as frequency controller.Create schedule Odisturbanceineachcontrolarea. 5.Please add any comments or criticisms on the following line Satellite phone needs to be improved.Passive antenna in Healy control room is needed to improve radio. Headquarter base station on old VHF did not work. 6.How do you think this process /procedure could be improved? It went well and demonstrated our ability to regulate schedules manually. 7.How would you improve the pre-drill training? Did not need any. 8.How could your participation in the drill have been more effective? See #4, 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? N/A O SR ced hetZornns lala a -O03-|lysy 2€:)lorm PRU e O JNLEP -lexs Oo Comme £Kutoe PARTICIPANT EVALUATION QUESTIONNAIRE .Please take a few moments to fill out this form.Your opinions and suggestions wil]help us prepare better exercises in the future, 1.Please rate the uP)elkuwsScenario exercise on the scale below: Api234567/778)9 10 Very Poor Very Good 2.Compared to previous drills,this was:(z Herve WETGreve IPATED Berore ) ]2 3 4 5 6 7 8 9 10 Much Worse Much Better 3.How well prepared for the drill were you: 1 2 3 4 5 6 7 (8)9 10 Unprepared Very Prepared 4,The drill scenario needs to be modified to include the following: 5.Please add any comments or criticisms on the following line 6.How do you think this process /procedure could be improved? 7.How would you improve the pre-drill training?More Ny sevesion YR wR 8.How could your participation in the drill have been more effective?By Voee Pre -DRiLL Drie cussion) 9.What tools or equipment should be provided to facilitate.your participation in the drill?In real-life situation? "ps/ag SL SEN ar"yo loos ef 1werri 0 mess Pe SEL)yt 34 T3907 7A5 6116 EXLUTNAPOWITESRSeTtes es Jus oF Fh UTmIAAL Corm Te Ex - --- __PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions wil]help us',prepare better exercises in the furure, 1.Please rate the YZ bo Scenario exercise on the scale below: Tr 2 3 4 5S 6 7 &@)10VeryPoorVeryGood 2.Compared to previous drills,this was: 1 -2 3 4 b}6 7 $8 9 10 Much Worse .Much Better 3.How well prepared for the drill were you: 1 2 3 4 S 6 7 &(@&10Unprepared|Very Prepared .'4.The drill scenario needs to be modified to include the following: 5.Please add any comments or criticisms on the following line A Fin) )'.Vi,fos 6.How do you think this process /procedure could be improved? 7.How would you improve the pre-drill training? 8.How could your participation in the drill have been more effective? 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation?; a7OS"(ura <:torrm rr PARTICIPANT EVALUATION QUESTIONNAIRE Please take a few moments to fill out this form.Your opinions and suggestions will help us prepare better exercises in the future, 1.Please rate the Wo KES Scenario exercise on the scale below: I 2 34S BRO IO Very Poor C8?Very Good 2.Compared to previous drills,this was:(x Have vor Been Ww Fz Eviev>s ON tLe ) 1 2 3 4 5 6 7 .8 9 10 Much Worse Much Better 3.How well prepared for the drill were you: i 2 #3 4 «5 (6)7 8 #9 10UnpreparedVeryPrepared 4.The drill scenario needs to be modified to include the follewing:When raigdP Afra 1s OFF -THEM EKiuTUAPIUSTBEAckBWLlED(rED Fup /UCLUBEN S.Please add any comments or criticisms on the ee Teeauw,SaATELUTE Howes Lowek 6.How do you think this process /procedure could be improved} 7.How would you improve the pre-drill training?Meee Dieaussiony ANESD 8.How could your participation in the drill have been more effective?Moke DiScusSiopn)pH ETS 9.What tools or equipment should be provided to facilitate your participation in the drill?In real-life situation? ,Y-9-GF 'SYSS O Miter98.xls 5/20/99 CHUGACH ELECTRIC ASSOCIATION,INC. Anchorage,Alaska Determination of Minimum Intertie Transfer Capability Rights 1998/1999 System Peak:02/04/99 @ Hour Ending 19:00 Hourly AEG&T Utility 18:15 18:30 18:45 19:00 Average MEA 103.3 104.0 103.8 103.9 103.8 HEA 76.7 76.9 77.4 774 77.1 | 180.9 Chugach Electric System Peak 412.0 Less:AEG&T Coincident Peak 180.9 Total (MW)231.1 1997/1998 System Peak:01/05/98 @ Hour Ending 19:00 Hourly AEG&T Utility 18:15 18:30 18:45 19:00 Average MEA 93.0 92.4 93.6 93.2 93.1 HEA 75,3 74.9 74.8 74.3 74.8 167.9 Chugach Electric System Peak 388.3 Less:AEG&T Coincident Peak 167.9 Total (MW)220.4 1996/1997 System Peak:01/07/97 @ Hour Ending 19:00 Hourly AEG&T Utility 18:15 18:30 18:45 19:00 Average MEA 96.8 97.7 97.0 97.6 97.3 HEA 79.4 78.8 78.8 79.2 79.1 176.3 Chugach Electric System Peak 397.0 Less:AEG&T Coincident Peak 176.3 Total (MW)220.7 Boy NeyJAN79,402 <-79,402A'FEB 64,291 64,291 ®MAR 65,672 65,672 APR 59,679 59,679 MAY 59,142 59,142 JUN 58,062 58,062JUL65,778 65,778 AUG 62,907 62,907 SEP 57,130 57,130 OCT 68,731 68,731 q,NOV 72,368 72,368 X DEC 74.011 74,011 nt 1997 787,173 787,173 "JAN 75,866 <-75,866 FEB 68,454 68,454 MAR 67,984 67,984 APR 63,882 63,882 MAY 61,250 61,250 JUN 62,720 62,720"JUL G4]66,605 66,605 AUG 64,381 64,381PDSEP60,667 60,667adOCT66,610 66,610 NOV 73,832 73,832 DEC 78,848 78,848 1998 811,099 811,099 JAN 78,080 78,080 FEB 81,291 <--81,291 O FY99 AEA VOICE/DATA CIRCUITS PROJECTIONS CKT NO FY1999 RATE |FY1999 COST FY2000 COST|FY2000 251-CIRCUIT MILES cost A<>F INTERTIE SYSTEM ] a 1001 APA/CNTWL PH 106.00 4.47 5,685.84.7.34,9,336.48 1002 Fbks<>DivCom 260.46 4.47 13,971.07,|ss (sisi7.84)22,941.321003Dgls-DivCom __41.27 4.47 2,213.72;|=ss«s7.34/--(3,635.061004sTeeland-DivCom 7 24.47 4.47|1,312.57 7 7.34)2,155.32 1007 |Fbks<>DivCom Chg 8-1-97,__260.46 4.47 13,971.07|,7.341 22,941.32 1008|CEA<>DivCom Chg8-1-97,|«4.00 4.47 21456,|«7.84 352.32 1009. =|CEA-DGLS 41.00)447,2,19924 |"7.34,3,611.28 1011 |MTA<>DivCom Chg8-1-97 ||-386.65 -447/-1,965.91||7.34:3,228.132002.|GVEA-CNTWUSTVNS/DGLS|234.00]_4.47 12,551.76,7.34,20,610.72 2003 -_-[Dgls-Div Com ft 44.27 447|___2,213.72)|7.34)_-Ss«3,635.062004./DGLS TLDN XFER TRIP |21.00 4.47 1.126.445 |7.34)1,849.682005=|Teeland-DivCom _24.47 447 1,312.57)|7.34 2,185.322007S|APA/ANC-FAIDATA#2,-|263.00,4.47,14,107.32),;7.34:23,165.04 2008 DOUGLAS RTU (CEA)41.00 4.47 2,199.24 7.34/3,611.282016|AEA/MEA DGL-CHLT 46.00 4.47 2,467.44 7.34 4,051.68 2017 |AEA/CEALKHD-CHLT 83.01,4.47,4,452.66,7.34 7,311.52 2018 __|Chulitna-Div Com 86.33 4.47 4630.74,|7.34 7,603.95 A <>F INTERTIE TOTALS 1,614.39 86,595.88 142,195.47 VOICE/DATA CIRCUITS (ABOVE)|_142,195.47|RADIOS (Next page),51,931.87-SPACE &POWER (page 3)!___5,429.76TotalFY2000CommunicationsRSAforAKIntertie!199,557.10 Prepared by K.D.Langill F:\FY98SLD\Dis rsa §/19/99 O FY99 AEA RADIO CIRCUIT PROJECTIONS CKT 1999PER|1999 2000 PER 2000 NO 251-CIRCUIT MILES MILE |ANNUAL MILE ANNUAL A<>F INTERTIE SYSTEM _- 0201 +|CNTWL-TRK RDO #1 106.07|$68.40]7,255.19 $97.92|10,386.37 0202 |CNTWL-TRK RDO #2 106.07|$68.40!7,255.19 $97.92|10,386.37) 0203 |CNTWL-TRK RDO #3 106.07!$68.40|7,255.19 $97.92|10,386.37): 0204 _|CNTWL-TRK RDO #4 106.07,$68.40!7,255.19 __$97.92|10,386.37,0205 _|CNTWL-TRK RDO #5 106.07)$68.40|7,255.19 $97.92 |10,386.37 Z Ac>F INTERTIE TOTALS 530.35 36,275.94 51,931.87) Prepared by KD Langil!F:\FY98SLD\Dis rsa 5/19/99 O FY99 AEA SPACE POWER PROJECTIONS SPACE &POWER BILLING -2000 1998 ANNUAL |1999 ANNUAL ANNUAL LOCATION EQUIPMENT COST COST |COST A<>F INTERTIE SYSTEM Cantwell VHF Repeater 2682.36 2,886.00 2,714.88 Chulitna MEA Microwave 2682.36 2,886.00 7 2,714.88 Teeland UHF Base Station A<>F INTERTIE TOTALS §,364.72 5,772.00!5,429.76 Prepared by K.D.Langili F:FYO8SLD\Dis rsa 5/19/99 03-02-99)03-27-99 CANTWELL SUBSTATION O7 970-0001-00 16206 ELECTRIC RATE:GENERAL SERVICE 1 MEMBER USAGE HISTORYOKWH01/14/99 PREV READ 48341 Clb 37402/22/99 CURR READ 54668 FEB-99:6327 39 162 MULTIPLIER 1 JAN-99:4777 27 177 KWH USED 6327 EST :DEC-98 1982 30 66 NOV-98:2086 30 70 PREVIOUS BALANCE 450.76 OocT-98 2095 26 81 TOTAL PAYMENTS 450.76-EST :SEP-98:1140 34 34 Oe nal:2|49 Sune 410-0064-00 AUG 98:1059 30 35 JUL-98 868 29 30 AECL Wr 3-8-9 . JUN-98 1441 |32 45 E-SO\-SbZpo-3d\Q.AS NO e ,MAY-98 1719 31 55 APR-98:1933 32 60 Cape sued 4 ls Whey MAR-98 2174 27 81 WA ,FEB-98 2794 31 90 BALANCE FORWARD 00 CUSTOMER CHARGE 20.00 "GVEA IS YOUR BUSINESS -GET INVOLVED. KWH CHARGE 700.57 , FUEL CREDIT 159,38-Your Co-op's Member Advisory Committee REGULATORY CHG 1.77 "a (MAC)needs you.The MAC serves in an advisory capacity to the Board of Directors,meets once a month and volunteers are compensated.Volunteer deadline is March 22.All members are eligible and can volunteer by phone. , MAC members will be selected by lottery. ELECTRIC Call 452-1151 for more information. CURRENT BALANCE 562.96 TOTAL DUE 562.96 562.96 a YOUR FUEL CREDIT OF $.02519 PER KWH RESULTED FROM GVEA'S REDUCED FUEL COSTS,ECONOMY ENERGY PURCHASES AND FT.KNOX GOLD MINE MARGINS. MONIES WILL BE APPLIED TO THE ELECTRIC PORTION OF YOUR ACCOUNT FIRST RETAIN THIS PORTION FOR YOUR RECORDS -cere-- GOLDEN VALLEY ELECTRIC ASSOCIATION P O BOX 71249 FAIRBANKS AK 99707-1249 (907)452-1151 OR 1-800-770-4832 r CATIO 03-02-994 03-27-99 HEA SPUR TOWER #765 ELECTRIC RATE:GENERAL SERVICE 1 KWH 01/21/99 PREV READ 5632602/25/99 CURR READ 56964 Ci S S 75 FEB-99)638 35 18 MULTIPLIER 1 JAN-99:659 30 22 KWH USED 638 DEC-98:371 27 14 Nov-98 134 30 4 PREVIOUS BALANCE 96.23 OcT-98 105 27 4 TOTAL PAYMENTS 96.23-SEP-98 105 33 3 CR roh Haq Duce Aloo -O1VS-00 AUG-98 98 28 4 Cos eeet JUL-98 86 34 3 +a\, JUN-98 67 29 2 fb -Sw-Sb&V4.4 >She MAY-98 106 31 3 maarred t APR-98'399 32 12CFMAR-98:450 28 16 FEBT9S:|.611 330 20 BALANCE FORWARD CUSTOMER CHARGE KWH CHARGE FUEL CREDIT REGULATORY CHG O ELECTRIC GVEA IS YOUR BUSINESS -GET INVOLVED. Your Co-op's Member Advisory Committee (MAC)needs you.The MAC serves in an advisory capacity to the Board of Directors,meets once a month and volunteers are compensated.Volunteer deadline is March 22.All members are eligible anda can volunteer by -phone. MAC members will be selected by lottery. Call 452-1151 for more information. CURRENT BALANCE 94.43 DELINQUEN TOTAL DUE 94.43 94.43 17 YOUR FUEL CREDIT OF $.02519 PER KWH RESULTED FROM GVEA'S REDUCED FUEL COSTS,ECONOMY ENERGY PURCHASES AND FT.KNOX GOLD MINE MARGINS. MONIES WILL BE APPLIED TO THE ELECTRIC PORTION OF YOUR ACCOUNT FIRST RETAIN THIS PORTION FOR YOUR RECORDS « GOLDEN VALLEY ELECTRIC ASSOCIATION P O BOX 71249 FAIRBANKS AK 99707-1249 (907)452-1151 OR 1-800-770-4832 03-02-994--63-27-99 HEALY SUBSTATION 960-0065-00 32294 ELECTRIC RATE:GENERAL SERVICE 1 MEMBER USAGE HISTORY KWH01/21/99 PREV READ 67908 G@}oS DL02/25/99 CURR READ 69474 FEB-99:1566 35 45 MULTIPLIER 1 JAN-99)1327 30 44 KWH USED 1566 DEC 98:987 27 37 NOV-98:904 30 30 PREVIOUS BALANCE 153.74 OCcT-98 600 27 22 TOTAL PAYMENTS 153.74-SEP-98:425 33 13 OX ro}B44 Seis A'o-CcO'S-O9 AUG-98 277 |28 10 Aes:<e %-S-FA4 :.JUL-98:151 34 4 JUN-98'226 29 8 MAY 98 439 31 14 APR-98 569 32 18 MAR-98 727 28 26 FEB-98 1039 30 35 BALANCE FORWARD -00 CUSTOMER CHARGE 20.00 : , GVEA IS YOUR BUSINESS -GET INVOLVED. KWH CHARGE : 193.33 FUEL CREDIT 39.45-Your Co-op's Member Advisory Committee REGULATORY CHG 44 (MAC)needs you.The MAC serves in an advisory capacity to the Board of Directors,meets once a month and volunteers are compensated.Volunteer deadline is March 22.All members are eligible and can volunteer by phone.O MAC members will be selected by lottery. ELECTRIC Call 452-1151 for more information. CURRENT BALANCE 174.32 PASEDUEL i DELINQUE TOTAL DUE 174.32 174.32 | YOUR FUEL CREDIT OF $.02519 PER KWH RESULTED FROM GVEA'S REDUCED FUEL COSTS,ECONOMY ENERGY PURCHASES AND FT.KNOX GOLD MINE MARGINS. MONIES WILL BE APPLIED TO THE ELECTRIC PORTION OF YOUR ACCOUNT FIRST RETAIN THIS PORTION FOR YOUR RECORDS May-18-99 04:23pm From-GVEA ENERGY SUPPLY 9074515657 T 047 =P.03/03-F-307 |[VV on™VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 «Falrbanks,Alaska 99707-1249 *907-452-1181 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 MITCROcalculationforGVEA.1996-1997 1997-8 1998-1999 134.1 Mw 168.8 MW 175.5 Mw 'Re Ss,AB ee"Brad Eva System Dispatch Manager mm RASTA wre VT. May-18-99 04:22pm =From-GVEA ENERGY SUPPLY 9074515657 T-047 =P.02/03 --F-307 |(3V Orr VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 *Fairbanks,Alaska 99707-1249 ©907-452-115] May 18,1999 Stan Sieczkowski Alaska industrial Development and Energy Authority 480 West Tudor Anchorage,AK 99503-6690 Subject:FYOO 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 §,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 System Dispatch Manager _ +,Cienye cc:Mike Kelly Robert Hansen Steve Haagenson O Stan Sieczkowski m:John Cooley [John_Cooley@chugachelectric.com] t:Friday,March 05,1999 3:05 AM :ssieczkowski@aidea.org Cc:Brian_Hickey@chugachelectric.com;Paul_Risse@chugachelectric.com Subject:Alaska Intertie FYOO Budget Chugach's budget request for regular maintenance for Teeland in FY2000 is $10,600.No extra ordinary maintenance is planned. vay-19-94 10:22am =From-GVEA ENERGY SUPPLY 9074515657 T-048 =P .01 F 311 -Mailing'Address:Physical Address: PO Box 71248 758 Illinois St. Fairbanks AK 99707-1249 Fairbanks AK 99701-2999O@Phone:(907)451-5655 @Fax:(907)451-5657 E-mail address:bwevans @ gvea.com Fax To:Stan Sieczkowski From:Brad Evans Firm:AIDEA Re:FY00 Intertie Operating Budget Fax:(907)269-3044 Pages:18 (including cover sheet) Phone:(907)269-3024 Date:05/19/99 0 Urgent 0]For Review 0D Piease Comment 0 Please Reply Note:If there were any problems receiving this fax,please cail:Maureen Camey @ (907)451-5661. @ Comments:Here is Golden Valley's FY0O Intertie Budget.It is in two sections;1.LineOMaintenance,and 2)Substation Maintenance.Original will follow in the mail. May-198-89 10:22am =From-GVEA ENERGY SUPPLY 9074515657 T 048 ==P.02 F-311 ”GV Oo VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 «Fairbanks,Alaska 99707-1249 »907-452-1151 May 18,1999 Stan Steczkowski 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 FYOQ0 budget submittal for:O 1.NORTHERN HALF TRANSMISSION LINE MAINTENANCE AND WORK PLAN 2.SUBSTATION PREVENTIVE MAINTENANCE PLAN FOR HEALY,GOLD HILL, AND CANTWELL SUBSTATIONS aeSystemDispatch Manager cc:Monte Ervin Mike Wright O May 19-88 10:22am From-GVEA ENERGY SUPPLY 9074515657 T-048 ==P.03 F-311 Rev.5-99 FY 2000 ANCHORAGE FAIRBANKS INTERTIE TRANSMISSION LINE MAINTENANCE (Northern 1/2) AND WORK PLAN Summary Yearly Cost 3 ea.Routine Patrols $12,582 1 ea.Ground Patrol 15,000 1/10 Climbing Inspection 31,800 Insurance 1,750 TOTAL TRANSMISSION LINE MAINTENANCE (Northern 1/2)§61,132 Special Projects Re-level Structures and Adjust Guys $30,000 Rebuild and Reclear Landing Pads 45,000 ROW Reclearing 29,000 TOTAL SPECIAL PROJECTS $95,000 Page 1 May-19-99 10:22am From-GVEA ENERGY SUPPLY 9074515657 T-048 =P.04 F-311 Rev,5-99OFy2000 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 AFA Preliminary Draft Routine Patrols,Aerial Special Patrols,Aerial Emergency Patrols,Aerial Ground Patrols Climbing Inspections There are many conditions that cccur which cause operating problems on a transmission line or limit its useful life.The above maintenance tasks will help discever these conditions and O corrective action may prevent serious damage or line failure. Page 2 O May-19-98 10:22am From-GVEA ENERGY SUPPLY 9074515857 T-048 «=P.O5/18 =F311 Rev.5-93 FY 2000 ANCHORAGE-FAIRBANKS INTERTIE PREVENTIVE MAINTENANCE BUDGET INTERTIE TRANSMISSION LINE NORTHERN PORTION Routine Patrols Routine visual aerial inspection patrol.Pilet 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 6)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/fhelicopter 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 Pear 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 -r _°ma Lee An An ita) May-19-98 10:23am =From-GVEA ENERGY SUPPLY 9074515657 T-048 «=P.06/18 =Fe3t1 O 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.) O May-19-99 10:23am From-GVEA ENERGY SUPPLY 9074515657 T-048 =P.O7/18 =F311 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 1 hr st 63.14 63.14 Equipment Equipment Manhaul lL 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 8 750/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) 2) rd Supervision and recordkeeping costs are included in the overhead for the manhour rate. More helicopter time,in addition to that shown,may be necessary for access on routine ground patrol and climbing insnections. O O May-19-99 10:23am =From-GVEA ENERGY SUPPLY 9074515657 T-048 «=P.08/18 =F311 Rev.5-99 Special Projects 1.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. 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. 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. mMmAMAT SnRATAT RDA THAMA -4ac AAA O May-19-99 10:23am From-GVEA ENERGY SUPPLY FY 2000 9074515657 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 Page 7 T=048 =6P.09/18 =FH3tt Rev.5-99 Cost per Hour $15.00 12.00 20.00 65.00 100.00 60.00 7.00 20.00 70.00 100.00 65.00 100.00 25.00 105.00 15.00 150.00 O May-19-99 10:24am From-GVEA ENERGY SUPPLY Position STRAIGHT TIME Dispatcher Electrician/Lineman Accounting Superintendent OVERTIME Dispatcher Blectrician/Lineman Accounting 9074515657 T-048 FY 2000 GVEA LABOR COSTS Current GVEA Base Rate Overhead $34.40 $44.72 $32.30 $41.99 $29.55 $38.42 $36.80 $47.84 $51.60 $44.72 $64.60 $41.99 $44.33 $38.42 Page 8 P.10/18 =F311 Rev.5-99 Total cost/ Manhour $79.12 $74.29 $67.97 $84.64 $96.32 $106.59 $82.74 O May-19-98 10:24am =From-GVEA ENERGY SUPPLY $074515657 ACCOUNT NUMBERS AEA INTERTIE MAINTENANCE BASIC ACCOUNT NUMBERS Transmiasgion Operation 560 Operation Supervision and Engineering 562 Station Expense $63 Overhead Line Expense Transmission Maintenance 568 Maintenance Supervision and Engineering 570 Maintenance of Station Equipment 571 Maintenance of Overhead Lines Detailed Accounting Codes Tieline HLS Substation Operation/Man/hr.562.10 Inventory Substation Maintenance Man/ur.570.10 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 (xepair &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 INA Ee Orne Ad non Wee STR PrN AA realaan O T-048 «=P.11/1B 0 F-311 Rev.5=99 cws GHS DGS 562.11 562.12 562.14 570.11 570.12 570.14 May=19-99 10:24am =From=GVEA ENERGY SUPPLY 9074515657 T-048 =P.12/18 F311 Rev.5-99O Fy 2000 ANCHORAGE-FATRRANKS INTERTIE SUBSTATION PREVENTIVE MAINTENANCE PLAN AND BUDGET HPS,GHS,CwSs SUMMARY Yearly Costs SCADA Maintenance $21,284 Walk Through Monthly Inspection 23,607 Minor Inspections 9,453 Major Inspections 9,984 Insurance 500 O Ama?SWS SME PAT WFR PRN VISTA ETAT aera aAN May-19-89 10:24am =From-GVEA ENERGY SUPPLY 9074515657 T-048 «=P.13/18 =F-311 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 to wan awe - O May-19-99 10:24am From-GVEA ENERGY SUPPLY 9074515657 T-048)«-P.14/18 --F-311 FY 2000 ALASKA INTERTIE SUBSTATION PREVENTIVE MAINTENANCE PLAN AND BUDGET Walk Through Monthly Inspection Visual and walk-through This can be accomplished in a normal working day. Rev.5-99 inspection once a month on each substation. Time Per Hour Total Yearly Blectrician Inspection 8 hre ST $74.29 $594.32 Vehicle Manhaul 8 hrs ST $12.00 $96.00 Total each $690.32 (HLP,GHS,CWS)$690.32 x 3 =$2070.96 $2070.96 x 12 months =$24,851.52 Minor Inspection Once a year.Visual and operational inspections,electrical testing and cleaning,oil samples,recloser load tap equipment--each substation. Time Per Hour Total Foreman 16 hrs ST $74.29 $1188.64 Electrician 16 hrs ST $74.29 $1188.64 Vehicle Manhaul 16 hrs ST $12.00 $192.00 Substation Maint.Tk #177 16 hrs ST $45.00 $720.00 Total each $3,289.28 (HLP,GHS CWS)$3289.28 x 3 = Major Inspection changing Yearly $9,867.84 Once every six years.Remove equipment from service and check for operation and work on under clearance --each substation. Labor Time Per Hour Total Foreman 40 hrs sT $74.29 $2971.60 Two Electricians 40 hrs ST ea $74.29 ea $5943.20 Tana Tinnewan ARM lnenen OM ata AN ANNA en Yearly May-19-99 10:25am From-GVEA ENERGY SUPPLY 9074515657 T-048 =P.15/1B =F-311 . .Rev.5-99 Major Inepection (continued) O 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 S$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 O Insurance Special Insurance Required by Contract S$500.00 SCADA Maintenance Normal maintenance for GHS,HLS (2),S$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. --a ae aoe -=_am arr an oD May-19-99 10:25am =From-GVEA ENERGY SUPPLY 9074515657 T-048 P.16/18 =F-311 Rev.5-99 Fy 2000OGVEA_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 5 May-19-88 10:25am From-GVEA ENERGY SUPPLY 9074515657 T-048 =P.17/18 =F-311 Rev.5-99 Fy 2000OGVEALABORCOSTS Total Current GVEA Cost/ Position Base Rate Overhead Manhour STRAIGHT TIME Dispatcher $34.40 $44.72 $79.12 Blectrician/Lineman $32.30 $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 Wlartviatan/Tinamsn ¢eGa EN f&#araa ea1nc cn May-19-89 10:28am =From-GVEA ENERGY SUPPLY 9074515657 T048 «=0P.18/18F-311 °Rev.5-99 ACCOUNT NUMBERS O AEA INTERTIE MAINTENANCE BASIC ACCOUNT NUMBERS Transmission Operation 560 Operation Supervision and Engineering 562 Station Expense 563 Overhead Line Expense frangmission Maintenance 568 Maintenance Supervision and Engineering 570 Maintenance of Station Equipment 571 Maintenance of Overhead Lines Detailed Accounting Codes Tieline HLS Cws GHS DGS Substation Operation/Man/hr,$62.10 562.11 562.12 562.14 Inventory Substation Maintenance Man/Hr.570.10 570.11 570.12 570.14 Working Patrol Ground Mile 563.11 Aerial Patrol Mile §63.10 O°imbing Inspection Structure 563.12 Insulator (replace)String 571.10 Right-of-Way Reclear Acre 571.11 and Treatment Culvert &Gate Fach 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 Pmnwardt ama Cee nweed ad nue Ree we ITIee PPA AA ern ce a O O ALASKA INTERTIE OPERATING COMMITTEE AGENDA Thursday,May 20,1999 Municipal Light and Power Anc 10:00 a.m. horage,Alaska (907)279-7671 Members Utility Phone Fax Email John Cooley CEA 762-4789 762-4540 Johncooley@chugachelectric.com Bob Drake MEA 761-9283 761-9328 Brad Evans GVEA 451-5655 451-5657 BWEvans@gvea.com Sam Mathews HEA 235-3303 235-3313 Smathews@xyz.net Bob Day ML&P 263-5295 263-5441 Dayrh@ci.anchorage.ak.us Stan Sieczkowski AEA 269-3024 269-3044 Ssieczkowsk@aidea.org I.Adoption of Prior Meeting Minutes A.February 18,1999 ll.Approval /Modification of Agenda WI.Committee Reports and Correspondence A.Dispatch Subcommittee Brad Evans,GVEA 451-5655 B.Reliability /Protection Subcommittee Luke Sliman,CEA 563-7494 C.Machine /Rating Subcommittee Steve Gilbert,CEA 762-4446 D.SCADA /Metering /Communication Sub Bob Day,ML&P 263-5295 E.Budget Subcommittee Stan Sieczkowski,AEA 269-3024 F.Maintenance Subcommittee Monte Ervin,GVEA 451-5686 G.Intertie Status Report H.Correspondence Received IV.Visitor's Comments Related to Items on Agenda V.Recess Vi.Work Session©A.Dispatch Subcommittee 1.)Spinning Reserve Issues 2.)Line Switching Restrictions and Recommendations B.Reliability /Protection Subcommittee 1.)4"Stage Load Shedding C.Machine /Rating Subcommittee 1.)Joint Maintenance Labor and Spare Parts Agreement Update D.SCADA /Metering /Communications Subcommittee 1.)Stevens Sub Communications Reliability E.Budget Subcommittee 1.)FY 99 Quarterly Report 2.)SVS Fund Custodian Agreement3.)FY 2000 Budget F.Maintenance Subcommittee 1.)Quarterly Maintenance Reports 2.)Contracts a.)ROW Clearing-MEA b.)Snow Load Monitoring-MEA G.Y2K Issues and Updates H.MEA report for Dec.15 Intertie Outage VIL.Formal Operating Committee Actions /Recommendations A.Election of Officers Vill.Subcommittee Assignments IX.Determine Agenda for Next Meeting Meeting Location:Date:Time: X.Adjournment "O ALASKA INTERTIE FY 2000 PROPOSED BUDGET April 13,1999 REVENUES GVEA MLP CEA AEGT FMUS INTEREST TOTAL REVENUES EXPENSES FERC 561 -Load Dispatching GVEA Northern Controller MLP Southern Controller AFI Other FERC 562 -Station Operation Expenses GVEA -substation electricity usage FERC 563 -Overhead Line Expenses GVEA -Weather monitoring equipment FERC 565 -Transmission of electricity by others MEA Wheeling -Holly Rd to Douglas FERC 566 -Miscellaneous transmission expense SCADA &voice circuits (SOA) Cell phones for weather monitoring Weather monitoring maint (batteries) Revenues include full year capacity billing Wheeling charges at Contract rate. Intertie Communications Circuits AT&T through 1/16,Mactel Charges through 2/16 Replacement of batteries APPROVED PROPOSED BUDGET Budget FY 1999 FY 2000 §/28/98 5/19/99 NOTES: 510,031 563,280 25,720 22,920 38,242 34,541 33,725 34,134 0 0 0 0 607,718 654,875 0 0 0 0 0 7,500 7,500 0 7,500 7,500 220,476 220,000 220,476 220,000 31,029 32,000 31,029 32,000 131,300 199,600 8,000 10,000 20,000 20,000 159,300 229,600 O h:all\elaine\aki\file:FYOO Budget.xls\ws:oO BRq "O ALASKA INTERTIE FY 2000 PROPOSED BUDGET April 13,1999 FERC 567 -Transmission Expenses -Rents Rents -Alaska Railroad MEA-Talkeetna Storage FERC §70 -Maintenance of station equipment GVEA -Healy Cantwell,Goldhill CEA Teeland Substation MEA-Douglas substation Extraordinary maint -GVEA Extraordinary main -CEA -CB &Transform Extraordinary maint -MEA -batteries FERC §71 -Maintenance of overhead lines Maintenance of Overhead Lines -Other GVEA Northern Maintenance MEA Southern Maintenance Weather monitoring equipment maintenance Extraordinary Maintenance -GVEA Extraordinary Maintenance -MEA MEA-Landing Pads GVEA-Landing Pads GVEA-Tighten Guys GVEA-Moody Creek Slide Study GVEA-Northern ROW clearing MEA-Southern ROW clearing APPROVED PROPOSED BUDGET Budget FY 1999 FY 2000 5/28/98 §/19/99 NOTES: 600;Annual lease payment. 7,200 7,200]Annual lease payment. 7,200 7,800 50,000 64,828 |Routine 10,000 10,000 |Routine 10,000 10,000 |}Routine 0 0 23,600 0 6,500 0 100,100 84,828 0 0 50,000 61,132 |Routine 21,500 31,500 |Routine 60,000 60,000 |Routine and report 0 0 31,000 0 45,000}Rebuild and/or clear 30,000 30,000}Routine 30,000 0 20,000 20,000]Routine 92,000 25,000]Routine 334,500 272,632 h:all\elaine\aki\file:FYOO Budget.xts\ws:O BR "O ALASKA INTERTIE FY 2000 PROPOSED BUDGET April 13,1999 FERC 920 -AEA Administrative Costs Personal Services,travel and other costs FERC 920 -1OC Administrative Costs Legal Expense 1OC -Gen Prof Services FERC 924 -Property Insurance AF Intertie -Insurance Risk Management Fee Line of Credit Fee TOTAL EXPENSE SURPLUS (SHORTAGE) APPROVED PROPOSED BUDGET Budget FY 1999 FY 2000 §/28/98 5/19/99 NOTES: 76,300 60,000 76,300 60,000 75,000 25,000 35,000 0 110,000 25,000 80,000 82,000 6,200 6,200 1,200 0 87,400 88,200 1,133,805 1,027,560 (526,087)(372,685 h:all\elaine\aki\file:FYOO Budget.xis\ws:oO BR ALASKA INTERTIE FISCAL YEAR 1999 ENERGY PROJECTIONS FMUS AEG&T CEA ML&P MON TOTAL MONTH MWH MWH MWH (IN GVEA) Jul-99 Aug-99 Sep-99 Oct-99 Nov-99 Dec-99 Jan-00 Feb-00 Mar-00 Apr-00 May-00 Jun-00 C/O/O/O/Oj;OlD/O1ol|o/o|oC/OHOl/OlSiO/O/C!olol;o|aOC/OLO/OS!O/O/q/ol|alol|oFY 00 TOTAL 0 93,387 1,344 (=)0 94,731 TOTAL INTERTIE PROJECTED ENERGY USAGE FOR FY 00 94,731 MWH ||| Section 8.2.2 MINIMUM USEAGE CONTRACT VALUE 183,960 MWH "O FY 00 Usage Projections 51999.xls OQ” ALASKA INTERTIE FISCAL YEAR 1999 ENERGY PROJECTIONS FMUS GVEA AEG&T FMUS GVEA AEG&T /|ML&P CEA CASH FLOW ENERGY CAPACITY TOTALS $0 $18,381 $205 $0 $84,700 $27,240 $22,920 $34,541 $187,986 $0 $63,500 $386 $63,885 $0 $80,154 $643 $80,797 $0 $41,160 $643 $41,803 $0 $12,863 $1,029 $13,892 $0 $25,725 $1,029 $26,754 $0 $25,725 $1,029 $26,754 $0 $12,863 $515 $13,377 $0 $10,290 $386 $10,676 $0 $41,160 $386 $41,546 $0 $36,015 $386 $36,401 $0 $110,746 $257 $111,003 $0 $478,580 $6,894 $0 $84,700 $27,240 $22,920 $34,541 $654,874 TOTAL MWH REVENUE $654,874 O&M BUDGET FY 00 $1,027,560 DIFFERENCE ($372,686) "CO FY 00 Usage Projections 51999.xIs 5/20/99O MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS (MITCR)DETERMINATION FOR FISCAL YEAR 1999 Annual System Demand SOUTHERN UTILITY PARTICIPANTS (MW) 96-97 97-98 98-99 3 YR AVE. PROPOSED AML&P 150.0 145.0 151.0 148.7|MW CEA 220.7 220.4 231.1 224,1|MW UNITS FY 00 AEG&T 176.7 |MW HEA 79.4 75.8 81.3 USEAGE KWH 183,960,000 MEA 97.6 93.1 103 BUDGET $$1,027,560 MITCR KW 140000 TOTAL 549.5|MW ENERGY $.000/KWH 4.664E-03 NORTHERN UTILITY PARTICIPANTS (MW)ENERGY 0.466 cents FMUS CAPACITY $/KW $1.21 GVEA 134.1 168.8 175.5 159,.5|MW TOTAL 159.5|MW MITCR DETERMINATION FY 00 AEG&T 32.16%22.514|MW AML&P 27.06%18.940|MW CEA 40.78%28.546|MW FMUS 0.00%0.000 |MW GVEA 100.00%70,000);MW 140.00|MW "oO 8)CQ MINIMUM INTERTIE TRANSFER CAPABILITY RIGHTS (MITCR)DETERMINATION FOR FISCAL YEAR 1999 APPROVED APPROVED APPROVED 5/28/98 5/28/97 9/26/96 FY 99 FY 98 FY 97 REV.FY 97 FY 96 FY 95 FY 94 183,960,000 224,200,000 287,000,000 300,000,000 342,000,000 356,640,000 311,800,000 $1,133,805 $1,365,410 .$1,142,662 $980,662 $1,272,704 $1,068,893 $1,402,776 140,000 140,000 140,000 140,000 140,000 140,000 140,000 5.146E-03 5.085E-03 3.324E-03 2.730E-03 3.11E-03 2.50E-03 3.76E-03 0.515 cents 0.509 cents 0.332 cents 0.273 cents .311 cents .29 cents .376 cents $1.34 $1.61 $1.35 $1.16 $1.50 $1.26 $1.65 O OQ" Mip Municipal Light &Power GENERAL MANAGER 1200 East First Avenue Anchorage Alaska 99501-1685 phone 907.263.5201 tax 907.263.5205 e-mail kohterm@cl.anchorage.ak.us 1 P @€tit y Oo F qa N ©H O R A G E May 19,1999 Chugach Electric Association P.O.Box 196300 Anchorage,AK 99502-0300 Attention:John Cooley IOC Chairman Dear Oley: Please regard this letter as notification,effective immediately,that Robert Day is now ML&P's representative at 1OC meetings.He replaces Tim McConnell.Hank Nikkels will serve as alternate. Sincerely, Varn QLMeeraKohler General Manager c:Railbelt General Managers Rick Mystrom =Mayor eee)LT) = {7-29-1999 1:43PM FROM MLP POWER MGT/OPS 907 263 5441 P.1 Matanuska Electric Ba-t ith Foy Note T7671 Dale04/78 4a »fsaeaeWw.Swe ee CA ee Fs ASSOCIANIOD,LLC.%STA From deveweePsaecsDeaeCONEAyDBae°MLS | P.O.Box 2929 Phone #Phone # Palmer,Alaska 99645-2929 fine fax ® Telephone:(907)745-3231 Fax:(907)743-9328 December 23,1998 Tim McConnell”4200 East FirstA Avenue Anchorage,Alaska 99501 John Cooley Chugach Electric Association,Inc. Post Office Box 196300 Anchorage,Alaska 99519-6300 Dear Sirs: SUBJECT:INTERTIE OUTAGE OF DECEMBER 15,1998 The ground fault that occurred on the Intertie on December 15,1998 appearsto haveproducedatransferredpotentialeventthatdamagedapproximately50Turtletransmitters inware.ihe Wiliuw -Nancy Lakes aed. Until further investigation can be completed,Matanuska Electric Association (MEA)Fallarwtne Pi nn ndi ee Phe ee lee Saw be Pie.tae tamatomtan a -8.TeQuesis QI CeeRY Operating Pioceuur|S tor ine Dougias "neay ie Waly. . a. ” a, 2a 4, Me mk 2A Hee Panll Te mntn nn antannseeiae £€a.ld la wwtiaontjteCcaNaeR1kAEUMUCBCLIU isolate fautad sediion taaving Sunniv available at Stevens Suhatation Nuiify maintenance coniraciors for inspeciion prior to re-energizing of fauitedi Section, Your cooperation is appreciated. Sincerely yours Waar ery ---FARaymond Morgan,PLE.Staff Engineer fam tV342/1 27 Sesintertieoutage.acecc:Bob Drake.Ooeratians Mananer MUNICIPAL LIGHT &POWER POWER MANAGEMENT MEMORANDUMMEP DATE:February 05,1999 TO:10C Dispatch Subcommittee Members FROM:ML&P,Southern Operator,Alaska Intertie SUBJECT:Quarterly Reliability Report,October Through December 1998 REF:Ref.General Managers Agreement,December 15,1994 This report is in two parts. PART 1 -EXECUTIVE SUMMARY 1.Atthe March 15,1995 meeting,the |OC established by unanimous vote the reporting criteria to be used for the Quarterly Reliability Report as directed in the December 15,1994 Agreement. These are listed below: a.All events which cause frequency excursions greater than +or -.2 Hz.b.All unit trips,and trips of transmission lines or transmission facilities greater than 69 kV. c.Spinning reserve deficiencies which are in excess of 20%of a utility's requirement or .5mW which ever is less for at least 3 consecutive hours for more than 2 days or any systematic pattern of abuse. d.Any event which a Dispatch Subcommittee Member or 1OC Member determines should be investigated. PART 2 -EVENT SUMMARY 1.During this quarter,the Intertie tripped open two times,for a total of 38 hours and 12 minutes.a.Dec.15 at 16:02 Teeland breakers 538 and 5110,Douglas breaker 138-B1,and HLP breaker 1B17 trip open;"C”phase to ground fault,approximately 5 miles north of Douglas Sub.Cause unknown.Time closed 18:08,duration 6 minutes 28 seconds. b.Dec.15 at 18:30 Teeland breakers 538 and 5110,Douglas breaker 138-B1,and HLP breaker 1B17 trip open;phase-to-phase fault (A &B phases)approximately 11.8 miles south of Healy. Cause unknown.Time closed Dec.17 at 08:35,duration 38 hours,5 minutes and 54 seconds. 2.During this quarter there were 30 reported disturbances caused by 25 unit trips,four transmission line outages,and one from other causes.These disturbances resulted in 13 SILOS operations,four Load Shed operations,and two Protective Relay operations. 3.During this quarter there were no scheduled interruptions on the Alaska interconnected system. A4THQTR9I8 PAGE 1 lOC QUARTER ITY REPORT OCTOB BER PART 2 EVENT SUMMARY QTR.4 1998 EVENT EVENT FREQUENCY |.INTERTIE..KENAS.UNIT..:LINE LOAD,LOAD SILOS ©COMMENTS NUMBER DATE TIME DESCRIPTION EXTREME OPENED .OPENED TRIP."TRIP AT TRIP)SHED : . (H2)eenees (MN) :.nee wR bese :'ieee QMO Ben Ry Bee cae abet ata EE ee ba 15 2-Oct 10:35 CEA Beluga Unit 6 tip §9.13 Cause unknown,loss of most of Unit 8 116 5-Oct 05:16 CEA Beluga Unit 6 trip 58.98 Cause unknown,loss of most of Unit 8.Load Shed, .AMLP 8.62,CEA 7.6,HEA 2.5,GVEA 24.4,MEA 18.0mw W7 6-Oct 01:10 Healy Unit 1 trip 59.68 NO NO x 23.80 X Trip on turbine vibration,GVEA SILOS 3.6mw 118 6-Oct 11:55 AMLP Unit 4 trip 59.96 NO NO x 7.66 Trip white control testing on gas 119 T-Oct 09:33 AMLP Unit 4 Load Rejection Test 59.90 NO NO x 9.96 Load rejection test 120 7-Oct 14:47 Healy Unit 1 trip 59.93 NO NO x 7.00 Hot bearing causes unit tip 121 7-Oct 15:51 AMLP Unit 8 trip 59.37 NO NO x 64.44 X Cause unknown,GVEA SILOS 16.4mw 122 80a 14:04 AMLP Unit 8 trip 59.52 NO NO x 45.27 X Cause unknown,GVEA SILOS 8.2mw,AMLP SILOS 2.16mw 123 12-Oct 11:47 AMLP Unit 8 trip 59.12 NO NO x 71.21 X Computer contro!problems,GVEA SILOS 22.8mw 124 13-Oct 11:36 JBP tips (Chena 6)59.74 NO NO x 20.00 Cause unknown 125 13-Oct 17:01.ZNS B4 opens MVA overload CHS Unit 5 trip §9.52 NO NO x 19.00 X AMLP SILOS tmw,GVEA SILOS 2.1mw 126 15-Oct 05:47 AMLP Unit 7 backs off line 59.75 NO NO 42.02 Unit 7 backs off line,low atomizing air pressure 127 16-Oct 11:22 AMLP Unit 4 trip §9.92 NO NO x 748 Trip while testing oil to gas transfer 128 16-Oct 12:12 Healy Unit 2 tip 59.93 NO NO x 1.90 Cause unknown 129 21-Oct 08:42 AMLP Unit 5 trip 59.68 NO NO x 25.23 Cause unknown 130 30-Oct 09:54 Healy Unit 1 trip 59.94 NO NO x 24.30 Cause unknown 131 3Nov 07:53 Healy Unit 1 trip 59.66 NO NO x 28.50 X Boiler feed pump,GVEA SILOS 6.5mw 132 24-Nov 12:14 Healy Unit 2 tip 59.45 NO NO x 56.30 X Cause unknown,GVEA SILOS 6.7mw,Other relays 27.6mw13327-Nov 15:12 CEA Intemational Bkr 1516 trip 59.96 NO NO Contractor dug into 138kv underground cabie just west of Airport East Sub13430-Nov 10:14 CEA Beluga Unit 8 trip 59.72 NO NO x 20.90 Cause unknown 135 5-Dec 09:28 AMLP Unit 5 tip 59.68 NO NO x 28.80 X Trip on high vibration,GVEA SILOS 4.7mw 134 14-Dec 21:23 Quartz Creek Soldotna 69 kV line lockout 59.99 NO NO Cause unknown 138 15-Dec 16:02 _Intertie Open Teeland,Douglas and Healey 60.26 YES NO 15.10 X Teetand 538 &§110,Douglas 136-81 and HLP 1817 open,cause unknown close at 18:08.GVEA SILOS 8.3mw,Other relays 5.2mw, MEA Load Shed 3.8mw,Time open 6 min.,28 sec 136 15-Dec 18:30 -Intertie Open Teeland,Douglas and Healey 60.08 YES NO 4.30 X -Teeland 538 &5110,Dougias 138-B1 and HLP 1817 open,cause unknown Relays indicate fault 11.8 miles south of Healy.Close 17 Dec 08:35:23 GVEA Other relays 0.4mw,MEA Load Shed 3.8mw Time open 38hrs,5 min.,54sec 137 19-Dec 09:37 Healy Unit 2 trip 59.51 NO NO XxX 35.00 X Cause unknown,GVEA SILOS 6.5mw 138 19-Dec 12:25 Healy Unit 2 trip §9.92 NO NO x 10.00 Cause unknown 139 19-Dec 19:57 Healy Unit 2 trip 59.56 NO NO x 29.10 X Cause.unknown,GVEA SILOS 7.2mw 140 20-Dec 09:28 Healy Unit 2 tip 59.67 NO NO x 25.50 X Cause unknown,GVEA SILOS 8.8mw,AMLP SILOS 1.0mw 141 20-Dec 12:21 Healy Unit 2 trip 59.74 NO NO 'X 22.10 Cause Unknown . 142 31-Dec 11:12 Healy Unit 1 trip 59.75 NO NO x 25.90 Bearing failure 4THOTROB Page 2 FEB-17-99 14:48 FROM:GVEA OPERATIONS ID:3074515618 PAGE 2/72 1e = Intertie Maintenance Summary GVEA October 98 thru Dec 98 October 98 Acct.#570.10 Healy Substation Monthly check Acct.#570.12 Goldhill Substation monthly Check and intertie share of Doble engineering reports Nov.98 No billings for this month Dec.98 O Acct.#563.10 Regular Aerial Patrol patrol Acct,#570.10 Healy substation monthly check and SVS check Acct.#570.12 Goldhill substation monthly check Acct.#571.10 Switching for work on southern portion of the intertie.. FEB-17-99 14:46 FROM:GVEA OPERATIONS ID:8S074515618 PAGE 1/2 \e O Mailing Address:Physical Address:"ert PO Box 71249 758 Ullinois St,'GoldenFairoanksAK99707-1249 Fairbanks AK 99701-2irban 999 Valley #Phone:(907)451-5686 «Fax:(907)451-5618 Electric i < E-mail address:mrervin@ gvea.com :Associatiion,|sachetseasWE To:Stan Seiczkowski From:Monte R.Ervin Firm:AIDEA Re:Quarterly report of Accounts Fax:269-3044 Pages:2 including cover sheet Phone:269-3024 Date:Feb.16,1999 Urgent For Review Please Comment Please Reply Note:If there were any problems receiving this fax,please call:Monte R.Ervin @ (907)451-5686. @ Comments: Stan attached find the quarterly report.I'll give a copy to Brad for the Conference Call tomorrow. Golden Valley Electric Assn. "Power You Can Count On!" PO Box 71249 °(907)452-1151 Fairbanks AK 99707.°(800)770-GVEA Date:[1-30 -98 To.Ot Gn From:fackeg dbp besten S8OSHereistheinformationIpromisedtosendyou. Star,pat tat.Cap ts "ee dnd)6.bere of.ptel Apes sath eeTANoahe.lng ak.ise te off ibeCpptakBro!to higpuplaterosthoThe0€. We paves ALi Mag (!VU 0 -_ Special Services ...just for GVEA members Energy$ense Programs We offer three electrical energy efficiency pro- grams.Home$ense provides in-home education and product installation.Builder$ense offers rebates to home builders who install electrically efficient products.Business$ense offers rebates to commercial members for lighting retrofits. Easy Pay Option Easy Pay automatically transfers your monthly electric payment directly from your checking or savings account to GVEA. Utility Payment Drop Boxes Installed at Fred Meyer West and North Pole SuperValu,these centers offer another convenient payment option for GVEA,College Utilities Corp.and GCI customers. Between Tenants Agreement (BTA) Landlords,have electric service continue at your rental when tenants request a disconnection-automatic transfer of service. Removal of Danger Trees Do you havea tree that is growing into or at risk of falling into a power line?If the tree is a power line hazard,GVEA will remove it-at no cost. V Opowwen VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 «Fairbanks,Alaska 99707-1249 ©907-452-1151 November 24,1998 EGelVeMeeraKohler .General Manager pn..Anchorage Municipal Light &Power DEC -2 19981200EastFirstAveAlaskaIndustrialDevelopment Anchorage AK 99501 and Export Authority Dear Ms.Kohler: ;( The Intertie Operating Committee (IOC)respectfully requests that you evaluate and execute the enclosed Agreement Between Railbelt Utilities to Share Generation Equipment Spare Parts.The IOC formally and unanimously recommended execution of the agreement at their November 19 meeting.The Procedure for Generation Parts Sharing is also included. O Please return the signed agreement to my attention at Golden Valley by early February1999sincewewouldliketofinalizethisagreementattheFebruary18,1999 IOC meeting. If you have any questions,please call me at 907-451-5609. Sincerely, },/) Marvin D.Riddle airman,Alaska Intertie Operating Committee kag Enclosure (3V Oho:VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 «Fairbanks,Alaska 99707-1249 ©907-452-1151 November 24,1998 Eugene N.Bjornstad General Manager Chugach Electric Association Inc PO Box 196300 Anchorage AK 99519-6300 Dear Mr.Bjornstad: The Intertie Operating Committee (IOC)respectfully requests that you evaluate and execute the enclosed Agreement Between Railbelt Utilities to Share Generation Equipment Spare Parts.The IOC formally and unanimously recommended execution of the agreement at their November 19 meeting.The Procedure for Generation Parts Sharing is also included. O Please return the signed agreement to my attention at Golden Valley by early February1999sincewewouldliketofinalizethisagreementattheFebruary18,1999 lOC meeting. If you have any questions,please call me at 907-451-5609. Sincerely, Tr 1r JD pd li.in D.Riddle Chairman,Alaska Intertie Operating Committee kag Enclosure [VV Opowen VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 «Fairbanks,Alaska 99707-1249 *907-452-1151 November 24,1998 Norm Story Alaska Electric Generation &Transmission Inc c/o Homer Electric 3977 Lake St Homer AK 99603 Dear Mr.Story: The Intertie Operating Committee (IOC)respectfully requests that you evaluate and execute the enclosed Agreement Between Railbelt Utilities to Share Generation Equipment Spare Parts.The IOC formally and unanimously recommended execution of the agreement at their November 19 meeting.The Procedure for Generation Parts Sharing is also included. O Please return the signed agreement to my attention at Golden Valley by early February1999sincewewouldliketofinalizethisagreementattheFebruary18,1999 IOC meeting. If you have any questions,please call me at 907-451-5609. Sincerely, in D.Riddle Chairman,Alaska Intertie Operating Committee kag Enclosure (VV Ojos VALLEY ELECTRIC ASSOCIATION INC.PO Box 71249 «Fairbanks,Alaska 99707-1249 *907-452-1151 November 24,1998 Mike Kelly President and CEO Golden Valley Electric Association PO Box 71249 Fairbanks AK 99707-1249 Dear Mike: The Intertie Operating Committee (IOC)respectfully requests that you evaluate and execute the enclosed Agreement Between Railbelt Utilities to Share Generation Equipment Spare Parts.The IOC formally and unanimously recommended execution of the agreement at their November 19 meeting.The Procedure for Generation Parts Sharing is also included. O Please return the signed agreement to my attention at Golden Valley by early February1999sincewewouldliketofinalizethisagreementattheFebruary18,1999 l|OC meeting.- If you have any questions,please call me at 907-451-5609. Sincerely, »/)oO bbe Mawin D.Riddle Crairman,Alaska Intertie Operating Committee kag Enclosure O O Agreement Between Railbelt Utilities to Share Generation Equipment Spare Parts The parties to this agreement are Anchorage ML&P,Chugach Electric Association,Inc., Alaska Generation &Transmission,Inc.and Golden Valley Electric Association,Inc. Whereas,the parties have power generating facilities that contain similar equipment and have substantial capital invested in spare parts,and Whereas,many of these spares are stocked to reduce the risk of lengthy equipment downtime due to critical equipment failure,and Whereas,many parts suppliers have very limited shelf stock available for purchase on short notice,and Whereas,the parties have benefited in the past by sharing each other's critical spare parts when needed for emergency equipment repairs. NOW,THEREFORE,the parities do hereby agree to the following: The agreement shall become effective upon the date of its execution and shall continue in effect for three (3)years upon mutual agreement. During the term of this agreement,the parties will all implement the attached procedure for sharing of spare parts,including a means of receiving and replacing them in a timely manner.(See attached Parts Sharing Procedure). The parties will pursue ways of optimizing spare parts inventories to enable all parties to obtain maximum benefit from a shared capital investment. IN WITNESS THEREOF,the parties have caused the Agreement to be duly executed as of the day and year set forth. BY:/__/ Anchorage Municipal Light &Power BY:/_| Alaska Electric Generation &Transmission BY:/_e/ Chugach Electric Association,Inc. BY:/__/ Golden Valley Electric Association,Inc. Il. Procedure for Generation Parts Sharing All parties shall establish a blanket purchase order with each of the other parties for the purchase of spare parts from any of the other parties. Spare parts may be purchased from any of the other parties to this agreement under the following stipulations. a.New parts shall be replaced in kind.The seller does not warranty the part however,where possible,the manufactures warranty may be transferred from one party to the next. New parts price shall be agreed to and shall be equal to the replacement part price Used parts will have no warranty. Used parts prices will be negotiated and agreed to prior to transfer.In any case,the price for a used part shall not exceed the price of a new part. A time line for replacement of the part by the purchasing party to the supplying party shall be agreed to before the transfer of a part. 2-16-1999 12:54PM FROM MLP POWER MGT/OPS 907 263 5441 Power Management Municipal Light &Power Fax Transmittal 1200 East First Avenue, Anchorage,Alaska 99501Misp(907)263-5455 phone(907).263-5441 fax To:Distribution Below From:Robert Day,Acting Manager,Power Mgmt Fax:Pages (Including Cover):3 Phone:Date:2-16-99 Re: Urgent For Review Please Comment Please Reply Other Comments: Attached is the 4th Quarter,1998,IOC Quarterly Reliability Reports. Distribution: Stan Sieczkowski,AEA,269-3044 Jonn Cooley,CEA,762-4540 Brian Hickey,CEA,762-4540 Brad Evans,GVEA,1-907-451-0556 Marv Riddle,Chairman lOC,(GVEA),1-907-451-5633 Sam Matthews,HEA,1-907-235-3305 Ray Morgan,MEA,(807)745-9339 -1 O 2-16-1999 12:55PM FROM MLP POWER MGT/OPS 9@7 263 5441 MEP MUNICIPAL LIGHT &POWER POWER MANAGEMENT MEMORANDUM DATE: TO: FROM: SUBJECT:Quarterly Reliability Report,October Through December 1998 REF February 05,1999 lOC Dispatch Subcommittee Members ML&P,Southern Operator,Alaska Intertie Ref.General Managers Agreement,December 15,1994 This report is in two parts. PART 4 --EXECUTIVE SUMMARY 1,At the March 15,1995 meeting,the LOC established by unanimous vote the reporting criteria to be used for the Quarterly Reliability Report as directed in the December 15,1994 Agreement. These are listed below: a. b, c. All events which cause frequency excursions greater than +or -.2 Hz. All unit trips,and trips of transmission lines or transmission facilities greater than 69 kV. Spinning reserve deficiencies which are in excess of 20%ofa utility's requirement or .6mW Which ever is less for at least 3 consecutive hours for more than 2 days or any systematic pattern of abuse. Any event which a Dispatch Subcommittee Member or IOC Member determines should be investigated. PART 2 --EVENT SUMMARY 1.During this quarter,the Intertie tripped open two times,for a total of 38 hours and 12 minutes. a.Cec.15 at 18:02 Teeland breakers 538 and 5110,Douglas breaker 138-B1,and HLP breaker 1B17 trip open;"C”phase to ground fault,approximately 5 miles north of Douglas Sub,Cause unknown.Time closed 18:08,duration 6 minutes 28 seconds. Dec.15 at 18:30 Teeland breakers 538 and §110,Douglas breaker 138-B1,and HLP breaker 1B17 trip open;phase-to-phase fault (A &B phases)approximately 11.8 miles north of Douglas Sub.Cause unknown.Time closed Dec.17 at 08:35,duration 38 hours,5 minutes and 54 seconds. 2.During this quarter there were 30 reported disturbances caused by 25 unit trips,four transmission line outages,and one from other causes.These disturbances resulted in 13 SILOS operations,four Load Shed operations,and two Protective Relay operations. 3.During this quarter there were no scheduled interruptions on the Alaska interconnected system. 4ATHQOTR93 PAGE 1 IOC QUARK RELIABILITY REPORT OCTOBER-DECEMBER 1298 PART2 EVENT SUMMARY 4THQTROB 09:37 19:57 12:24 11:12 CEA Beluga Unit6 trip CEA Beluga Unit 6 vip Healy Unit f trip ANP Und 4 tip AMLP Uni 4 Load Rejection Test Healy Und 4 trip AMLP Unk 8 tip AJALP Unit tip AMLP Unit 4 tip JBP trips (Chena 6) 2NS 84 opens MVA overicad CHS Unit5 tip AMLP Unk?backs off line AMLP Unk 4 tip Healy Unit 2 bip AMLP Unit 5 tip Haly Unit §tip Healy Unit ¢tip Healy Unit 2 inp CEA Intemational Bly 1618 tipCEABelugaUna8trip AMLP Uni 5 trip Quartz Creek Soldotna 69 kV line lockout Wntertie Open Teeland,Douglas end Healey Inertia Open Teetand,Qouglas and Healay Healy Unit 2 bip Healy Unil 2 vip Healy Unit 2 bip Healy Una 2 bip Healy Una 2 brip Healy Unit trip x x NO NO x NO NO x NO NO % NO NO x NO NO x NO NO x Ko NO x HO NO x Oo NO x NO NO NO NO x NO NO x NO KO x NO Oo x NO KO x NO wo x NO NO x NO NO x NO NO Xx NO NO x YES NG x YES NO x no NO x Eile)NO x NO NO Xx NO NO x NO NO x NO Oo x Page 2 35.00 28.10 25.50 22.10 25,90 aCause unnown,oss of most of Unit"Cause unkaaym,oes of most of Unit 8.Load Shed, AMLP 8.82,CEA 7.6,HEA 2.5,GYEA 24.4,MEA 16.0nn Trip on turbine vibration,GVEA SILOS 3.6nwTripwhilecontoltestingongas Load rejection teat Hol bearing causes unit ire Camis unknown,GVEA SILOS 16.40 Cause unknown,GVEA SILOS 6.2an,AMLP SILOS 2.16ma Computer conirel problems,GVEA SILOS 22.8 Cause unknown AMLP SILOS 1mm.GVEA SFLOS 2.4mw Unit 7 backs off line,low atomizing alt pressure Trip wie tesling of to gas Iransfer Cause unknown Cause unknown Cause unknown Bofer feed pump,GVEA SILOS 6.5mwCauseuncaiown,GVEA SILOS 6.7m,Other relays 27.80 Contractor dug into 138kv underground cable just west of Airport East Sud Cause unknown Trip on high wWhralion,GVEA SILOS 4.7017 Cause unknown Tealand §38&5110,Douglas 138-69 and HLP 1817 open,cause unioncloseat18:08.GVEA SILOS 8.30,Other relays 5.2rwe,MEA Load Shed 3.dmve,Time open 6 min.,26 sec Tesland£38 &6410,Douglas 136-61 and HLP 1B17 open,cause unknownRetaysindicatefault11.8 miles north ofGouglas.Close 17 Dec 60:34:23 GVEA Otter relays 0.4:nw,MEA Load Shed 3.8m Time open 368rs,5 nin,S450 Cause unknown,GVEA SILOS 6.5muw Cause unknown Cause unknown,GVEA SILOS 7 2riwCausemknown,GVEA SILOS 4.nuw,AMLP SILOS (drm Cause Unknown Bearing feture fl6661-91-2WSIvrPS€922406SdO/LOWSHSMOdDWWOdS Y 5/20/99/9:06 AM ALASKA INTERTIE FY 2000 PROPOSED BUDGET April 13,1999 O Revenues include full year Wheeling charges at Contract rate. »Intertie Communications Circuits AT&T through 1/16,Mactel Charges through 2/16 Replacement of batteries Page 1 APPROVED PROPOSED BUDGET Budget FY 1999 FY 2000 5/28/98 §/19/99 NOTES: REVENUES GVEA 510,031 563,280 MLP 25,720 22,920!capacity billingCEA38,242 34,541 AEGT 33,725 34,134 FMUS 0 0 INTEREST 0 0 TOTAL REVENUES 607,718 654,875 JS EXPENSES FERC 561 -Load Dispatching GVEA Northern Controller 0 MLP Southern Controller 0 AFI Other 0 0 0 FERC 562 -Station Operation Expenses GVEA -substation electricity usage 7,500 7,500 0 7,500 7,500 FERC 563 -Overhead Line Expenses GVEA -Weather monitoring equipment 220,476 220,000 220,476 220,000 FERC 565 -Transmission of electricity by others MEA Wheeling -Holly Rd to Douglas 31,029 32,000 31,029 32,000 FERC 566 -Miscellaneous transmission expense SCADA &voice circuits (SOA)131,300 199,600 Cell phones for weather monitoring 8,000 ,000 Weather monitoring maint (batteries)20,000 20,000 159,300 229,600 h:allielaine\aki\file:FYOO Budget xls\ws:FY99 AKI BR _O 5/20/99/9:06 AM ALASKA INTERTIE FY 2000 PROPOSED BUDGET April 13,1999 FERC 567 -Transmission Expenses -Rents Rents -Alaska Railroad MEA-Talkeetna Storage FERC §70 -Maintenance of station equipment GVEA -Healy Cantwell,Goldhill CEA Teeland Substation MEA -Douglas substation Extraordinary maint -GVEA Extraordinary main -CEA -CB &Transform Extraordinary maint -MEA -batteries FERC §71 -Maintenance of overhead lines Maintenance of Overhead Lines -Other GVEA Northern Maintenance MEA Southern Maintenance Weather monitoring equipment maintenance Extraordinary Maintenance -GVEA Extraordinary Maintenance -MEA MEA-Landing Pads GVEA-Landing Pads GVEA-Tighten Guys GVEA-Moody Creek Slide Study GVEA-Northern ROW clearing MEA-Southern ROW clearing O APPROVED PROPOSED BUDGET Budget FY 1999 FY 2000 §/28/98 5/19/99 NOTES: 600)Annual lease payment. 7,200 7,200]Annual lease payment. 7,200 7,800 50,000 64,828 Routine 10,000 10,000 |Routine 10,000 10,000 |Routine 0 0 23,600 0 6,500 0 100,100 84,828 0 a) 50,000 61,132 )Routine 21,500 31,500 |RoutineX- 60,000 60,000 |Routine and report 0 0 31,000 45,000 rebut and/or clear 30,000 000}Routine 30,000 0}9&- 20,000 20,000}Routine 92,000 25,000}Routine 334,500 272,632 Page 2 h:all\elaine\aki\file:FYOO Budget.xls\ws:FY99 AKI BR »O ALASKA INTERTIE FY 2000 O+ 5/20/99/9:06 AM Page 3 PROPOSED BUDGET April 13,1999 APPROVED PROPOSED BUDGET Budget FY 1999 FY 2000 §/28/98 5/19/99 NOTES: FERC 920 -AEA Administrative Costs Personal Services,travel and other costs 76,300 60,000 xe 76,300 60,000 FERC 920 -10C Administrative Costs Legal Expense 75,000 29,000 10C -Gen Prof Services 35,000 0 110,000 25,000 FERC 924 -Property Insurance AF Intertie -Insurance 80,000 82,000 Risk Management Fee 6,200 6,200 Line of Credit Fee 1,200 0 87,400 88,200 TOTAL EXPENSE 1,133,805 1,027,560 Y SURPLUS (SHORTAGE)(526,087)(372,685 / h:all\elaine\aki\file:FYOO Budget.xls\ws:FY99 AKI BR ALAS ERTIE FISCAL YEAR 1999 ENERGY PROJECTIONS FMUS GVEA AEG&T CEA ML&P MON TOTAL MONTH MWH MWH MWH MWH (IN GVEA) Jul-99 0 3,941 0 0 Aug-99 0 12,342 0 0 Sep-99 0 15,579 0 0 Oct-99 0 8,000 0 0 Nov-99 0 2,500 0 0 Dec-99 0 §,000 0 0 Jan-00 0 5,000 0 0 Feb-00 0 2,500 0 0 Mar-00 0 2,000 0 0 Apr-00 0 8,000 0 0 May-00 0 7,000 0 0 Jun-00 0 21,525 0 0 FY 00 TOTAL 0 93,387 1,344 0 0 94,731 TOTAL INTERTIE PROJECTED ENERGY USAGE FOR FY 00 94,731 |MWH || Section 8.2.2 MINIMUM USEAGE CONTRACT VALUE 183,960 |MWH Alaska Intertie FY OO Usage Projections 51999.xIs 5/20/99 ALAS ERTIE FISCAL YEAR 1999 ENERGY PROJECTIONS FMUS GVEA AEG&T FMUS GVEA AEG&T ML&P CEA CASH FLOW ENERGY CAPACITY TOTALS $0 $18,381 $205 $0 $84,700 $27,240 $22,920 $34,541 $187,986 $0 $63,500 $386 $63,885 $0 $80,154 $643 $80,797 $0 $41,160 $643 $41,803 $0 $12,863 $1,029 $13,892 $0 $25,725 $1,029 $26,754 $0 $25,725 $1,029 $26,754 $0 $12,863 $515 $13,377 $0 $10,290 $386 $10,676 $0 $41,160 $386 $41,546 $0 $36,015 $386 $36,401 $0 $110,746 $257 $111,003 $0 $478,580 $6,894 $0 $84,700 $27,240 $22,920 $34,541 $654,874 TOTAL MWH REVENUE $654,874 | O&M BUDGET FY 00 $1,027,560|- DIFFERENCE ($372,686)|- Alaska Intertie FY OO Usage Projections 51999.xIs 2 5/20/99 O MINIMUM INTERTIE TR (MITCR)DETERMINATION FOR FISCAL YEAR 1999 R CAPABILITY RIGHTS Annual System Demand SOUTHERN UTILITY PARTICIPANTS (MW) 96-97 97-98 98-99 3 YR AVE. PROPOSED AML&P 150.0 145.0 151.0 148.7;MW CEA 220.7 220.4 231.1 224.1 [MW UNITS FY 00 AEG&T 176.7 |MW HEA 79.4 75.8 81.3 USEAGE KWH 183,960,000 MEA 97.6 93.1 103 BUDGET $$1,027,560 MITCR KW 140000 TOTAL 549.5|MW ENERGY $.000/KWH 4.664E-03 NORTHERN UTILITY PARTICIPANTS (MW)ENERGY 0.466 cents FMUS CAPACITY S/KW $1.21 GVEA 134.1 168.8 175.5 159.5|MW TOTAL 159.5|MW MITCR DETERMINATION FY 00 AEG&T 32.16%22.514|MW AML&P 27.06%18.940|MW CEA 40.78%28.546 |MW FMUS 0.00%0.000|MW GVEA 100.00%70.000 |MW 140.00|MW AFMITR2000.xls 5/20/99 MINIMUM INTERTIE R CAPABILITY RIGHTS (MITCR)DETERMINATION FOR FISCAL YEAR 1999 APPROVED APPROVED APPROVED 5/28/98 5/28/97 9/26/96 FY 99 FY 98 FY 97 REV.FY 97 FY 96 FY 95 FY 94 183,960,000 224,200,000 287,000,000 300,000,000 342,000,000 356,640,000 311,800,000 $1,133,805 $1,365,410 .$1,142,662 $980,662 $1,272,704 $1,068,893 $1,402,776 140,000 440,000 140,000 140,000 140,000 140,000 140,000 5.146E-03 5.085E-03 3.324E-03 2.730E-03 3.11E-03 2.50E-03 3.76E-03 0.515 cents 0.509 cents 0.332 cents 0.273 cents .311 cents .25 cents .376 cents $1.34 $1.61 $1.35 $1.16 $1.50 $1.26 $1.65 AFMITR2000.xls §/20/99 MINIMUM INTERTIE "(R CAPABILITY RIGHTS (MITCR)DETERMINATION FOR FISCAL YEAR 1999 APPROVED APPROVED APPROVED 5/28/98 5/28/97 9/26/96 FY 99 FY 98 FY 97 REV.FY 97 FY 96 FY 95 FY 94 183,960,000 224,200,000 287,000,000 300,000,000 342,000,000 356,640,000 311,800,000 $1,133,805 $1,365,410 $1,142,662 $980,662 $1,272,704 $1,068,893 $1,402,776 140,000 440,000 140,000 140,000 140,000 140,000 140,000 5.146E-03 5.085E-03 3.324E-03 2.730E-03 3.11E-03 2.50E-03 3.76E-03 0.515 cents 0.509 cents 0.332 cents 0.273 cents .311 cents .25 cents .376 cents $1.34 $1.61 $1.35 $1.16 $1.50 $1.26 $1.65 AFMITR2000.xis 5/20/99 - DRAFT PROP Scope Railbelt wide drill on operating electric system with limited informatiof&-and_) communications during Y2K rollover Participating Entities ye A Cooley,6 fe VA WD cD Chugach Electric Association,Inc.Steve G Tem Borclen,Golden Valley Electric Association,Inc.-[=>eadAnchorageMunicipalLight&Powere- F>e b Db Homer Electric Association,Inc. C>e0twuze Bousesa)Matanuska Electric Association,Inc.=tel eeeAlaskaEnergyAuthority-Act Cc eppo Lee_=Sa fpalParticipating Personnel Dispatchers Substation and Field Personnel Power Plant Operators Computer and Communications Technicians Drill Assumptions Partial loss of primary voice communications systems Partial loss of data communications systems Partial loss of EMS,SCADA,and control system functionality Possible bad or missing data in EMS,SCADA and control systems Drill Objectives Given the assumptions stated above: e Personnel are dispatched to key locations sufficient to allow system monitoring and operation. e On request,personnel identify,obtain and communicate key operating information sufficient to monitor and operate the system. e Personnel communicate using alternate (backup)communications systems. Critical Communications Interfaces Control area operators to plant operators Control area operators to other control area operators Control area operators to distribution utility operators Control area/utility operators to substation and field crews Duration As necessary to meet drill objectives Preparations Identify critical communications interfaces,operating facilities,and information requirements for operation with limited data communications and EMS/SCADA functionality and possible bad or missing data Prepare procedures/plans for operation with limited information and communications Identify and test backup communications systems Train personnel Coordinate resources to assure normal operations are not interrupted Reporting Report from operating entities to IOC at May meeting Address nature of drill,objectives,success measures,and key lessons learned Wert ft -a go 79 SBnien Hickey 7/9/99