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Feasibility Report City Creek Run of River Hydro Petersburg July 1979
PET 001 c. 2 PROPERTY OF: Alaska Po,aer Authority 334 W. 5th Ave. Anciforag�-, F,LSka 99501 FEASIBILITY REPORT CITY CREEK RUN OF THE RIVER HYDROPOWER PROJECT PETERSBURG, ALASKA Prepared for The State of Alaska ALASKA POWER AUTHORITY July, 1979 NORTHERN TECHNICAL SERVICES ANCHORAGE,ALASKA Li U NORTHERN TECHNICAL SERVICES 716 WEST FOURTH AVENUE, SUITE 500 • ANCHORAGE, ALASKA 99501 (907)276-4302 July 5, 1979 Mr. Eric P. Yould, Executive Director Alaska Power Authority 333 West 4th Avenue, Suite 31 Anchorage, AK 99501 Dear Mr. Yould: Enclosed for your review are four copies each of a "Feasibility Report, City Creek - Run of the River Hydropower project, Petersburg, Alaska." Northern Technical 'Services is pleased to have participated in this project.. If you should have any questions, or desire additional information on the report, please contact Mr. Giles McDonald of this office. Very truly yours, NORTHERN TECINICAL SERVICES C. A. Champion President Attachments as above NAP/CAC/gk FEASIBILITY REPORT CITY CREEK RUN OF THE RIVER HYDROPOWER PROJECT PETERSBURG, ALASKA Prepared for The State of Alaska Alaska Power Authority by Northern Technical Services 900 W. Fifth Avenue Anchorage, Alaska July, 1979 TABLES OF CONTENTS Subject Page GENERAL LOCATION MAP SUMMARY. . . . . . . . . . . . . . . . . . . . . . . . 1 Location. . . . . . . . . . . . . . . . . . . . . . . 1 Authority. . . . . . . . . . . . . . . . . . . . . . 3 Scope. . . . . . . . . . . . . . . . . . . . . . . . 1 Recommended Plan . . . . . . . . . . . . . . . . . . . 2 Environmental . . . . . . . . . . . . . . . . . . . . 3 Conclusion. . . . . . . . . . . . . . . . . . . . . . 4 SECTION I GENERAL DESCRIPTION . . . . . . . . . . . . . . 5 1. The Project . . . . . . . . . . . . . . . . . . . 5 2. History of Investigations . . . . . . . . . . . . 5 3. The Power Market Area . . . . . . . . . . . . . . 7 4. Geography . . . . . . . . . . . . . . . . . . . . Q 5. History, Population, Industry . . . . . . . . . . 10 SECTION II ENVIRONMENTAL SETTING AND RESOURCES . . . . . . 12 1. Terrain . . . . . . . . . . . . . . . . . . . . . 12 2. Climate . . . . . . . . . . . . . . . . . . . . . 12 3. Oceanography . . . . . . . . . . . . . . . . . . . 12 4. Minerals . . . . . . . . . . . . . . . . . . . . . 13 5. Forestry . . . . . . . . . . . . . . . . . . . . . 13 6. Fishery . . . . . . . . . . . . . . . . . . . . . 13 7. Wildlife . . . . . . . . . . . . . . . . . . . . . 14 8. Conclusions . . . . . . . . . . . . . . . . . . . 15 SECTION III POWER SUPPLY AND DEMAND . . . . . . . . . . . 17 1. Existing Facilities . . . . . . . . . . . . . . . 17 2. Estimated Future Requirements . . . . . . . . . . 17 SECTION IV. HYDROLOGY . . . . . . . . . . . . . . . . . . 21 1. Stream Flow Records . . . . . . . . . . . . . . . 21 2. Climate Records . . . . . . . . . . . . . . . . . 21 3. Tidal Records and Elevation Datum . . . . . . . . 24 4. Stream Flow Correlations . . . . . . . . . . . . . 24 5. Synthetic Flows . . . . . . . . . . . . . . . . . 25 6. Spillway Design Flood . . . . . . . . . . . . . . 28 7. Reservoir Data . . . . . . . . . . . . . . . . . . 30 a. Municipal Water Supply Reservoir Alternative . . . . . . . . . . . . . . . 30 b. Power Reservoir Alternative . . . . . . . . . 31 i TABLE OF CONTENTS Subject 8. Sediment . . . . . . . . . . . . . . . . . . 9. Reservoir Losses . . . . . . . . . . . . . . . 10. Diversions for Other Uses . . . . . . . . . . . 11. Power Studies . . . . . . . . . . . . . . . . . a. Existing Municipal Water Supply Reservoir. . . . . . . . . . . . . . . b. Power Reservoir Alternative . . . . . . . . 12. Operation Studies . . . . . . . . . . . . . . . 13. Diversion During Construction . . . . . . . . . SECTION V PROPOSED DEVELOPMENT PLANS AND COSTS . . . . . Page 31 32 32 34 35 39 41 43 44 1. Geology . . . . . . . . . . . . . . . . . . . . 44 2. Construction Materials . . . . . . . . . . . . . 44 3. Accessability . . . . , t . . . . . . . . . . , 45 4. Project Works . . . . . . . . . . . . . . 45 5. Municipal Water Supply Reservoir Alternative 45 a. Storage for Power Purposes . . . . . . . . . 45 b . Outlet Works . . . . . . . . . . . . . . . . 45 C. Penstock . . . . . . . . . . . . . . . . . . 47 d. Power House . . . . . . . . . . . . . . . . 47 e. Tailrace and Tail Water Setting . . . . . . 47 f . Control System . . . . . . . . . . . . . . . 49 g. Transmission Facilities . . . . . . . . . . 49 h. Access Roads . . . . . . . . . . . . . . . . 51 i. Rights -of -Way and Relocations . . . . . . . 51 J. Cost Estimate . . . . . . . . . . . . . . . 51 6. Alternative Works Considered for Municipal Water Supply Reservoir . . . . . . . . . . . . . 54 a. Turbine Types . . . . . . . . . . . . . . . 54 b . Generator Types . . . . . . . . . . . . . . 54 C. Generator Installed Capacities . . . . . . . 55 d . Penstock Types . . . . . . . . . . . . . . . 55 e. Penstock Size . . . . . . . . . . . . . . . 55 7. Power Reservoir Alternatives . . . . . . . . . . 56 8. Operation and Maintenance Costs . . . . . . . . 62 9. Replacement Costs . . . . . . . . . . . . . . . 63 10. Salvage Value . . . . . . . . . . . . . . . . . 63 SECTION VI PLAN FORMULATION . . . . . . . . . . . . . . 64 1. Alternative Power Sources . . . . . . . . . . . 64 ii TABLE OF CONTENTS Subject Page 2. Economic Criteria . . . . . . . . . . . . . . 65 a. Benefits . . . . . . . . . . . . . . . . . 65 b. Costs . . . . . . . . . . . . . . . . . . 66 C. Base Year . . . . . . . . . . . . . . . . 66 3. Penstock Sizing . . . . . . . . . . . . . . . 66 4. Installed Capacity . . . . . . . . . . . . . . 67 5. Choice of Diversion Sites . . . . . . . . . . 68 6. Recommendation . . . . . . . . . . . . . . . . 68 SECTION VII ECONOMIC ANALYSIS . . . . . . . . . . . . 72 1. Project Costs . . . . . . . . . . . . . . . . 72 2. Benefits . . . . . . . . . . . . . . . . . . . 72 3. Benefit to Cost Ratio . . . . . . . . . . . . 73 SECTION VIII REQUIRED FUTURE ACTIONS . . . . . . . . . 74 SECTION IX GOVERNMENT REQUIREMENTS . . . . . . . . . . 75 ATTACHEMENT 1 REFERENCES APPENDIX iii LIST OF TABLES 1.1 Energy Sales to Largest System Customers . . . . . . 9 3.1 Southeastern Undeveloped Hydroelectric Sites . . . . 19 4.1 Water Supply Records . . . . . . . . . . . . . . . . 22 4.2 Climatic Record, Petersburg, Alaska . . . . . . . . 23 4.3 Tidal Datum . . . . . . . . . . . . . . . . . . . . 24 4.4 Adopted Monthly Flow Statistics . . . . . . . . . . 26 4.5 City Creek Drainage Area Relationships . . . . . . . 27 4.6 [Not Used] 4.7 Municipal Water Supply Reservoir Alternative - Elevation, Area, Storage Relationships . . . . . . 30 4.8 Power Reservoir Alternative -- Elevation, Area, Storage, Relationships . . . . . . . . . . . . . . 31 4.9 City Creek Near Petersburg, Alaska Measured Monthly Average Discharge . . . . . . . . . 33 4.10 Municipal Water Reservoir Proposed Storage Alloction. . . . . . . . . . . . . . . . . . . . . 36 4.11 Municipal Water Supply Reservoir Hydraulic Losses, Head and Effective Tailwater Setting for Power Discharges . . ... . . . . . . . . . . . . . . . . . 37 4.12 High/Low Power Reservoir Alternatives, Proposed Storage Allocation . . . . . . . . . . . . . . . . . 39 4.13 Power Reservoir Alternative Hydraulic Losses and Effective Tailwater Setting for Power Discharges . . . . . . . . . . . . . . . . . . . . . 40 4.14 Energy Production Summary . . . . . . . . . . . . . 42 5.1 Feasibility Cost Estimate Municipal Water Supply Reservoir Alternative . . . . . . . . . . . . 52 5.2 Feasibility Cost Estimate, a Power Reservoir Alternative . . . . . . . . . . . . . . . . . . . . 59 5.3 Annual Operating and Maintenance Costs . . . . . . . 62 6.1 Power System Characteristics . . . . . . . . . . . . 64 9.1 Key Permit Requirements . . . . . . . . . . . . . . 75 9.2 Governmental Authority . . . . . . . . . . . . . . . 78 iv LIST OF FIGURES AND PLATES FIGURES Figure 1-1 General Vicinity Map . . . . . . . . . . . . . 6 Figure 5--1 Site and Facilities Map . . . . . . . . . Back Cover PLATES Plate 4--1 Flood Frequency . . . . . . . . . . . . . . . 29 Plate 4-2 Efficiency Curve . . . . . . . . . . . . . . . 38 Plate 5-1 Petersburg Hydropower, Municipal Water Supply Reservoir Intake Works . . . . . . . . 48 Plate 5-2 Petersburg Hydropower, Powerplant . . . . . . 50 Plate 5-3 Water Supply Reservoir, Economic Penstock Diameters . . . . . . . . . . . . . . . . . . 57 Plate 5-4 Power Reservoir, Economic Penstock Diameter . . . . . . . . . . . . . 58 Plate 6-1 Economic Analysis Diversion from Municipal Reservoir . . . . . . . . . . . . . 69 Plate 6-2 Economic Analysis Diversion from Power Reservoir . . . . . . . . . . . . . . . 70 Plate 6-3 Mill Rates vs. Capacity . . . . . . . . . . . 71 LIM L h �+•a. / :re " ♦: $•c ' 'sc so o , 3 _ ,rer ��� . € _ • G ^ .� •a .. 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C' r- A!IISS,_: 4� Cy t Melviite `osar ►o\ N F h} T R = Prince Rupee, , • ;� C- angara,1 S;" Rose ?t tit R x� r, , 34r.a�L . o,, h4cl^tym i SUMMARY FEASIBILITY REPORT CITY CREEK RUN OF THE RIVER HYDROPOWER PROJECT PETERSBURG, ALASKA T,nr_a f inn On Mitkof Island, Alaska about 2 miles east of the city of Petersburg, Alaska. Authority: Contract effective April 11, 1979, between the State of Alaska, Alaska Power Authority, and Northern Technical Services. Scope: This report examines the economic feasibility of developing the City Creek Hydropower Project to serve the Community of Petersburg, Alaska. The City Creek Hydropower Project is located within the Municipal Watershed for potable water supply to Petersburg. The study effort includes the decision process in determining the expected power plant capacity, configuration, operation constraints and construction costs for the preferred scheme resulting from examination of several alternatives. It examines the impact of the hydropower development on other water resource needs of the area. Hydrologic and hydraulic inputs to the study effort are presented and justified. The role, scope and permitting/approval requirements of appropriate federal, state and local agencies are outlined in relation to this project. -1- Environmental constraints are examined in sufficient detail to assess any major environmental impact, or constraints for the recommended work. Recommended Plan: Modify the outlets of the existing municipal water storage reser- voir to provide power storage and connection for a penstock. A 8,500 foot penstock will convey water to a 700 kw powerhouse located at tidewater. About one-half mile of new transmission line will interconnect the system with the existing city grid. Project Features: Municipal Water Supply Reservoir Alternative Elevation at full pool (ft) 333.0 Elevation at bottom of power pool (ft) 329.72 Power Storage (a-ft) 9 Domestic Water Storage (a-ft) 32 Gross Head (ft) '323 Average Net Head (ft) 314.8 Hydrology Drainage Area (sq. miles) 2.36 Average Annual Runoff (cfs) 17 Penstock Length (ft) 8,500 Inside Diameter (inches) 28 Powerplant Number of Units 1 Type of Units - Radial impulse --type turbine with asynchronous generation -2- Installed Capacity (kw) Overload Factor (%) Voltage ( v ) Length (miles) Transmission System Construction Cost (Sept 1980) 700 1.15 2,400 0.5 Production Plant (1,058,000) Dam $174,000 Waterways 473,000 Powerplant 411,000 Roads and Bridges 14,000 Transmission System 53,000 Total Construction Cost $1,125,000 Benefit to Cost Ratio (35 year period-7 1/2% interest) Annual Project Benefits Annual Project Costs Ratio Average Annual Energy (MWH) Average Energy Rate (mills/kwh) Recommended Alternative Diesel Alternative (average annual equivalent with fuel costs escalated 7% annually) Environmental: $ 350,740 $ 111,670 3.14 2,830 38.7 124.6 The recommended system should not induce any long range environmen- tal effects. Because it is a run of the river system, existing -3- water quality should not be altered, i.e. the system should not noticeably alter the water temperature or affect turbidity. Change in air quality will not be 'a factor. Fish and wildlife resources are currently minimal in the City Creek project area. Terrain and vegetative disturbance during construction can be minimized; the prevailing marine environment will assure rapid natural revegetation and recovery of disturbed areas. Conclusion: This feasibility study concludes that: 1. The City Creek Hydropower project proposed in this report is economically and environmentally feasible. 2. The development plan recommended has the least capital cost and greatest benefit/cost ratio of the alternatives examined. 3. The size and cost of the recommended project are such that project financing appears possible through one or more sources, such as sale of municipal bonds, loans from the State of Alaska, or a Program Opportunity Grant through the U.S. Department of Energy. -4- I. GENERAL DESCRIPTION 1. The Protect The City Creek Hydropower Project takes its name from a creek on the northerly end of Mitkof Island in the Alexander Archipelago of southeastern Alaska. A reservoir on the upper reaches of the creek is the principal potable water source for the municipality of Petersburg which is located just west of the proposed project site. Two alternative sites were investigated. The recommended scheme, the Municipal Water Supply Reservoir Alternative, consists of modifying the existing outlet works at the city water reservoir, providing a penstock and a powerplant at tidewater. The alternative scheme, the Power Reservoir Alternative, consists of providing a rock fill dam at a site one quarter mile downstream of the Municipal water supply reservoir together with a penstock and a powerhouse at tidewater is not recommended. Both schemes utilize "run of the river" streamflows in excess of domestic water needs to produce energy. Neither scheme yields firm power. 2. History of Investigations The Southeast region is rich in hydroelectric resources commen- surate in scale with local electricity needs. Virtually every community in this region has a technically feasible hydroelect- ric site in its immediate vicinity. Land use and environmental impacts are minimal for most of these sites, including the one under study, because, in general, they are small area, high ele- vation, natural reservoirs with high to extreme annual rainfall and runoff and generally too steep for anadromous fish. Sites -5- -1 McDonald O Islands d— 41 or f is 26 IL 0 rebut ;N Jr, 1\4\lr D RO p 0. w IS — I POW to 34 N -73 A 11iCt Ski (11 Frederick PoiM W r X IF- T P, IAL P'Tr Red "K 11L -S Kv )A _11JRC I- I A C-g'r=N-[-RhL V11CINITY M&P WA I r]of KW Y I TY E_ _ l •ti L- 1'l� C *IC ' ��. r4 t It's r Ii; �`, t� �'.�•t,.,�� + :. •ti,' , \`, HYDRO POWC -R PROJE-.CT V/ P _B Te R43 E) U RCS 14 _JALAS I� Il'i%,,` lit v-: ` "i! %' �! I X, `'W of this character are both technically and environmentally very desirable. In past years, studies have been conducted on several potential hydroelectric sites in the Petersburg -Wrangell area, which are technically feasible. Retherford and Millerl-/ well cover past and current studies concerning hydroelectric development in the Petersburg -Wrangell area. This past work emphasizes that, except for Juneau, which already has substantial excess generating capacity in the Snettisham hydroelectric project, each of Southeast Alaska's communities, including Petersburg, has a limited demand, thus, their best technological options in the near future appear to be small- scale projects or larger scale projects with interconnection-Y. Because of the distance between Southeast Alaska's individual load centers, their small size, and difficult mountainous, glacial and marine topography, the cost'of energy from larger scale projects with interconnection exceeds the energy cost associated with the plan recommended in this report. Secondary energy from the proposed Tyee Project is presently estimated at 39 mills per kwh.3/ 3. The Power Market Area Retherford & Miller 1/ cover the principal market for system energy sold by Petersburg Municipal Power & Light. Therefore, this information will not be repeated for purposes of this study, other than to include for ready reference a copy of a 1/R. W. Retherford Assoc. & K. Miller, Nov. 1976, System Review and Planning Guidelines for Petersburg Municipal Power & Light. 2/University of Alaska, Institute of Social & Economic Research, Aug. 1976, Electric Power in Alaska, 1976-1995. 3/Verbal communication, C. Steely, R. W. Retherford Assoc., July 1979. -7- table included within their report which reflects Energy Sales to Largest System Customers, 1975. Time was not available to Retherford & Miller to allow their examination of the Munici- pality of Petersburg energy consumption. They contemplate, how- ever, that the city itself probably ranks within the top customers listed in Table 1.1.4/ 4. Geography The Municipality of Petersburg, its harbor and the project site are geographically situated in latitude 561481north, longitude 1320571 west, at the northwest tip of Mitkof Island in the Alexander Archipelago in Southeastern Alaska. The municipality is located about 780 miles northwesterly of Seattle, Washington, and 120 miles south of Juneau, Alaska, near the confluence of Wrangell Narrows and Frederick Sound. Petersburg is located in the coastal foothills physiographic province which consists of blocks of mountains separated by flat -floored valleys, straits and fiords. Mountains.less than 3500 ft elevation generally have been overridden by glaciers; therefore, they have rounded hummocky summits in contrast to the jagged higher mountains of the coastal range laying immediately to the east. The coastal foothills are characterized by a belt of early Cretaceous to late Jurassic slate, graywacke, conglomerate and limestone. Surficial deposits above bedrock on the land surface 4/See footnote 1. Table 1.1* ENERGY SALES TO.LARGEST SYSTEM CUSTOMERS Energy Annual Revenue Rank Customer Sales Amount Rate/Unit Kwh $ $/Kwh I. Petersburg Fisheries, Inc.1/ 2436577 $122,156 .0501 2. Whitney Fidalgo Seafoods, Inc.1/ 867494 42,107 .0485 3. Mitkof Lumber Co., Inc.1/ 650033 35,704 .0549 4. Alaska Department of Fish and Game (Blind Slough Fish Hatchery) 521960 28,164 .0546 5. The Trading Union, Inc. 515769 24,742 .0480 6. Hammer and Wikan, Inc. 387261 19,385 .0501 7. Petersburg Public Schools 377288 19,658 .0521 .8. Alaskan Glacier Sea Food Co. 33780 15,361 .0490 Total/Average 6070162 307,277 .0506 o Total Sales 37.9 1/ Connected Loads: Petersburg Fisheries, Inc. Whitney Fidalgo Seafoods, Inc. Mitkof Lumber Co., Inc. * Copy of Table 1.6, R.W. Retherford Assoc. & K. Miller, Nov. 1976, System Review and Planning Guidelines for Petersburg Municipal Power & Light. �.m are generally unconsolidated materials including clay, silt, sand and gravel. Much of the unconsolidated material is of glacial origin deposited during the Quaternary. According to a preliminary seismic risk map of Alaska prepared by the U.S. Army Corps of Engineers, all of southeast Alaska falls in seismic risk zones 3 and 4 [>6.0 Richter magnitude]. 5. History, Population, Industry Petersburg, with a population of approximately 3,197 in 1974V , is famous as a fishing center and as Alaska's "Little Norway." Petersburg was founded in 1898 when a cannery was built near the north end of Wrangell Narrows. Industrious Scandanavian fishermen settled around the cannery and on March 1, 1910, the town incorporated. The community was mainly built with local capital and work effort. Although fishing is the major industry, Petersburg also serves as the trading and supply center for settlements and activities on Wrangell Narrows, Frederick Sound, Sumner Strait and portions of Chatham and Clarence Straits. Lumbering and logging have become increasingly important in recent years and should continue to be so, if not adversely impacted by recent and pending actions affecting the public lands within Alaska. Port facilities at Petersburg include five wharves, one seaplane approach dock and float, a float system within the boat basin, a marine way and dry dock facility, a ferry dock, and several private, state and federal small boat floats. 5/State of Alaska, Department of Regional and Community Affairs, Annual Revenue Sharing Report, March 1979. -10- Three privately owned wharves are used for fish handling, processing and temporary storage. The two remaining wharves are utilized for handling and bunkering of petroleum products. The town supports the normal services, facilities and other service organizations found in cities of comparable size. Revenue producing facilities include the water and garbage collection system, the light and power system and the hospital. Additional revenue is obtained by a sales tax and taxes on real and personal property. Access to the community is by boat or plane. Alaska Airlines currently services the community by scheduled daily flights. Petersburg, on the Alaska Marine Highway System, also is served by scheduled ferry service between Seattle, Washington and other ports within Southeast Alaska. Freight coming into Petersburg arrives by barge from Seattle (or Anchorage), by vanline (via the ferry system) or by air. -11- II. ENVIRONMENTAL SETTING AND RESOURCES 1. Terrain Petersburg lies on relatively flat to gently sloping land at the northwest end of Mitkof Island. The mountains to the southeast of the city, which define the watershed for City Creek, rise about 2600 ft elevation. Soils in the area are generally dense, well graded silty gravels typical of glacial outwash. In areas, soils are thin over meta- morphic bedrock. Outcrops of bedrock occur along the tidal zone between Sandy Beach Recreation area and the mouth of City Creek. Bedrock bluffs also are evident along the right bank of City Creek between the municipal reservoir and the creek mouth. The powerhouse and much of the penstock route will be founded on bedrock. 2. Climate Petersburg has a typical maritime climate with mild winters, cool summers and an annual precipitation of approximately 106 inches which includes 103 inches of snow. Summer temperatures range from 451 F to 640 F; winter ranges between 221 F to 371 F. Extremes range from --90 F to 840 F. (See also, Table 4.2). Precipitation distribution at Petersburg is similar to that at other southeastern stations; almost 40 percent of the annual total falls during the three months from September to November. The first measurable snow usually falls in November and general- ly extends through March. 3. Oceanography The extreme range of tide in the harbor is about 20.5 ft; the mean high water range is 14.8 ft. Tidal currents mid -channel in -12- the Wrangell Narrows are reported as high as 8 knots, but are much less within the harbor area. See also Table 4-3. 4. Minerals Southeastern Alaska has a moderately high lode -metal potential. Gold, copper, silver, lead and zinc occur moderately within the Petersburg mining district; mainly near beaches. Limestone and barite deposits are in evidence on Kupreanof Island near Duncan Canal, across the Wrangell Narrows to the northwest of Petersburg. There is little evidence of any significant past mining activity in the proximity of the project. 5. Forestry Except for the Petersburg exclusion area and other State select- ed lands in the proximity of Petersburg, the entire land area is within the Tongass National Forest. The forest boundary is shown on Figure 1.1. The well drained strongly acid, dark, soil occurring 'on moraine hills supports a forest vegetation of Sitka spruce and western hemlock of good commercial value in the vicinity of Petersburg. The right bank of City Creek throughout its length is heavily covered with spruce and hemlock. The project site and facilities, as recommended, lay westward of the left bank of the creek in a more thinly timbered and open area. At lower elevations this open area is generally muskeg in character. 6. Fishery/ The economy of Petersburg revolves around the fishing industry. Salmon and halibut are most significant; shrimp production also is important. Bottom fishing for cod, flounder, and other 6/Alaska Dept. of Fish & Game, 1978, Alaska's Fisheries Atlas -- Vol. I. -13- species, as currently developing within Alaskan waters, also may become an important productive resource in the area. All five species of North American Pacific salmon are present in Southeast Alaska but are not equally distributed. Of the five species, coho and pink salmon spawn in streams occurring on Mitkof Island, namely Falls Creek, Big Creek, Blind River and Blind Slough and their tributaries. Red king crab, tanner and dungeness crab are fished in Wrangell Narrows and off the eastern and southern shores of Mitkof Island. Traditionally, three geographic locations Duncan Canal, Stikine Flats and Thomas Bay -- in Southeast Alaska produce the major portion of the shrimp harvest. Shrimp are taken off the eastern and southern shorelines of the Island. Verbal communication with residents and U.S. Forest Service officials in Petersburg indicates that City Creek supports little or no anadromous or sport fish. 7. Wildlife7/ Game Management Unit 3, located centrally in Southeast Alaska, includes several major islands, the largest being Kupreanof, and two principal cities, Petersburg and Wrangell. Black bear are found within the Unit and are primarily hunted for trophies. On Mitkof Island these bears are most commonly concentrated along Blind River and Blind Slough which lie south of Petersburg. 7/Alaska Dept. of Fish & Game, Jan., 1973, Alaska's Wildlife & Habitat. -14- Sitka blacktail deer in residence on Mitkof are generally concentrated in an area bordering Frederick Sound and in a narrow zone on the southwesterly shore of the island. Wolves are present within Unit 3. Wolverine are rare. Harbor seals commonly occur within the Unit, but no concentra- tions are present on Mitkof Island. Steller sea lion have been observed in Unit 3; elephant seal are sighted occasionally as are humpback and finback whales. Dense populations of waterfowl and seabirds occur within the Unit. On Mitkof, key habitat areas for waterfowl are along Wrangell Narrows and Blind Slough. 8. Conclusions Limited on -site investigation and verbal communication with Petersburg residents together with a literature review form the basis for the summary coverage of environmental and resource information incorporated in the study. An assessment of this information indicates that the proposed project, if constructed, should not induce any long range impact upon existing resources or environmental amenities in the proximity of the project facilities. Available information indicates that fish and wildlife resources currently are minimal or non-existent in the City Creek drain- age. The existing air and water quality are excellent. Because the project as envisioned is a "run of the river" system, water quality will not be altered; however, diversion will reduce flow. Air quality will not be affected. Construction will -15- cause some local terrain and vegetative disturbance over and above that which has already occurred. The disturbance can be minimized. The prevailing marine environment will assure rapid natural revegetation and recovery of disturbed areas. The project will not generate any industrial wastes, thus, disposal of solid or liquid wastes is not a factor. The power plant's tailwater discharges into the sound at a point about one half mile west of the normal stream mouth. This discharge could induce some changes to the marine environment in the immediate area of the discharge point. -16- III. POWER SUPPLY AND DEMAND 1. Existing Facilities Petersburg presently uses a mix of hydroelectric and diesel electric power. Hydroelectric capacity is reported at 2000 kw (Blind Slough -- one former 400 kw unit at this location has been retired). Diesel capacity is currently reported at 5480 kw.8/ The present and projected power demands are also discussed in Section VI-1 Plan Formulation, Existing Power Sources. Past study work by Retherford and Miller in 1976g/ and Retherford Assoc., 197810/, well describes existing and projected system needs. In the interest of not repeating this already well documented information, further coverage will be dispensed with in this report. (See also Section I.) 2. Estimated Future Requirements Southeast Alaska is not a single regional power market as are other areas within the state such as Anchorage and Fairbanks. This region comprises a number of isolated load centers with populations ranging from a couple hundred to that of Juneau (22,105 in 1979).1/ Population and electrical demand in the region is expected to increase, but at a more moderate rate than in areas such as Anchorage and the Susitna and Tanana Valleys. 8/R.W. Retherford Assoc., Sept. 1978, Revised Preliminary Appraisal Report, Tyee Lake, prepared for Thomas Bay Power Commission, Petersburg -Wrangell, Alaska. 9/R. W. Retherford Assoc. & C. Miller, Nov. 1976, op.cit. 10/R. W. Retherford Assoc., Sept 1978, op.cit. 1.1/State of Alaska 1979, op.cit. -17- However, future requirements may trigger an accelerated growth in energy needs. As mentioned in Section II, bottom fishery development is occurring and the industry most likely will expand significantly in Southeastern Alaska. The miner- al industry also has future growth potential. To meet these needs, several sites close to Southeast Alaska communities have been identified through past studies where small scale hydropower projects appear technically and economically viable, particularly in light of the rapidly escalating costs and usage of petroleum products. A list of the more promising of these are included in Table 3.111/. Of particular present interest on the part of Petersburg and Wrangell is the large Tyee Lake hydroelectric development project12/, in order to meet their combined projected energy and peak demand requirements through year 1998, with a minimum of increasingly costly diesel generation. Notwithstanding, this interest does not detract from the need for the City Creek hydroelectric energy which can be made available well before the Tyee Project comes on line and at lower unit cost. 12/Taken from Electric Power in Alaska, 1976-1995, by Institute of Social & Economic Research, University of Alaska, August, 1976. 13/Tyee Lake, op. cit. Table 3.1* SOUTHEASTERN UNDEVELOPED HYDROELECTRIC SITES Prime Capacity (KW) Energy Total Area/Project Installed Prime (MWH) (000$) Southeast Metlakatla Purple Lake Rehabilitation 1,400 Hassler Lake 4,000 Total 5,400 Ketchikan Upper Mahoney Lake 10,000 Swan Lake 15,000 Lake Grace 20,000 Total 45,000 Petersburg -Wrangell Anita 4,000 Anita and Kunk Lakes 8,000 Virginia Lake 61000 Sunrise Lake 4,000 Ruth Lake 16,000 Crystal Lake Expansion 2,500 Cascade Creek I 15,000 Cascade Creek II 36,000 Scenery Lake 18,000 Total 105,500 Juneau Snettisham Expansion I Snettisham Expansion 11 Total Capital Cost Per* Prime KW Installed KW 400 17,520 1,134 2,835 810 2,000 16,980 6,630 3,415 3,415 2,400 34,500 4,700 41,172 9,035 1.772 903 7,700 67,500 32,980 4,263 2,199 11,000 94,000 39,351 3,577 1,968 23,800 202,672 2,100 18,395 5,871 2,796 1,458 3,830 33,550 9,128 2,383 1,141 3,000 26,280 7,070 2,357 1,178 2,400 21,024 4,174 1,739 1,043 7,950 69,660 23,355 2,938 1 ,460 400 3,504 4,400 11,000 1 ,760 5,100 44,781 22,955 4,501 1,530 17,900 156,672 21,335 1,192 593 91100 79,716 22,310 2,452 1,239 51,780 453,583 27,000 11,758 103,000 22,000 1,871 815 - 18,607 162,997 16,000 860 - 27,000 30,365 265,997 38,000 1,251 Table 3.1 continued Area/Project Sitka Lake Irina Green Lake Lake Diana Milk Lake Four Falls Lake Carbon Lake Takatz Lake Total Haines Unnamed Lake Skagway Goat Lake 9,000 4,450 38,982 9,140 2.054 1,016 Total Region 287,900 158,240 1 ,393 ,827 *From the University of Alaska, Institute of Social and Economic Research, August 1976, Electric Power in Alaska, 1976-1995. **All costs calculated assuming construction begins early 1976. 0 Prime Capacity (KW) Energy Total Installed Prime (MWH) (000$) 3,000 1,790 15,680 3,665 14,000 6,600 '57,816 18,050 10,000 4,565 40,165 9,705 16,000 8,000 70,080 18,750 61000 3,000 26,280 4,265 18,000 6,830 59,832 19,200 20,000 10 ,op0 87,600 26,600 87,000 40,805 357,453 9,000 4,640 40,640 10,435 Capital Cost Per** Prime KW Installed KW 2,047 1,222 2,735 1,289 2,117 970 2,321 1,172 1 ,417 711 2,811 1,067 2,660 1,330 2,249 1,159 1V. HYDROLOGY Water supplies available for power consumption were determined by correlating the limited available monthly flow data for City Creek with the long term records available for the Harding River near Wrangell and Cascade Creek near Petersburg. 1. Stream Flow Records Reasonably good stream flow records are available as a basis for determining the available water supply. Reliable runoff records have been gathered for City Creek for -only three years, however, good long term records that correlate well with City Creek exist at two nearby stations. Table 4.1 provides the station history as well as pertinent basin data. Data are from the U.S. Geological Surveys stream characteristics file. In addition to the above data, limited additional record has been obtained on the upper reaches of City Creek by the U.S. Forest Service. However, this data has not been reduced to a usable format from the analog form in which it was recorded. 2. Climate Records Climatic records were not used in estimating stream flows because of poor correlation. Climate records have been gathered at Petersburg since 1924. Petersburg has a typical maritime climate with mild winters, cool summers, and an annual precipitation of more than 100 inches. Minimum and maximum record air temperatures are -90 F and 841 F. A summary of climatology data is presented on Table 4.2. opaw TABLE 4. 1 WATER SUPPLY RECORDS Station Period of Record Drainage Mean Area Elevation (sq miles) (ft) Lakes Glacier Cascade Cr. near Oct 1918 - Nov 1929 23.0 3160 4 13 Petersburg Oct 1947 - Sept 1978 N N 1 Harding River Sept 1961 - Jan 1978 67.4 2400 0 9 near Wrangell City Creek near Oct 1970 -- Oct 1973 3.17 1000 1 0 Petersburg - 3LE - __ CLIMATIC RECORD PETERSBURG, ALASKA JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC Annual Monthly Mean Temp. OF 27.6 30.8 34.3 40.4 41.3 53.2 55.8 55.0 55.5 43.5 35.6 30.8 42.1 Daily Max Temp OF 32.9 36.5 40.9 48.4 56.1 61.8 63.1 62.9 57.5 49.2 40.6 35.4 48.8 Daily Min Temp OF 22.4 25.1 27.7 32.4 38.5 44.7 47.9 47.0 43.5 37.9 30.6 26.2 35.3 Record Highest/Year 60/ 64/ 59/ 72/ 78/ 83/ 84/ 79/ 81/ 72/ 63/ 59/ 84/ 1955 1938 1937 1931 1945 1958 1933 1942 1938 1938 1949 1944 1933 Monthly Average Precip. In. 9.27 7.76 7.06 7.02 5.82 4.79 5.37 7.52 11.26 17.27 12.12 11.02 106.28 N l,J 1 Daily Max Precip. In. 3.77 4.42 3.16 2.54 2.83 2.35 2.86 3.55 4.49 5.70 5.58 3.76 5.70 Monthly Max Precip. In. 16.07 17.00 11.90 10.57 12.76 8.76 11.95 16.66 20.51 29.05 26.78 21.27 29.05 Monthly Snow Mean In. 28.1 22.6 16.5 1.9 T T 0.0 0.0 0.0 0.7 10.0 23.2 103.0 Greatest Monthly Snow In. 92.6 73.6 61.9 12.4 T T 0.0 0.0 0.0 11.0 32.0 23.0 92.6 Greatest Snow Depth on the 62 78 83 20 0 0 0 0 0 11 24 52 83 Ground In. 1. Period of record - 38 years Station: 2. Aviation observations began 11/17/36 1. Started at school grounds - 10/28/24 3. Station elevation - 2B feet 2. Aviation observation began 11/17/36 4. Latitude - 56049'; longitude - 132057' 3. Wind instrument installed 8/18/37 3. Tidal Records and Elevation Datum Tidal data is necessary for the study in that tides affect the tail water and determine the lowest powerhouse setting. Table 4.3 provides tidal data from mean lower low water datum. TABLE 4.3 TIDAL DATUM Elevation Datum (Ft MSL) Estimated Highest Water Level 12.4 Mean Higher High Water 7.60 Mean High Water 6.70 Mean Water Level 0.00 Mean Low Water -6.70 Mean Lower Low Water -8.10 Estimated lowest water level -12.6 Elevation ( Ft MLLW ) 20.5 15.70 14.80 8.10 1.40 0.00 -4.5 The datum used in this report is at mean sea level. The basis of elevation is the monument on the curb in front of the National Bank of Alaska in Petersburg, USCAGS No. 10-1958, its elevation is 24.12 feet MSL. 4. Stream Flow Correlations Monthly recorded stream flows for the USGS gage on City Creek were extended by means of the "Monthly Streamflow Simulation" computer program (HEC-4) developed by the Hydrologic Engineering Center of the U.S. Army Corps of Engineers. This program ana- lyzes the monthly streamflows at a number of interrelated sta- tions to determine their statistical characteristics and, in turn, generates a sequence of hypothetical streamflows of any desired length having those characteristics. It considers the mean, standard deviation, skew, and the correlation of each months flow with the preceding months flow. Also, it considers -24- the correlation matrix between flows for each month and preceding months for each station. Appendix 1, Hydrology, contains a record of the monthly flows used for the studies and the statistics generated. Reasonableness of the generated statistics for City Creek were evaluated by considering the raw correlation coefficients and estimated statistical parameters. The means and standard deviations for each station and each month were plotted and examined. As expected, the estimate of monthly mean flow for City Creek was good but the estimates of the standard deviations of the months were poor. Accordingly, a regional standard deviation and skew of monthly flows based on those for Harding River was adopted. Average monthly correlation; coefficients for Harding River and Cascade Creek also were adopted. A tabulation of the adopted statistics are shown in Table 4.4. 5. Svnthetic Flows Once reasonable statistics for monthly flows were developed, a program option of the HEC-4 program, which generated flows from statistics, was used. Monthly flows for 3 - 50 year periods were generated. These flows and the statistics are shown in Appendix I. The generated flows are for the USGS gage site, not the two diversion sites being studied. Monthly flows for these latter locations were developed by applying a drainage area ratio to the flow for the gage site. Table 4.5 gives the drainage areas and their ratios. -25- Table 4.4 Adopted Monthly Flow Statistics, USGS Gage Station, City Creek near Petersburg OCT NOV DEC JAN FEB MAR APR MAY .'TUN JUL AUG SEP Preceding Month - .053 .075 .300 .480 .595 .606 .421 .293 .036 .138 .488 .155 Corel.ation Coefficient Log Mean Flow 1.409 1.278 0.791 0.791 � 0.759 0.905 1.346 1.724 1.439 1.349 1.555 1.388 Log Standard .172 .187 .263 .315 .295 .2.52 .204 .091 .057 .059 .113 .126 rn Deviations Log Skew .216 .452 .451 .576 .414 .433 -.107 .251 -.130 -.053 -.559 .373 Coefficient Flow Increments .279 .194 .064 .074 .060 .091 .273 .523 .452 .231 .261 .257 in cfs Table 4.5 CITY CREEK DRAINAGE AREA RELATIONSHIPS Station USGS Gage Power Reservoir . Municipal Water Reservoir Drainage Area % (Sq miles) 3.17 100 3.02 95.3 2.36 74.4 -27- 6. Spillway Design Flood For large dams upstream of population centers failure would be catastrophic and human life endangered. Normal practice requires design of a spillway to accommodate the most severe flood considered possible for the region. For minor impound- ments, where failure can be tolerated, normal practice dictates design for a 50 or 100 year flood.. For the two reservoirs considered, failure would not endanger existing property other than the dams themselves. The stream downstream of the dams is confined to a gorge and discharges to tidewater about 1/2 mile from any existing developments. The spillway capacity of the existing municipal water reservoir dam is about 1500 cfs with the water surface at the top of the dam. This flow corresponds roughly to a 1,000 year flood as estimated by extrapolating a frequency curve for the USGS gage site and adjusting it for drainage area. This is considerably less than the maximum probable flood but is judged extremely conservative for the project under consideration. The frequency of occurrence of floods on City Creek was esti- mated in accordance with USGS "Flood Characteristics of Alaskan Streams", USGS WRI 78-129. The calculated values were smoothed by plotting. The results are presented in Plate 4-1. WRI 78-129 and several other estimates show that the peak discharge for Alaskan streams varies with about the 0.8 power of the drainage area. The spillway design, flood for any dam on the stream should be consistent with those used elsewhere on the stream. Thus by ratioing the drainage areas to the 0.8 power the spillway design flood at the power dam site should be 1800 cfs. For large reservoirs usual practice dictates reduction of the peak of the in -flowing spillway design flood to account for water stored in the reservoir. However, for the two small reservoirs being considered, attenuation of the peak by storage is considered insignificant and consequently is disregarded. -28- IG••• 2000 POWER DAM Q WATER SUPPLY RES ••• 500 300 200 2 POWER DAM SPILLWAY = 0.967 USGS GAGE MUNICIPAL DAM SPILLWAY Q = G.790 USGS GAGE i USGS GAGE WATER SUPPLY RESERVOIR PLATE 4-1 FLOOD FREQUENCY 1800 C1=S 1460 CFS 7. Reservoir Data Two separate dam and reservoir locations are considered. These two sites are described in Section 1. a. Municipal Water Supply Reservoir Alternative The proposed scheme for diverting water for power flow requires superimposing power storage on top of the existing domestic water storage. No additional dam would be built; however, the existing manual gates would require replacement with motorized gates controlled by a telemetry system. As an additional safeguard, the penstock would be routed to an elevation equal to the spillway.crest and fitted with a vacuum release valve so that the penstock would be incapable of drawing the reservoir below the top of the domestic water supply pool. This feature is further discussed in Section V. Physical characteristics of elevation, storage and surface area are necessary to model the operation of a reservoir. Table 4.7, which provides this data for the existing municipal water reservoir, is based on its anticipated condition when cleaned. Table 4.7 MUNICIPAL WATER SUPPLY RESERVOIR ALTERNATIVE ELEVATION - AREA - STORAGE - RELATIONSHIPS Elevation Area Storage (ft) (Acres) (Acre ft) 311.41 (invert outlet) 1 3 320 2 10 325 2 25 329.72 (spillway crest) 3 35 332 3 42 334 3 47 335.05 (top dam) 3 51 -30- b. Power Reservoir Alternative Under this scheme, a power dam will pond water released from the upstream water reservoir. All storage above the outlet of the power dam is available for power purposes. Table 4.8 provides information on elevation, area, and storage relationships. Table 4.8 POWER RESERVOIR ALTERNATIVE ELEVATION - AREA - STORAGE - RELATIONSHIPS Elevation Area Storage (ft) (Acres) (Acre ft) 258 0 0 264 (minmum pool) 1 5 270 1 10 275 3 35 280 6 60 284 (spillway crest) 8 90 288 10 110 290 11 135 (This information was developed from limited surveys near the dam axis and from USGS maps.) Seasonal Rule Curves for reservoir operation were not developed because the project is operated strictly as a run of the river plant. 8. Sediment Sediment data is not available for City Creek. However, the water is used for domestic purposes with minimal treatment. Loss of storage by deposition of sediment is judged not to be a significant problem. -31- 9. Reservoir Losses Evaporation; Pan evaporation records are not available for Petersburg. The closest station, at Juneau Airport, is in an exposed location. However, in a maritime regime evaporation is minimal. Through correlation of the recorded evaporation at Juneau and winds expected at the reservoirs, evaporation is estimated at 2.7 inches for the month of July and 2.8 inches for the month of August. All other months should have a net gain of precipitation over evaporation. Thus, evaporation losses are considered insignificant. However, evaporation for July and August have been included in the power study. Because of low head and minimal surface area, as well as tight underlying bedrock, reservoir leakage was ignored. 10. Diversions for Other Uses The existing primary use of City Creek is domestic water supply for the City of Petersburg. Records of diversions from 1969 through 1978 have been made available by the City Water Utility. The diversions are made upstream of the USGS gaging site, there- fore, it is necessary to add the diversions into the gaged record before stream flow correlations can be made. Table 4.9 provides the recorded diversions as well as the historic and adjusted recorded stream flow. -32- Year OCT NOV DEC JAN 1970 10.1 3.55 2.91 6.05 1971 28.9 20.9 6.44 4.10 1972 39.9 27.8 5.10 6.84 1973 23.9 1969 2.6 2.0 1.8 1.B 1970 1.9 1.9 1.2 1.5 1971 2.3 2.0 2.0 2.2 1972 1.9 2.0 1.5 1.5 1973 2.5 1.9 1.9 1.7 1974 2.2 1.9 2.0 2.0 1975 1.1 0.92 1.1 1.1 1976 1.4 0.92 0.92 0.77 1977 1.4 0.77 0.93 0.93 1978 1.5 0.93 0.77 Mean 1.88 1.52 1.41 1.50 Std Dev. 0.52 0.55 0.48 0.49 Annual 8.78 7.10 6.58 7.00 $ Avg Annual 105 85 79 84 1970 12.0 5.45 4.11 7.55 1971 31.2 22.9 8.44 6.30 1972 41.8 29.8 6.6 8.34 1973 26.4 Table 4.9 CITY CREEK NEAR PETERSBURG, A.LA5KA Measured Monthly Average Discharge (cfs) FEB MAR APR MAY JUN JUL AUG SEP Year 3.11 1.74 26.0 52.8 52.7 14.0 20.1 28.1 1971 1.76 8.35 6.10 46.0 48.3 30.1 32.7 18.0 1972 6.99 11.6 44.2 51.6 27.9 16.4 16.8 23.0 1973 Diversions from above gage for city water (cfs) 1.7 1.7 1.8 2.2 2.3 2.9 3.1 2.6 1970 1.9 1.9 1.7 2.0 2.2 2.9 2.9 2.9 1971 2.3 2.0 2.0 2.2 2.2 2.9 2.6 2.3 1972 1.9 1.7 1.9 2.3 2.3 2.9 3.1 2.8 1973 2.0 2.2 2.5 2.3 2.0 2.3 2.0 2.3 1974 1.9 1.5 2.3 2.0 2.0 1.9 2.0 1.5 1975 1.3 1.2 1.2 1.1 1.0 1.1 1.5 2.0 1976 0.77 0.77 0.92 1.1 0.77 1.5 2.3 1.4 1977 1.1 0.77 0.93 0.77 0.77 0.77 1.2 2.2 1978 Annual Average 1.65 1.53 1.69 1.77 1.82 2.13 2.30 2.22 1.79 0.49 0.52 0.57 0.61 0.61 0.85 0.69 0.52 0.30 7.70 7.14 7.89 8.26 8.50 9.94 10.74 10.36 100 92 85 94 99 102 119 128 '124 100 Gaged Discharge Plus Diversions (cfs) 5.01 3.64 27.7 54.8 54.9 16.9 23.0 31.0 1971 4.06 10.35 8.10 48.2 50.5 33.0 35.3 20.3 1972 8.89 13.3 46.2 53.9 30.1 19.3 19.9 25.8 1973 1974 A projection of future water diversions was made by extending the historic annual water consumption per capita and the esti- mated population for future years as provided in the 1976 report "Petersburg Municipal Power and Light System Revenue and Plan- ning Guidelines". A monthly distribution of this annual con- sumption was estimated by applying the historic monthly percent- age of annual use. The resulting formula for monthly diversions for domestic water is. Q = 1978 population (1.035)n M% (1.05) where: Q = the estimated diversion for any month in any year in cfs The 1978 population is 2900. n = the year - 1978 M = the historic monthly percentage of the annual average diversion rate 1.05 = the 1978 annual average rate of diversion in cfs 1.035 = the forecast annual population growth rate The flows as computed above were diverted from stream flow at the existing city reservoir before energy generation was computed. 11. Power Studies The operation of the alternative reservoir and power plant was simulated by the HEC--3 computer program "Reservoir System Analy- sis for Conservation", as developed by the Hydrologic Engineer- ing Center, U.S. Army Corps of Engineers. The Program simulates the operating systems of reservoirs with various configurations of diversions, power plants and stream control points. Inputs to the program comprise monthly flows, evaporation, diversions, -34- operating rates, reservoir and outlet descriptions and power plant characteristics. Outputs are the regulated flows and economic benefits. The program is more fully described in the Users Manual for HEC-3. Two separate systems of reservoirs were considered in the study. The first scheme consists of diverting flows in excess of domes- tic water needs from ,the existing municipal water reservoir. The second consists of constructing a new dam and reservoir downstream from the existing dam. All computations were made on a water year basis. a. Existing Municipal Water Supply Reservoir: For this scheme, no other reservoir would be constructed. Flow in excess of that required for domestic water use would be diverted through a penstock to a powerhouse located at tidewater. Pondage for power generation would be obtained by replacing the existing manually controlled spillway gates with remotely controlled motorized gates. This remote control system also would provide data on reservoir level, gate positions and enable automatic regulation of the gates. An atmospherically vented pipe stand would be constructed immediately downstream of the outlet to prevent reservoir drawdown below the top of the domestic water - pool. More details of this system are described in Section V "Development Plans and Costs". Reservoir storage is allocated according to the following Table 4.10. -35- Table 4.10 MUNICIPAL WATER SUPPLY RESERVOIR Proposed Storage Allocation Elevation Storage (ft) Level (a-ft) 335.0 Top Power Pool 55 333.0 Average Power Pool 44 329.72 Top Domestic Water Storage 35 311.41 Bottom Domestic Water Storage 3 As envisioned, the reservoir would provide daily pondage for power generation but would provide no long term storage, the power plant would function solely as a run of the river plant. Penstock and gate losses were estimated based on a 28 inch penstock. Penstock selection was based on an economic diameter. (This selection is discussed more fully in Section V.) Penstock losses were computed by Mannings formula with a roughness value of 0.013. The tailwater setting of the turbines is 10 feet. Hydraulic losses and effective elevation of the turbine are shown in Table 4.11. -36- Table 4.11 MUNICIPAL WATER SUPPLY RESERVOIR Hydraulic Losses, Head and Effective Tailwater Setting for Power Discharges Discharge Head Loss Effective Effective Turbine Head (cfs) (ft) Elevation (ft) (ft) 0 0 10 323 4 1.3 11.3 321.7 7 3.8 13.8 319.2 10 7.8 17.8 315.2 20 26.3 36.3 286.7 40 124.8 134.8 188.2 Since the economics of power value require that almost all water be used for power generation, penstock sizing was independent of power studies and the same penstock was used for all installed capacities. Installed capacities of 500, 575, 650, 725, 800, 900, 1000, 1200, and-1300 kw were investigated, using turbine and generator efficiencies of 82 percent. This is a conserva- tive value for the recommended type of units. Also an overload ratio of 1.15 times the installed capacity was applied, which is the typical ratio for Tmerican practice and should be specified when equipment is ordered. Typical efficiency curves for the cross -flow type of turbines recommended are shown on Plate 4-2. -37- 90 80 70 60 Lu 50 LU 40 30 20 10 0 10 20 30 40 so 60 70 80 90 10 0 GATE OPENING OSSBERGER with divided water admission - PLATE 4-2 TYPICAL TURBINE EFFICIENCIES b. Power Reservoir Alternative: The alternately proposed power reservoir is located about 0.6 mile downstream from the existing water supply reservoir at the site of an old abandoned log and earth fill dam. Inflow would be spilled as excess of diversions from the upstream water supply darn augmented by local inflow between the two sites. The maximum height of dam and the amount of storage available, which would be dedicated solely to power production, is limited by geographic considerations. The site does not allow development of seasonal storage. Two dam heights were investigated although no specific study of dam height was made. The lowest height provides minimum conditions for intake and power storage equivalent to that at the water reservoir. The second height provides the maximum storage reasonably possible and 4 percent more head. The reservoir storages are allocated in accordance with following Table 4.12. Elevation (ft) Table 4.12 HIGH POWER RESERVOIR ALTERNATIVE Proposed Storage Allocation Level Storage (a-ft) 284 Top Power Pool 90 271.5 Bottom Power Pool 13 264.0 Minimum Pool 5 LOW POWER RESERVOIR ALTERNATIVE Elevation Level Storage (ft) (a-ft) 274.0 Top Power Pool 22 271.5 Bottom Power Pool 13 264.0 Minimum Pool 5 -39- The high reservoir provides significantly more power pondage than the low reservoir or the upstream water reservoir. How- ever, the storage is not adequate for seasonal purposes. The minimum pool is at the bottom of the outlets. Sufficient head is allowed to prevent air entrainment. Penstock and gate losses were estimated based upon a 34 inch penstock, which was selected solely on economic considerations. (The selection is discussed more fully in Section V.) Friction losses were computed by Manning's formula using a roughness value of 0.013. The tailwater setting of the turbine is 10 feet. Hydraulic losses and effective elevation of the turbine are presented in Table 4.13. Discharge (cfs) 0 4 10 25 40 100 Table 4.13 POWER RESERVOIR ALTERNATIVE Hydraulic Losses and Effective Tailwater Setting for Power Discharges* Head Loss (ft) 0 0.3 1.7 10.4 26.6 176.4 *These are applicable to both power reservoirs. Effective Turbine Elevation (ft) 10 10.3 11.7 20.4 36. 6 186.4 Losses between points were determined by linear interpolation. Installed capacities, efficiencies and plant factors used were identical to those used for the water supply reservoir case. - 4 0 - 12. Operation Studies A sequential routing of the synthetic monthly inflows through the reservoir systems and power plant was made for each reser- voir case and each of the installed capacities using the HEC-3 model previously described. The simulation model operates by generating all the energy possible for the overload value of the installed capacity. Water in excess of that usable for generation or diversion for domestic water supply was spilled. The average monthly energy generated for each month over the 35 years of study was calcu- lated and an annual amount of energy for each year developed. The worth of the energy for each of the years was calculated. Table 4.14 presents the average annual energy and output factor for each scheme examined. Output factor is defined as the ratio of actual energy produced to the energy output that would have occurred if the machine had been operating at its nameplate rating through the entire period of time. The value of that energy is described in Section VI. A by-product of the operations study discloses shortages of domestic water during the winter months in the later years of the study period. These shortages demonstrate that consideration of the modeled operation scheme beyond 35 years is not warranted. Although these shortages are relatively minor, they indicate that alternative sources of domestic water supply or storage may have to be developed in about 36 years. (The analysis presented in Appendix 1 shows the shortages.) -41- Table 4.14 Energy Production Summary Water Supply Reservoir Power Reservoir High Low Installed Average Output Average Output Average Output Capacity Annual Factor Annual Factor Annual Factor Energy M Energy M Energy M (MW hours) (MW hours) 500 2616 60 2861 65 2747 63 N 1 650 2777 49 3068 54 2945 52 725 2830 45 3137 49 3012 47 800 2860 41 3189 46 3061 44 900 2879 37 3228 41 3099 39 1000 2892 33 3246 37 3116 36 1200 2900 28 3266 31 3135 30 1400 2900 21 3267 39 3136 26 13. Diversion Durinq Construction A hydrologic factor affecting the cost of the power dam but not the amount of energy generated is the need to divert streamflows during construction. The largest daily discharge during the 3 years of record at the USGS gage was 161 cfs; this is judged to be a reasonable value for diversion during construction. The water supply reservoir option has no need to consider diversion during construction. The nature of the existing works enable revision of the outlet works without disruption of the_ domestic water supply. -43- V. PROPOSED DEVELOPMENT PLANS AND COSTS Two basic development schemes were considered: (1) modification to the outlet works of the existing water supply reservoir, a longer penstock and a powerhouse at tidewater; (2) constructing a small diversion dam, a penstock and the same powerhouse at tidewater. The project options are shown on Figure 5-1. 1. Geology No detailed investigation was made of subsurface geology. At the proposed downstream dam site rock outcrops are visible on the right abutment. The left abutment is glacial till that the stream has incised to a depth of about 20 feet. The stream bed consists of gravel through small boulder material. Stream bed elevations appear to be controlled by underlaying bedrock which appears massive and competent. The penstock route is mostly over shallow tundra underlain by glacial till, and in the lower section, bedrock. Portions of the route are forested. The route is free of avalanche hazards. The power plant is located on a low terrace above tidewater. No foundation investigation was made, however, the surface appears to be underlain by bedrock at a shallow depth. The tailrace would be excavated through bedrock to tidewater. 2. Construction Materials Excellent quarry sites having stone from a maximum diameter of 5 feet to 2 inches for embankments are available locally. No economic sources of silt or clay suitable for impervious dam cores were found. Concrete is available at Petersburg for project needs. -44- 3. Accessability All alternative project features are located close to an exist- ing road network. Only short access roads from the Existing road net to the project sites are necessary. Sufficient lodging is available locally for construction forces, thus no construc- tion camp is envisioned. 4. Project Works The recommended plan for development comprises diversion of water in excess of domestic water needs from the existing municipal reservoir through a penstock to a power house at tidewater. The most economic point of diversion would be the outlet works from the existing reservoir. Extensive automation of the outlet system would be provided to assure no inadvertent drawdown of domestic water storage. Project features for the recommended plan will be described first, followed by a brief description of investigated, but not recommended, alternatives. 5. Municipal Water Supply Reservoir Alternative a. Storage for Power Purposes: Storage in the existing reservoir above spillway level would be increased by means of remotely controlled gates to provide an additional 9 acre feet of pondage above the existing water reservoir. No alterations to the existing dam are considered necessary. Reservoir data is provided in Table 4.7. b. Outlet Works: Changes in the existing outlet works would consist of: (1) Provision of motor controls on the existing spillway gates to enable power storage above the spillway crest. The gates would be provided with automatic water level controls to limit the maximum pool elevation to the top of the dedicated power storage. -45- Telemetry of water level and gate position as well as an alarm system would be provided to the municipal power plant control room. The level controls would be seasonally adjustable should it be warranted for future operational needs. (2) Addition of a 30-inch motorized gate and pipe stand system at the existing outlet below the dam. The 30-inch, battery operated, motorized valve would be controlled from two sources: (a) From the power house to automatically limit flow into the penstock to that desired at the turbine; emergency gate closure would be from the upper end of the penstock to limit waterhammer. (b) An independent system which would close the valve should power fail or the reservoir water level drop to the top of the domestic water storage pool. (3) Installation of a pipe stand system with air vent to limit the possible drawdown of the reservoir to the top of the domestic water pool. This can be accomplished by routing the penstock uphill from the existing outlet to a point where the penstock invert is at the top of the domestic water pool. An air relief vent will prevent formation of a syphon, therefore, the pipe can not fill unless the reservoir water Level is above the invert of the pipe at the high section. Thus, two independent systems to prevent drawdown of domestic water storage are provided. The air relief vent also will function to limit water hammer in the event of a shutdown and limit development of vacuum in the penstock. -46- (4) Provision of a storage battery system to energize gates, valves and the telemetry system during power outages. The existing powerline to the water treatment plant would be extended to provide normal energy. The system also would incorporate an ice regulation system; either resistance heaters or air bubblers. The proposed intake works is shown on Plate 5-1. C. Penstock: A 8,500 foot, 28 inch diameter, steel penstock designed to withstand static heads at 50 percent of yield strength, with an additional 1/8 inch allowance for corrosion, is provided. The penstock is routed above ground on concrete supports spaced at 50 foot intervals. Two weights of pipe are proposed; one having a wall thickness of .218 inches for the upper 6750 feet, and one with a wall thickness of .281 inches for the lower 1750 feet. (An economic analysis of penstock diameter and type selection is presented in Section VI, Plan Formulation.) d. Power House: The proposed power house site is located on lot 12 of the Sandy Beach Subdivision with access for the pen- stock provided on existing road easements. The power house will consist of a prefabricated metal building on a concrete slab about 18 feet square. The tailrace will extend under the slab with provision for installing generation units. Because of the underlying bedrock foundation, requirements are considered to be minimal. The turbine generator set selected is a 700 kw lowspeed radial impulse turbine with an asynchronous generator. Turbines of this type are referred to as "Ossberger" turbines. The turbine and generator selection is based on American practice which allows continuous operation at a 15 percent overload. e. Tailrace and tailwater setting: The tailwater setting was chosen as 10 feet MSL. This coupled with a draft head of about -47- 0 atmospheric vent inn rinm a ! "jI.9-0 ce of dam ]sting gate p of dam elev. 91 III pool 33.0 ottom over pool 2 9.72 3ke 12.41 PLATE 5 - ! PETERSBURG HYDROPOWER INTAKE WORKS 5 feet will allow the powerhouse to be located above the highest tides. A final tailwater setting will depend upon the charac- teristics of the turbine to be actually purchased. The tail race dimensions are minimal, a ditch 5 feet wide was used for estimating purposes. The powerhouse is shown on Plate 5-2. f. Control System: The Ossberger turbines are provided with a mechanism that regulates flow in accordance with a predetermined reservoir level. They are also provided with automatic over - speed shutdown. Since the generator is asynchronous, no speed regulation system is provided. Startup is automatic provided an excitation current from the municipal grid system is provided and a sufficient head is available. There are three constraints on generation: (1) Generation will be limited to that amount possible by the motorized gate position at the outlet works. This setting will be normally open, but regulated by the power plant operator to limit generation. (2) Generation will be automatically regulated by the unit by limiting discharge to that which will just maintain a predetermined water level in the reser- voir. Changes in turbine gate position will be slow enough to limit water hammer. (3) There will be no generation in the event of over - speed or loss of system power. In this event, there will be an automatic fast shutdown of the gates in the reservoir, admittance of air to the penstock and a slow shutdown of turbine gates to limit water hammer. g. Transmission Facilities: Transmission lines are provided from the powerhouse site to the existing power grid and from the existing water treatment plant to the water reservoir. -49- 9 TURBINE ELEV. I5.0' MEL -� EST. HIGHEST TI DELEVEL ELEV. 1 2.4 ' MIN,TAILWATER ELEV. 10.0 � a' A :o PLATE 5 -2 PETERSBURG HYDROPOWER POWERPLANT h. Access Roads: Access along an existing right-of-way is provided to the power house site. i. Rights -of -way and Relocations: Construction of the project will not require relocation of any known facilities. All project facilities are located either on state, municipality or Forest Service lands. No costs are envisioned for right-of-way acquisition. Two grade crossings of local roads by the penstock will be required. j. Cost Estimate: The construction cost estimate for the recommended project is shown in Table 5.1. The estimate is based on costs anticipated in October 1980. Present costs have been escalated by 7 percent to obtain 1980 unit costs. This rate is about an average of the current 6.8 percent ENR construction cost index and the 7.3 percent Bureau of Reclamation water projects index. Table 5.1 FEASIBILITY COST ESTIMATE Hydroelectric Power Development, City Creek near Petersburg, Alaska, Diversion from the Municipal Water Reservoir, Installed capacity 700 kw, Asynchronous Generation (Oct 1980) Reservoirs and Dams Dams Outlet works Gates and valves 30" motorized gate $20,000 28" manual gate 17,500 2-6" vacuum release 2,500 Ice control system LS Telemetry & controls Power Supply Power Plant Structures Concrete (16 cy @ $200/cy) 3,200 Building LS 6,000 Site Preparation LS 1,800 Waterways Penstock (2811) Steel pipe, 629,000 lbs @ $0.28/lb 176,000 Clearing LS 32,000 Pad, 4000 cy @ $5.00/cy 20,000 Supports, 140 @ $150 21,000 Fabrication LS 91,500 $(125,000) 40,000 5,000 50,000 30,000 340,000 $125,000 11,000 674,000 $125,000 695,000 -52- Table 5.1 Continued. Tailrace Rock excavation, 880 880 @ $30/cy Concrete (30 cy @ $200/cy) Turbines & generators (includes controls)LS Telemetry LS Misc. equipment LS Roads and Bridges 800 ft @ $12.50/ft Transmission Lines - Switch Yards Switchyard LS Transmission Line LS Clearing LS Poles and fixtures LS Conductors and devices LS Subtotal Engineering and Design (10%) Supervision During Construction (40) Contingencies (150) TOTAL CONSTRUCTION COST 24,000 6,000 264,000 20,000 20,000 10,000 5,000 33,000 3,000 20,000 10,000 M-OW1191111 ($858,000) 86,000 34,000 141,000 1,125,000 -53- 6. Alternative Works Considered for the Municipal Water Suppl Reservoir a. Turbine types: Three types of alternative turbines were considered. Pelton wheels are at the near limit of their effective head range. Because of the relatively low head they are slow speed and require speed increasers to mate with efficient generators. Additionally, the draft head below the nozzle can not be recovered. This would result in about a 5- foot loss of head or about 2 percent of the energy. Their advantage lays in being slightly more efficient at the best range of operations. Francis turbines are commonly used for the range of heads con- sidered. Their advantage accrues to regaining draft head and operating at higher efficiency at their best gate openings. Disadvantages are higher cost and inability to operate with good efficiency over the full range of discharges expected. Ossberger turbines have a guaranteed maximum efficiency of about 83 percent which is significantly lower than the best efficiency of either the Pelton or Francis turbines (87%). However, they maintain an efficiency of about 80 percent over a range of gate openings of 15 to 100 percent. A Francis turbine would typical- ly have an efficiency of about 75 percent at 50 percent gate and 40 percent at 30 percent gate. The relationships are shown graphically on Plate 4-2. Since flows vary widely for this pro- ject, an Ossberger turbine appears the best choice. To obtain similar efficiencies with Francis units, multiple installation would be necessary. b. Generator types: Two types of generators were considered. A conventional synchronous generator would add to system stability and can operate independently of the system grid. Its disadvantage however, is that it requires an elaborate and costly governoring system plus the increased expense of main- taining the governoring system, once installed. -54- The second type considered is an asynchronous generator. This type draws an excitation current from the system and, when driven by a turbine, generates power at the same frequency as system power. Its chief disadvantages are its inability to function independently of the system and its limitation to about one third of the system's capacity. Its principal advantages are: reduced maintenance, and a reduction in the capital cost of installed capacity of about $35 per kw. Since the ratio of installed capacity to total system capacity is well within limits, an asynchronous generation system is recommended. C. Generator Installed Capacities: See Section VI-4. d. Penstock types: Two basic types of penstock were considered; conventional welded steel versus corregated metal pipe combined with steel in the high pressure areas. Prices of pipes having the same water carrying capacity were $10.90 per foot for 20--inch steel pipe and $18.00 per foot for 24-inch asphalt coated, corregated metal pipe. The same ratio of costs generally would 'hold for all sizes under consideration. Therefore, conventional welded steel pipe is recommended. e. Penstock size: An economic selection of size was made for each of the two proposed schemes. Basic assumptions were: (1) the average flow in the penstocks would be near the average annual flow; (2) the head loss is proportional to the square of the discharge, therefore, the geometric mean monthly flow was representative of average friction losses; (3) the value of energy lost was equal to the estimated costs of replacement diesel generation in the future adjusted to 1980 values; and ( 4 ) the annual cost of the penstock was the cost of the pipe amortized over the 35 year project life. No salvage benefits were taken. -55- Plates 5.3 and 5.4 provide results of the economic analysis. A penstock diameter of 28 inches was selected for the recommended scheme and a diameter of 34 inches was selected for the power dam option. Wall thickness was selected based on static pressures plus an allowance for corrosion. Water hammer will be restrained to allowable limits by diversion and gate closure from the upper intakes. Gate closure rates at the turbine will be limited to those producing allowable pressures. 7. Power Reservoir Alternatives: Cost and benefit estimates were prepared for a power dam site located near the old abandoned water supply reservoir downstream from the municipal reservoir. The dam considered is a rockfill dam with a steel pile cutoff wall to prevent leakage. The inlet works consist of a steel conduit through the dam with a remotely controlled motor operated gate and trash rack at the inlet. The conduit is equipped with a "T" and a gated outlet to .serve as a reservoir drain and to provide diversion during construction. Penstock gate controls are similar to those considered for the water supply reservoir. The spillway is ungated. The spillway will be constructed of 4 foot stone placed on a 1 on 4 slope. The estimate also considers an 800-foot access road and a power line from the existing water treatment plant. Two heights of dam were considered. The lowest dam was the most economic. The top of the spillway for the low dam was set at elevation 274 with the thalweg of the existing stream at about 258 feet. The power plant is similar to that for the water reservoir option. The installed capacity having the best bene- fit to cost ratio and the best net benefits is 800 kw. A cost estimate for this option is shown in Table 5.2. -56- .N 55 45 .� ,40 a J 35 J 30 0 x 25 20 15 10 5 0 ANNUAL COST OF LOST ENERGY 12 14 NOTES 1. DISCONTINUITIES IN PENSTOCK COST CURVE DUE TO CHANGES 1N STD. PIPE WALL THICKNESSES. 2.n=0.013 L=8500FT 3• Q= 16 CFS ;TOCK COST WATER SUPPLY RESERVOIR ECONOMIC PENSTOCK DIAMETER PLATE 54 16 18 20 22 24 26 28 30 32 34 36 38 40 PIPE DIAMETER ( INCHES) 55 50 45 40 x Q N OTES 35 I. DISCONTINUITIES IN 0 PENSTOCK COST CURVE DUE TO CHANGES IN STD. M 30 PIPE WALL THICKNESSES 2.n=0.013 L;5450FT x 25 3. Q = 2 2 CFS 20 ANNUAL COST OF LOST ENERGY 15 IN 5 LOWER POWER RESERVOIR ECONOMIC PENSTOCK DIAMETER ro Q a U 0 z 0 U ts.f PLATE 5-4 ANNUAL PENSTOCK COST 0 1 1 1 1 [ 1 1 L 1 1 1 1 L 1 -- --I — 12 14 16 18 20 22 2.4 26 28 30 32 34 36 38 40 PIPE DIAMETER ( INCHES ) Table 5.2 FEASIBILITY COST ESTIMATE Hydroelectric Power Development City Creek near Petersburg, Alaska Low Power Dam Alternative Installed capacity 800 kw, Asynchronous Generation Reservoirs and Dams Access Roads Clearing & disposal 1 acre @ $1500/acre $ 1,500 Embankment 1900 cy @ $4.50/cy 8,500 Reservoirs Clearing 10 acres @ $500/acre 5,000 Dam and Spillways Dam Structure Stripping 4000 cy @ $3.00/cy 12,000 Rock fill 10,000 cy @ $10.70/lb 107,000 Sheetpile 100,000 lb @ $0.57/lb 57,000 Outlet works Structure 23,000 lbs @ $0.50/lb 11,500 Fabrication & installation 18,500 Trashracks 2000 lbs steel @ $0.50/lb 1,000 Fabrication & installation 2,000 (176,000) (183,000) 30,000 3,000 $ 10,000 5,000 359,000 $374,000 -59- Table 5.2 continued. Conduit LS 15,000 41x2001 steel pipe with stiffeners Ganti seeprings Gates and valves 100,000 60" manual gate valve 23,000 40" manual gate valve 17,000 20" motor controlled gate valve 29,000 34" manual gate valve 8,000 2-8" vacuum release 3,500 Fabrication 19,000 Ice control system LS Telemetry and controls LS Power supply LS Power Plant Structures Concrete, 16 cy @ $200/cy 3,200 Building, LS 6,000 Site preparation, LS 1,800 Waterways Penstock (34") Steel pipe 550, 800 lb @ $0.28/lb 154,200 Clearing, LS 26,000 Pad, 3,600 cy @ $5.00/cy 18,000 Supports, 110 @ $150 16,500 Fabrication 51,300 Tailrace 31,000 Rock excavation, 800 cy @ $30/cy 24,000 Concrete, 35 cy @ $200/cy 7,000 5,000 20,000 10,000 266,000 11,000 603,000 624,000 Table 5.2 continued. Turbines and generators LS 266,000 (includes controls) Telemetry LS 20,000 Miscellaneous equipment LS 20,000 Roads and Bridges 800' @ $12.50/ft Transmission Lines - Switchyard Switchyard LS Transmission Line Clearing LS 3,000 Poles and fixtures LS 20,000 Conductors and devices LS 10,000 Subtotal Engineering and Design (10%) Supervision during Construction (4%) Contingencies (15%) TOTAL 10,000 38,000 5,000 33,000 ($1,036,000) 110,000 45,000 193,000 $1,384,000 -61- A cost estimate also was prepared for an alternate structure 10- feet higher which would provide more storage and 6 percent more head. The cost estimate is identical except for an increase of $300,000 for the cost of dams and outlets. No detailed cost estimate is provided. With the project operated as a run of the river plant, no benefits accrue to the increased storage. The 10 foot increase in head results in a 4 percent increase in energy. This plant is at the topographic limit of dam height. 8. Operation and Maintenance Costs Operations and maintenance costs mainly consist of: routine servicing of control systems, annual servicing of the turbine generator unit, cleaning of gates and trash racks, and ice removal.. Maintenance costs are significantly greater for syn- chronous generation units because of the speed governors. Table 5.3 lists O&M costs considered for evaluating various alterna- tives. O&M costs were considered to be independent of installed capacity. Reservoir Option Table 5.3 ANNUAL OPERATION AND MAINTENANCE COSTS Asynchronous Generation Domestic Water Reservoir $15,000 Power Reservoir 15,000 Synchronous Generation $20,000 20,000 Costs of maintaining the power dam are offset by the increased cost of maintaining control equipment for the municipal water reservoir. -62- 9. Replacement Costs Replacement costs are the cost of replacing components of the power system that have worn out. The economic analysis is based on 35 years. The major system components have a economic life of about 35 years, therefore, no replacement of major system components is envisioned. However, minor system components, such as control systems and gate operating motors, have a short- er life and some replacement will be necessary. For purposes of the feasibility analysis, annual replacement costs of $5,000 per year for the municipal water reservoir diversion and $10,000 per year for the power reservoir is used. The increase for the power reservoir alternative is attributed to the cost of replac- ing stone in the dam spillway. 10. Salvace Value No salvage value has been assigned. Domestic water needs begin to exceed the available supplies during low flow season at the end of the 35 year study period. Therefore, a need is indicated to develop other water resources at that time. There is consid- erable uncertainty over the future availability of water for power generation beyond the study period. Costs of removing pipe and other metals for salvage would nearly exceed their market values. Additionally, the 1980 value of any salvage in the year 2025 at 7.5 percent interest would be about eight cents on the dollar. Consequently, salvage value has been ignored. -63- VI. PLAN FORMULATION I. Alternative Power Sources The existing generation system is a mixture of hydro and diesel generation. Generation characteristics are provided in Table 6.1. Table 6.1 POWER SYSTEM CHARACTERISTICS Hydro Diesel Total Installed Capacity (Kw) 2,000 3,700 5,700 1) Dependable Capacity (Kw) 1,600 3,700 5,300 1) Total Generation., 1978 Mwh 8,300 11,824 20,124 2) Projected Generation, 1978 Mwh 19,500 1) Projected Generation, 1980 Mwh 20,600 1) Projected Generation, 2015 131,000 3) Energy Supplied by the recommended Project Average Mwh 2,820 4) Highest Year Mwh 4,000 4) Lowest Year Mwh 2,030 4) Highest Month 599 4) Lowest Month 0 4) 1) From "Petersburg Municipal Power and Light System Review and Planning Guidelines", prepared by Robert W. Retherford and Kent Miller, November, 1976. 2) From Petersburg Municipal Power and Light operating records. 3) Extended from 1978 Historic Base at 5.5% annual rate of growth. 4) From Power Study, using simulated flows. -64- From Table 6.1, the energy from the proposed plant will be a small part of the diesel generation and will, therefore, always be marketable as long as its cost is less than the marginal cost of alternative diesel energy. 2. Economic Criteria a. Benefits: The only economic benefits for the recommended project are from the replacement cost of the diesel fuel. Diesel costs have been esti- mated as follows: The 1979 cost of fuel and lubricants is $0.573 per gallon based on April, 1979 purchases. From the Retherford Report, energy is generated at the rate of 13 kwh/gallon. The 1979 cost of energy is then $44.077 per Mwh. From information supplied by the Alaska Power Authority the expected rate of increase of fuel and lubricants is 7% per annum. This rate may be overly conservative considering the current and projected escalation cost of petroleum products. However, this value is judged suitable for purposes of the study. The cost of energy during any year is then 44.077 (1.07)n where n is the number of years past 1979. Since the only benefits are from the escalating cost of diesel fuel replacement and the decline of water availability, due to diver- sions, the equivalent diesel energy cost is defined as the average annual equivalent of the diesel fuel displaced. s b. Costs: (1) Interest: The interest rate specified by the Alaska Power Authority is 7.5%. This rate is used for all economic evaluations. (2) Economic Payout Period. A 35--year period is used in which to recover all capital costs. This period was specified by the Alaska Power Authority. At 7.5% interest and a 35-year period, the corresponding annual capital recovery factor is 0.08148. C. Base Year: The assumed construction schedule would have power on the line on the first of October, 1980, which corresponds to the start of the 1981 water year. Therefore, all initial values for economic calculations are based on October, 1980; and all cost estimates are based on the anticipated October 1980 costs. 3. Penstock Sizin Penstocks were economically sized according to the criteria provided in Section V-6,e, and the cost of money and value of power describ- ed above. The value of the average annual energy lost to friction for each penstock was compared to the annual cost for a range of diameters of penstocks and the size having the least annual cost was selected. An important assumption in this analysis is that the square root of the square of the average monthly flows (geometric mean) is appro- priate for determining annual costs. This assumption is appropriate because the losses of energy to friction are proportional to the square of the discharge. The analysis considers only monthly flows, whereas there are more fluctuations in daily flows and the reservoirs are incapable of smoothing these fluctuations. However, the highest daily fluctuations would be spilled and not available for power generation. Therefore, the assumption made is considered reasonable for a feasibility analysis. 4. Installed Capacity The optimum installed capacity for each of the two alternatives considered was determined according to the following sequence: a. Construction costs were determined for each alternative and a range of installed capacities. b. Construction costs were converted to average annual costs by multiplying by an amortization factor of 0.08148. C. Annual operation and maintenance and annual replacement costs were determined and added to the average annual construction cost. The result is termed average annual cost. d. A curve of average annual cost versus installed capacity resulted. e. The amount of energy generated each year was determined by applying the HEC-3 Model described in Section IV. f. The 1980 value of that energy was determined by multiplying each year's value by the appropriate value of energy factor and the appropriate present worth factor. g. The average annual value of energy was determined by amortizing total 1980 present value of the energy produced using an amortization factor of 0.08148. h. A curve of average annual benefits resulted. i. A net benefit curve was derived by subtracting the annual costs from the annual benefits for each capacity. j. The benefit to cost ratio was determined by dividing the annual benefits by the annual costs for each capacity. k. The installed capacity having the highest benefits to Cost Ratio was adopted for recommendation. -67- 1. Mill rates were derived for each installed capacity by dividing the average annual energy production by the average annual cost; resulting curves were plotted. The resultant curves, which are presented as Plates 6.1, 6.2, and 6.3, show that the most economic capacity alternative site is: 700 kw for the municipal water supply reservoir alternative and; 800 kw for the option of constructing the power reservoir alternative. Similar curves were prepared for the synchronous generation option; however, since the costs were significantly higher and the recom- mended capacity is within the limits of the system to absorb asyn- chronous generation, the synchronous case curves are not included. Curves of mill rates versus installed capacity for the two options are included as Plate 6.3. The average annual energy production for the recommended project is 2830 MWH. The cost of that energy is 38.7 mills per kilowatt hour. 5. Choice of Diversion Sites The foregoing study provided cost benefit comparison for both sites. The option requiring a new dam is less economic and was dropped from further consideration. The criteria used for comparison was the benefit cost ratio. 6. Recommendation On the basis of the above analysis, a project consisting of a 700 kw power plant, a 28-inch penstock and diversion from the existing water supply reservoir is recommended. Emu 400 300 200 •s K 500 INSTALLED 1000 CAPACITY ( KW ) Q. 0 0 co 2 t— u- ui z uj m 1500 PLATE 6 -- 1 ECONOMIC ANALYSIS DIVERSION FROM MUNICIPLE WATER SUPPLY RESERVOIR ASYCHRONOUS GENERATION ;•• •w O 0 -200 v 500 1000 1500 INSTALLED CAPACITY ( KW ) PLATE 6 2 ECONOMI C ANALYSIS POWER RESERVOIR ASYCHRONOUS GENERATION 3 EQUIVALENT AVG DIESEL ENERGY COST I S 124.6 MILLS 50 p�� ERS1ON pO*E� �S �4N = 45 45.8 MILLS WITH 80OKW INSTALLED CAPACITY w E¢ DES 40 MOST ECONOMIC ENERGY IS --° 38.7 MILLS WITH 70OKW INSTALLED CAPACITY 35 30 0.5 1.0 1.5 INSTALLED CAPACITY ( M W) BASED ON AVG ANNUAL ENERGY AND AVG ANNUAL COSTS- 1980 SASE PLATE 6-3 CITY CREEK HYDROPOWER PROJECT MILL RATE VS CAPACITY VII. ECONOMIC ANALYSIS 1. Project Costs Project costs reflect the total cost of construction including engineering anddesign, supervision during construction and the cost of operation and maintenance. No allowance is provided for the cost of feasibility studies or for the cost of federal, state and local activities in administering this project. Project costs in accordance with the cost estimate information presented in Sections V and VI are: Pre -operation Installation Costs $ 1,125,000 Annual Equivalent Installation Cost (7 1/2o interest, 35 year period) 91,670 Operation, Maintenance and Replacements 20,000 Total Average Annual Costs, 35 year period $ 1111670 2. Benefits The tangible benefits of the City Creek Hydroelectric Project are limited to the cost of diesel fuel and lubricants for alternative diesel electric generation. No benefits arise from firm capacity. As discussed in Section VI, the cost of the energy produced from the recommended plant is 38.7 mills and the value of the diesel alternative replaced is 124.6 mills. With adjustments for the escalating cost of diesel fuel (7o), discounting for interest at 7 1/2% over a 35 year period, and applying a capital recovery factor of .08148 the average annual value of the energy supplied would be $350,740. -72- 3. Benefit to Cost Ratio The ratio of evaluated tangible benefits to estimated total economic costs is summarized below. Total Annual Benefits Total Annual Cost Benefit to Cost Ratio $350,740 111,670 3.14 -73- VIII. REQUIRED FUTURE ACTIONS The investigative work for this report has been conducted in sufficient detail to determine engineering and financial feasibility of the measures proposed and recommended. However, certain additional investigations will be necessary before start of construction. These are the normal preconstruction activities required to accomplish final design and construction plans and specifications. Preconstruction activities further should include a detailed survey and geologic investigation of the penstock and transmission line routes and power house site. This work is necessary in order to optimize alignments and facility locations. - 74- IX. GOVERNMENT REQUIREMENTS This draft of the role, scope and permitting requirements of federal, state and local agencies fo the proposed City Creek Hydropower Project to serve Petersburg, Alaska is present for preliminary information and guidance. Pending further planning and preparation of preliminary engineering, design and construction documentation, the scope of the information presented is necessarily generalized. However, as presented the coverage should suffice for initial planning purposes by the various agencies directly involved in furthering the proposed project beyond the conceptual phase. As indicated under subparagraph 12.a., following, it is suggested that at such time as permitting actions are required for the project, a master application be filed with the State of Alaska, Department of Environmental Conservation. This Department will then circulate the application to appropriate agencies for input. Final decisions will be made on a coordinated basis. Key Permits, coded to paragraph numbers in the attached listing, which are considered necessary for implementation of the project are as follows; Table 9.1 KEY PERMIT REQUIREMENTS 1. l.a.(1)(a); COE - Permit for construction in and affecting navigable waters of the United States as designated by the COE. 2. 2. (1) , USF,S - Permit for right-of-way, use and occupancy on land within the Tongass National Forest. -75- 3. 4. 5. T. 7. 3.a.(1); DOE/FERC - Permit and/or license for construction and operation of hydro -electric power development and any associated transmission lines. 6.b.(1); DOT/FAA - Review constructio plans for compliance with air-sapce usage and safety. 8.b.(l)(a); EPA - Permit (authorization) to discharge into naviagable water under the National Pollutant Discharge Elimination System (NPDES). 8.b- (1)(c); EPA - Exemption from noise control standards. ll.a.(1); ALASKA - Review/approve construction plans POWER (if project funding obtained AUTHORITY through or from the State of Alaska). ll.b.(1); PUBLIC - Amend authority to operate existing UTILITIES electrical generation/transmission COMMISSION utility, as necessary, to include expansion of the electrical utility system. 12.a.(2); DEC - (a) (c) (d) (e) (i) Permit to discharge; or; Permit for waste water discharge. Review facility plans for compliance with air quality standards. Permit, variance and/or exemption from safe drinking water standards. Review/approve plan for disposal of construction spoil, as required. -76- 8. 13.a.(2); ADFG - Review and/or permit work in, near, or involved in crossing, designated anadromous fish streams. (In any event, recommended ADFG be contacted to determine if any permitting action or approval may be required.) 9. 15.b; DNR/DIVISION OF -- (1) - Issues any required land use LANDS (occupancy) permit. (2) - Issues permit for taking of mineral material and merchantable timber, as required. (3) - Issues permit for burning slash, non -merchantable timber, etc., as required. (7) - Issues water resources permits (taking of State waters). 10. 16.b.(1); DIVISION OF - Review of construction plans for FIRE compliance with State fire PREVENTION prevention codes. 11. 18.a.; OFFICE OF -- Review program and/or construction COASTAL plans for compliance with Alaska MANAGEMENT Coastal Management Program. 12. 19. MUNICIPALITY OF - Issues permits and/or PETERSBURG authorizations as mya be required under municipal ordinances. 13. 20. PRIVATE LAND - As may be involved, grants HOLDERS permission for right-of-way or land use on private land holdings. -77- Table 9.2 GOVERNMENTAL AUTHORITIES AGENCY AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING 1. Chief, Army Corps of Engineers (COE) a. District Section 10, River and Harbor Engineer, Act of 1899, 30 Stat. 1151, Alaska 33 U.S.C. 403, Title 33 District C.F.R. Part 209, Sec. 404 of the Federal Water Pollution Control Act Amendments of 1972, 36 C.F.R. 327. Exec. Order 11988, May 24, 1977, Floodplain Management. (1) Administers overall policy matters which may involve the COE. (1) Exercise the authority of the Chief, COE on the following matters: (a) Permits for construction in and affecting navigable waters of the United States as designated by the COE. (b) Permits for fills and dredging for materials in navigable waters as designated by the COE. (c) Permits for temporary occupation and use of any public works in navigable waters of the U.S. ( d ) Reduce risk of flood loss and minimize impact of floods on human safety, health and welfare; insure adequate provision for the evaluation and consideration AGENCY 1. Continued 2. Department of Agriculture, U.S. Forest Service (USES) 3. Department of Energy (DOE) a. Federal Energy Regulatory Commission (FERC) 4. Department of the Interior (DOT) a. Office of Secretary AUTHORITY FOR INVOLVEMENT 30 Stat. 34-36; 16 U.S.C. 473-478, 74 Stat. 215, 16 U.S.G. 528-531, 88 Stat. 476, 16 U.C.S 1601-1610, 90 Stat. 2947; 43 U.S.C. 1761 and 1763. 91 Stat. 569; 42 U.S.C. 7131; Exec. Order 12009, Sept. 13, 1977; Title 18 C.F.R.; 16 U.S.C. Stat. 792 et seq. the 30 U.S.C., 185, Title I, P.L. 93-153, P.L. 94-579, 43 U.S.0 1701 et seq. ROLE/SCOPE AND PERMITTING of flood hazards in licenses and permits. Provide guidance to applicants to evaluate effects of proposals in floodplains. (e) Administers "wetlands" policies and requirements. (1) Permits Rights -of -Way (ROW), use, and occu- pancy in the National Forest system. (1) Issues permits and licenses for construc- tion and operation of non -Federal hydro -elec- tric power developments and associated trans- mission lines. (1) Administers overall policy matters which may involve the DOT on project under 43 U.S.C. 1701 et seq. AGENCY 4. Continued b. Bureau of Land Management (BLM) c. U.S. Geological Survey (USGS) d. U.S. Fish and Wildlife Service (FWS) AUTIiORITY FOR INVOLVEMENT 43 U.S.C. 31, 43 U.S.C. 31 (b), 28 Stat. 398 Land Use Management (50 C.F.R. 29), 16 U.S.C. 777-77K, 1.6 U.S.C. 668- 668D, 16 U.S.C. 1531-1543, 16 U.S.C.(2) 460, 16 U.S.C. 661--667E, 16 U.S.C. 669- 6691, 16 U.S.C. 668DD- 668JJ, 16 U.S.C. 715K, 16 U.S.C. 742a-742j; 70 stat. 1119. e. Natidnal Park 39 Stat. 536; 16 U.S.C. Service (NPS) 1 P.L. 89-665, Executive Order 11593, May 13, 1971. ROLE/SCOPE AND PERMITTING (1) Acts for the Secretary concerning 4.a.(1) above. (2) Maintains public records on land status. (3) Performs land surveys attendant to transfer or sale of public lands. (1) No permitting authority ( 2 ) May be involved in an advisory review capaci- ty to governmental en- tities regarding geolo- gic, seismic, thermal, geotechnic and hydrolo- gic criteria and design review functions. (1) Responsible for proper management of migratory birds, fish and wildlife. ( 2 ) May be involved in the project in reviewing alignment, criteria and designs as they may re- late to protection of endangered species, mi- gratory birds (water- fowl and rapters), anadromous fish and wildlife. (1) May be involved in support of the BLM and USFS in assuring com- pliance with the Anti- AGENCY 4. Continued f. Bureau of Indian Affairs (BIA) g. Mining enforce- ment and Safety Administration (MESA) 5. Department of Labor, Occupational Safety and Health Administration (OSHA) AUTHORITY FOR INVOLVEMENT 42 Stat. 208; 25 U.S.C. 13 48 Stat. 984; 25 U.S.C. 461, et Seq., Title 25 C.F.R. Part 161. 80 Stat. 772; 30 U.S.C. 721; Secretarial Order No. 2953, May 7, 1973. Occupational Safety and Health Act of 1970 (84 Stat. 1590) ROLE/SCOPE AND PERMITTING quities Act, [16 U.S.C. 431--433; 34 Stat. 225] , and recovery of archae- ological or paleontolo- gical remains, [16 U.S.C. 469-469c; 74 Stat. 220]. ( l ) May be involved if the project impacts tribal individually owned or government managed Indian lands. Also may be involved in an an- cillary role in promot- ing Alaska Native hire and in advising Alaska Native Corporations in- cident to their role/ involvement in project matters. (1) Inspection and approval of mineral (gravel) ex- traction activities occuring on Federal land. MESA is expected to work independently of other Federal Agencies in inspecting applicable gravel removal operations against MESA standards. (1) May be involved in inspection/enforcement of safety and health standards. This responsibility is AGENCY 5. Continued 6. Department of Transportation a. U.S. Coast Guard (USGS) 9 AUTHORITY FOR INVOLVEMENT 14 U.S.C, 1; 80 Stat. 931; 30 Stat. 1151, 33 U.S.C. 401, Title 33 C.F.R., Part 115.50. ROLE/SCOPE AND PERMITTING mostly assumed by the State of Alaska Depart- ment of Labor; see 14.b. below.) (1) Issues permits for con- struction of bridges over USGS designated navigable waters. (2) Principal Federal Agency (with EPA) involved in prevention, detection, containment, recovery and mitigation of pollution caused by spills of oil and other hazardous pollutants into or upon the navigable waters of the U.S. and adjoining shorelines and waters of the continguous zone. (3) Enforces rules and regulations for security of ports and movements of vessels in U.S. waters - including among other functions, monitoring on -off loading of hazardous materials at Alaskan ports. 1 AGENCY _ AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING 6. Continued b. Federal 14 C.F.R. part 77 (1) Possible review of Aviation construction affecting Administration airspace usage, control (FAA) and safety. 7. Department of 18 U.S.C. Section 843; (1) Permit for use and Treasury, Bureau 27 C.F.R. Part 181 storage of explosives. of Alcohol, COMMENTS: Actual or Tobacco and possible involvement in Firearms the proposed project is unknown at this time. Normally, use and storage of explosives is more appropriately permitted by OSHA (see 5. above) or State of Alaska Department of Labor (see 14.b. below.) 8. Environmental Protection Agency (EPA) a. Office of the (1) Administers overall Administrator policy matters involving the EPA. b. Regional Federal Water Pollution (1) Administers and Administrator Control Act §401, 402, 40 exercises authority of C.F.R. Part 125; 40 C.F.R. Administrator in Part 122. Resource abatement and control Conservation and Recovery of pollution concerning Act of 197E §300, §30, the following: 40 C.F.R. Part 230; Safe (a) Permit for dis- Drinking Water Act §1415, charge of pollu- 1416, 1421, 40 C.F.R. Part tants into navi- 142. Noise Control Act of gable waters 1972. 40 C.F.R. Part 204 (authorization and 205. Clean Air Act of to discharge AGENCY AUTHORITY FOR INVOLVEMENT B. Continued 1970, 40 C.F.A. Part 112, 33 C.F.R. part 156; Atomic Energy Act of 1954, 10 C.F.R Part 20. Trade Substances Control §4 (c), Federal Environmental Pest Control Act of 1972, 40 C.F.R. Part 162. I ROLE/SCOPE AND PERMITTING under the National Pollutant Discharge Elimination System). (b) Permit for solid water treatment, storage and dispo- sal. (c) Exemption from noise control standards. (d) Permit for waste- water discharges. ( e ) Permits or variances for air pollution. (f) Permit, variance and/or exemption from safe drinking water standards. (2) Review, approve or waiver of oil spill-, contingency disposal plans. (3) Review plans and/or issue permits, licenses or exemptions for treatment, storage, transportation and disposal of hazardous material. (4) Issue permits or exemp- tions for use and dis- posal of pesticides and herbicides. AGENCY 8. Continued AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING (5) Permit for disposal of pipeline spoils. (6) Permit and/or variance for dust control. ( 7 ) Permits or variances for blasting. COMMENTS: At this time it is unknown if the Regional Administrator or the Alaska operations Office/.EPA will be delegated authority to supervise and administer all preceding actions 8.b. (1) through ( 7 ) or if this responsibility will be shared with other authorized individuals. Also, it is to be noted that the State of Alaska, Department of Environmental Conservation (see 12.a. below) promulgates all the requirements listed under 8.b.(l) through (6), including issuance of appropriate permits, licenses, authorizations, etc . , on behalf of the State of Alaska. Normally, this will be a coordinated activity between EPA and DEC. AGENCY AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING FEDERAL AGENCIES WHICH MAY HAVE ANCILLARY/ADVISORY INTEREST IN THE PROJECT 9. Council on National Environmental May be involved in an Environmental. Policy Act of 1969 (83 advisory role to the DOS, Quality Stat. 852; 42 U.S.C. DOE, EPA or COS; in environ- 432, et seq.) mental assessment delibera- tions or controversies, should they become necessary. 10. Department of Commerce, National Oceanic and Atmospheric Administration, (NOAA) a. Administrator 16 U.S.C. 1451 et seq. (1) Possible coordination for Coastal and/or advisory role Zone concerning project Management compliance with the Coastal. Zone Management Act of 1972, as amended in 1976 (P.L. 92-583 and P.L. 94-370). b. National Title 16, Chapter 9, U.S.C. (1) Possible coordination Marine and/or advisory role Fisheries only to other involved Service Federal/State agencies as may be required concerning protection of anadromous fish. STATE GOVERNMENT STATE OF ALASKA 11. Department of AS 44.33 Commerce and Economic Development I AGENCY 11. Continued a. Alaska Power Authority b. Alaska Public Utilities Commission 12. Department of Environmental Conservation (DEC) a. Office of the Commissioner AUTHORITY FOR INVOLVEMENT AS 44.56.010--44.56.240 AS 42.05.010--42.05.721 AS 44.46 AS 43.03; 18 AAC 50; 18 AAC 60; 18 AAC 72; 18 AAC 75; 18 AAC 90 ROLE/SCOPE AND PERMITTING (1) Promotes, develops and advances construction, acquisition, financing and operations of hydroelectric and fossil fuel generating projects. (1) Regulates all aspects of public utilities involving - rates, classifications, rules, regulations, practices, services and facilities of public utilities. (1) Over_all administration, coordination and development of policies, programs and planning regarding the environment and enforcing standards for prevention and abatement of water, land and air pollution. (2) Issues permits, Licenses, variances or exemptions for the following: COMMENT: Note that actions listed closely parallel or are identical to those AGENCY 12. Continued 1 AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING listed for EPA, item 8.b.(1) through (6) preceding. (a) Permit for discharge of pollutants into waters of the State. (It is understood that DEC authority in this regard extends to Federal/Public lands.) (b) Permit for solid waste treatment, storage and disposal. (c) Permit for waste water discharge. (d) Permits for variances for air pollution. (e) Permits, variances and/or exemptions from safe drinking water standards. (f) Review, approve or waiver of oil (petroleum/ petroluum products) spill contingency disposal plan. (g) Permits, licenses or exemptions for treatment, storage, handling and I AGENCY AUTIiORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING 12. Continued disposal of hazardous material. (h) Permits, exemptions for use and dispo- sal of pesticidies and herbicides. (i) Permits for dispo- sal of pipeline construction spoils. (j) Permits or variances for dust abatement/control. COMMENT: Master Permit Application The 1977 Legislative Session enacted a law establishing a simplified procedure to assist those who must obtain a permit from one or more federal, state or local government agencies. While this procedure is not mandatory, a person proposing a project may summit a single master application to the Department of Environmental Conservation who will then circulate the application to the other appropriate - regulatory agencies for comment. Final decisions will be made on a coordinated basis. State Permits included in this process are shown on Attachment 1. AGENCY ___ T AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING 13. Department of Fish and Game (ADF&G) a. Office of the AS 44.39; AS 16.05; AS 16.20 (1) Overall administration Commissioner of State programs for management, conservation and development of commercial fishing, sport fishing and game resources. Enforcement of Fish and Game laws. ( 2 ) Issues permits or authorizes work in, near or involved in crossing designated anadromous fish streams as promulgated under A.S. 16.05.870. 14. Department of Labor (DL) a. Office of the AS 44.31; AS 23.05.060 (1) Overall administration Commissioner and enforcement of the State's laws relating to resident hire, occupational health and safety, labor relations and labor law compliance. b. Division of AS 18.60.010--.105; (1) Inspects work places Occupational AS 18.60.580--.660; for compliance with Safety and AS 18.60.670-.695. State safety and health Health standards and investi- gates job --related acci- dents and illnesses. AGENCY AUTHORITY FOR INVOLVEMENT 15. Department of Natural Resources a. Office' of the AS 44.37 Commissioner b. Division of AS 38.05; AS 46.15; AS 41. Lands 15; AS 41.20. ROLE/SCOPE AND PERMITTING (1) Overall administration of the State's programs for construction and development of natural resources; forests, lands, water, minerals, oil and gas, parks, historical sites, agriculture and soil conservation. (1) Issues temporary or other land use permits. (2) Conducts sales and/or issues free use permits for mineral or vegetative materials on State lands; includes sand, gravel, rock and merchantable timber. (3) Issues permits for burning slash, non -mer- chantable timber and other combustible waste material generated by construction on State lands. (4) Performs wildfire detection and suppression on State lands. AGENCY 15. Continued fl .16. Department of Public Safety a. Office of the Commissioner b. Division of Eire Preven- tion AUTHORITY FOR INVOLVEMENT AS 44.41 AS 18.70.010--.100 ROLE/SCOPE AND PERMITTING ( 5 ) dandles disposal of sand, stone, gravel, timber, etc., located below high water mark of navigable waters so identified by the State. (6) Maintains public records on State land status. (7) issues water resources permits (taking of State waters for industrial or potable use). (1) Overall administration of State programs for law enforcement and protection of life, property, fish and wildlife; State police, fire prevention and watercraft safety programs. (1) Reviews plans and inspects structures for compliance with State fare prevention codes and requirements. Pro- ject related (perman- ent) facilities must meet requirements promulgated by the State Fire Marshall. AGENCY 17. Department of Transportation and Public Facilites (DOT-PF) a. Office of the Commissioner 18. Division of Policy & Planning Development (office of the Governor) a. Office of Coastal Management AUTHORITY FOR INVOLVEMENT Executive Order No. 39 (1977), AS 44.42.010-080. AS 44.19.891--894; AS 46.35.010-210; AS 44.47.095; b AAC 80.010-160 ROLE/SCOPE AND PERMITTING (1) overall administration of construction, maintenance and operation of State highways, airports and marine transportation system. (2) Reviews designs and issues authorizations incident to project related work which may affect state roads and highways. (3) Enforces public highway load limitations and maintenance. (4) Exercises State authority for use and operation of State airports. Lead agency in implementing and coordinating the Alaska Coastal Management Act of 1977. Activities within the coastal zone are required to comply with the Alaska Coastal Management Plan regu- lations as promulgated through the OCM. AGENCY OTHER GOVERNMENT OR PRIVATE INTERESTS 19. Municipalities 20. Private Land Molders 21. Public Utilities AUTHORITY FOR INVOLVEMENT ROLE/SCOPE AND PERMITTING (applicable codes, laws or charter) Issue permits, authoriza- tions or non -objections for project related facilities occupying or affecting municipality interest land. Issues permission to cross or occupy land. May involve permission to cross or utilize public utility ROW, or facilities as required. i l/ Principal sources for Authority citation are: 1° (1) 1977/78; 1978/79 Government Manual. (2) State Statutes, and Alaska Blue Book, 1977. (3) State of Alaska Coastal Management Program and Draft Environmental Impact Statement, January, 1979. ATTACHMENT 1 Waste water disposal permit - AS 46.03.100, 18 AAC 72; • Solid waste disposal permit - AS 46.03.100, 18 AAC 60; • Air emissions permit - AS 46,03.150, 18 AAC 50.120; • Pesticides permit - AS 46.03.320, 18 AAC 90; ° Surface oiling permit - AS 46.03.740, 18 AAC 75; ° Open burning permit - AS 46.03.020, 18 AAC 50 . 120 ; ° Anadromous fish protection permit -- AS 16.05.870, 5 AAC 94.100; ° Critical habitat area permit -- AS 16 . 20 . 250 - 16 . 20 .260 ; State game refuge land permit - AS 16.20.050 - 16.20.060; ° Encroachment permit - AS 19.25.200; • Utility permit - AS 19.25.010; • Driveway permit - AS 19.05.020, 17 AAC 10.020; • State park incompatible use permit - AS 41.20.020, 11 AAC 18.010; ° Access road permit - AS 41.20.020, 11 AAC 18.0 20 ; ° Brine or other salt water waste disposal permit - AS 31.05.070; 11 AAC 22.250; ° Right-of-way and easement permits - AS 38.05.330, 11 AAC 58.200; • Special land use permit - AS 38.05.035, 11 AAC 58.210; • Tidelands permit - AS 38.05.320, 11 AAC 62.710; ° Tidelands right-of-way or easement permit - AS 38.05.320, 11 AAC 62.810; ° Limited personal use permit - AS 38.05.320, 11 AAC 62.820; • Permit to appropriate water -- AS 46.15.040, 11 AAC 7 2.050 ; ° Dam construction permit - AS 46.15.040, 11 AAC 72.060; ° Preferred use permit - AS 46.15.040, 11 AAC 72.160; ° Permit for use of timber or materials -- AS 38.05.110, 11 AAC 76.185; ° Special material use permit -- AS 38.05.115, 11 AAC 76.540; • Surface use permit - AS 38.05.255, 11 AAC 86.600; ° Burning permit during fire season - AS 41.15.050; 11 AAC 92.010; ° Miscellaneous state land use permit - AS 38.05.035, 11 AAC 96.010; ° Right-of-way permit - AS 38.05.330. REFERENCES 1. Alaska Department of Fish & Game, January 1973, Alaska's Wildlife and Habitat. 2. Alaska Department of Fish & Game, 1978, Fisheries Atlas - Vol. I & II. 3. Dames & Moore, September 1977, A Study of Dredging Means & Disposal Methods in Eighteen Alaskan Small Boat Harbors. 4. The Hydrologic Engineering Center, Corps of Engineers, U.S. Army, July 1974, Users Manual, HEC-3 Reservoir System Analysis for Conservation, Computer Program 723-X6--L2030. 5. The Hydrologic Engineering Center, Corps of Engineers, U.S. Army, HEC-4, Monthly Streamflow Simulation, Computer Program 723--X6-L2340. 6. Lamke, R. D., 1979, Flood Characteristics of Alaskan Streams; In - U.S. Geological Survey, Water Resources Investigations 78-129. 7. Petersburg Municipal Power & Light Operating Records. 8. R. W. Retherford Assoc. & K. Miller, November 1976, System Review and Planning Guidelines for Petersburg Municipal Power & Light. 9. R. W. Retherford Assoc., September 1978, Revised Preliminary Appraisal Report, Tyee Lake. 10. Selkregg, L.L., Alaska Regional Profiles, Southeast Region. 11. University of Alaska, Institute of Social & Economic Research, Aug. 1976, Electric Power in Alaska, 1976-1995. 12. U.S. Army Engineer District Alaska, Corps of Engineers, May 1966, Detailed Project Report on Petersburg Harbor, Alaska. 1 .v.'1 '4 K 1I 3 C. 13.. _._T'(J ..C-r I: ri (., 9 ,1 v C . 3 '1 A. 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