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HomeMy WebLinkAboutHydaburg Hydro Investigation 1991Hydaburg Hydro Investigation November 1991 Walter J. Hickel, Governor Charlie Bussell, Executive Director Alaska Energy Authority This study was prepared under the direction of the Alaska Energy Authority by: HDR Engineering, Inc. 4446 Business Park Boulevard Building B Anchorage, Alaska 99503 The technical content of this report has been reviewed and is accepted. ~;/~ Richard Rogers;> Date Project Manager Date A Hydabur'g-KJawock intertie and the Reynolds Creek hyroelectric project are recommended for economic analysis and review of financing options, with the goal of long-term. island-wide power needs. David Denig-Chakr Director. Rural Programs Date Hydaburg Hydro Investigation Prepared for State of Alaska Walter J. Hickel, Governor Alaska Energy Authority Charlie Bussell, Executive Director 701 East Tudor Road PO Box 1 90869 Anchorage, AK 99519 (907) 561-7877 l\Jovember 1991 Prepared under contract No. 2800306 by: HOR Engineering, Inc. Building B 4446 Business Park Blvd. Anchorage. Alaska 99503-711 8 TABLE OF CONTENTS Section I. Summary II. General ill. Reynolds Creek Description 1.0 Reynolds Creek Project Description 2.0 Hydrology 3.0 Project Layout 4.0 Power and Energy Generation 5.0 Cost Estimate 6.0 Development Issues and Schedule IV. Lake 1013 Project 1.0 Lake 1013 Project Description 2.0 Hydrology 3.0 Project Layout 4.0 Power and Energy Generation 5.0 Cost Estimate 6.0 Redevelopment Issues and Schedule V. Comparison of Reynolds Creek and Lake 1013 Projects VI. Conclusions and Recommendations APPENDIX Field Notes Vendor Quotation Letters Site Photos .em 1 4 4 4 5 7 10 12 12 15 15 16 17 20 22 23 25 27 LIST OF FIGURES Fipre 1 Projects General Location Map 2 Estimated Average Monthly Flows -Lake Mellen 3 Projected Flow Duration Curve -Lake Mellen 4 Reynolds Creek Project Site Plan 5 Reynolds Creek Project Plan and Profile 6 Reynolds Creek Project Diversion/Intake Plan and Sections 7 Reynolds Creek Project Powerhouse Plan 8 Reynolds Creek Project Powerhouse Section 9 Reynolds Creek Project One-line Diagram 10 Estimated Average Monthly Flows -Lake 1013 11 Projected Flow Duration Curve -Lake 1013 12 Lake 1013 Project Site Plan 13 Lake 1013 Project Plan and Profile 14 Lake 1013 Project Diversion/Intake Plan and Sections 15 Lake 1013 Project Powerhouse Plan and Sections 16 Lake 1013 Project One-line Diagram 17 Project Development Timeline -ii- LIST OF TABLES 1 Selection of the USGS Flow Gages and Diversion Site Projected Flows 2 Simulated Flow at Diversion (Lake Mellen) 3 Simulated Flows at Diversion IT (Lake 1013) 4 Power Generation Lake Mellen Site, 750 kw 5 Power Generation Lake Mellen Site, 1,500 kw 6 Detailed Cost Estimate -Reynolds Creek 7 Reynolds Creek First Year O&M Costs 8 Power Generation at Lake 1013 Site 9 Detailed Cost Estimate -Lake 1013 10 First Year O&M Costs -Lake 1013 -iii- HYDABURG HYDRO INVESTIGATION ALASKA ENERGY AUTHORI'IY CONTRACf No. 2800306 Work Order No. AEA-HDR-OIO I. S~Y INTRODUcnON The City of Hydaburg on Prince of Wales Island in southeast Alaska currently has an average load of about 150 kW and a peak load of about 370 kW. All power to this isolated system is presently generated by diesel generator sets owned and operated by Alaska Power and Telephone. This study examined two alternative hydroelectric power generating sites to assess their feasibility as possible energy sources for the City of Hydaburg. The two sites are; 1) The Reynolds Creek Project and; 2) The Lake 1013 Project. See Figure 1. REYNOLDS CREEK PROJECT This site is located about 10 miles due east of Hydaburg on the east shore of Hetta Inlet. Reynolds Creek is fed by Lake Mellen and a series of other small mountain lakes at higher elevations. The project selected for development at this site includes a rockfill dam at elevation 881 feet ms~ a 24-inch diameter buried steel penstock 2,600 feet long, and a poweraouse located at elevation 200 feet msl. The intake, penstock and powerhouse wouid be designed to accommodate two 750 kW turbine generator sets, but only one would be installed during the first phase of construction. When loads increase in the future, a second unit could be added with very little difficulty. Average annual discharge for Reynolds Creek is about 70 cfs. Since the design plant flow for 750 kW output is only 18 cfs, the proposed project would have a plant factor of 1.0 All energy produced would be firm. Peak annual generation with the single unit could -1- · .... .1.----+--:- I t J I r- .~ I I ~l !' • I o .~ ,.- ( I 0:· -, 'L -- .. ;- ") '; I ' .\ .. o fiR r-..... MAP .. <lENERAL. L.OCATION r ____ _ ~ LAKE 1013 ,-Fig.," r5 -CREEK A~ANA TlVES ~ ~AICO~A:L.~~ ____________ ___ ~ABUAG , , , t be as high as 6,000,000 kWh, but it is expected that actual output would be adjusted to follow Hydaburg's load more closely, and that actual annual output would be closer to Hydaburg's current annual use of 1,300,000 kWh. Cost for the Reynolds Creek Project is estimated to be $8,260,000. About $4,795,000 of this total is related to transmission line construction. Since the proposed project transmission line crosses navigable waterways (Hetta Inlet), we believe it will be necessary to obtain a FERC license or possibly an Exemption for the project. LAKE 1013 PROJECf The Lake 1013 Project is located about 4 miles due north of Hydaburg. The outlet of Lake 1013, an unnamed creek, flows out of Lake 1013 in a generally southwesterly direction, crosses the Craig/Hydaburg Road and empties into Natzuhini Bay north of Hydaburg. The project selected for this site would consist of a small rockfill dam that would raise Lake 1013 about 10 feet, an IS-inch diameter penstock 5,500 feet long and a small powerhouse building at elevation 300 feet msl housing one pelton type turbine- generator set rated at 600 kW full load output, 14 cfs and 650 feet gross head. The average annual flow from the Lake 1013 basin is approximately 9 cfs. Assuming 7 feet of drawdown, Lake 1013 would provide about 280 acre-feet of storage that could be used to increase the project output at times when Hydaburg's load exceeds the plant's normal run-of-the-river output Average annual generation for this project is estimated to be about 2,046,000 kWh without use of reservoir storage. Use of the entire reservoir should generate an additional 140,000 kWh per drawdown. Although Hydaburg's annual energy use is currently only about 1,300,000 kWh, there are times that the proposed project would not meet the instantaneous load demand of the City. This would occur during very cold periods in January and February as well as during low flow periods of July and August Reservoir capacity will allow peak loads to be reached until the reservoir is drained, but it is expected that a dry period in excess of one month will result in energy shortfalls at low flow times of the year. -2- The cost for the Lake 1013 Project is estimated to be approximately $4,880,000 in 1993 dollars. About $2,120,000 of this total is for transmission line construction. If a transmission line is ever built between Hydaburg and Klawock, about 3 miles of the Lake 1013 transmission line could be incorporated into the Hydaburg/Klawock line. It is believed that this project would not be under the jurisdiction of the FERC and would not require a FERC License or Exemption. Detailed descriptions of the proposed projects, drawings of proposed structures, and detailed cost and power generation estimates are contained in the text of this report. This report concludes that both projects are technically feasible and that both would provide a very high percentage of Hydaburg's current energy needs. The Lake 1013 Project would meet Hydaburg's current energy demands quite effectively but has no potential for future expansion. It would be less expensive overall than the Reynolds Creek Project but supplemental diesel generation would still be required for Hydaburg part of the time. The Reynolds Creek Project, although more expensive initially, has considerable capacity for future expansio~ allowing very cost effective staged development as loads grow over time. Its high firm energy capacity would make diesel generation necessary only during plant forced outages. It is recommended that a stream gaging program be initiated on the Lake 1013 outlet as soon as a cIedaion is made about further study of this site. Land surveys to confirm the actual eIe-air of the selected dam and powerhouse sites should also be considered. Finally, State eI. Alaska and federal agencies should be contacted to begin to scope the environmental issues that will be raised as part of these projects. -3- - - ... ... II. GENERAL HDR Engineering, Inc. (HDR) was retained by the Alaska Energy Authority to complete a reconnaissance level pre-feasibility analysis of two hydroelectric development sites to potentially serve the town of Hydaburg, located on Prince of Wales Island in southeastern Alaska. These two development sites are; 1) the Reynolds Creek Basin at Lake Mellen about 10 miles east of Hydaburg and 2) the Lake 1013 Basin located about 4 miles north of Hydaburg. Please refer to the Project Site Vicinity Map, Figure 1. This report will addresses each site separately and a comparison of the two sites is presented at the end of the report. III. REYNOLDS CREEK PROJECT 1.0 REYNOLDS CREEK PROJECT DESCRIPTION The Reynolds Creek Basin lies about 10 miles due east of Hydaburg on the east side of Hetta Inlet. Reynolds Creek itself is the outlet of Lake Mellen, a 128 acre mountain lake at elevation 873 feet msl. The Reynolds Creek Basin includes two additional lakes, Lake Marge at Elevation 1,750 feet and Lake Summit at Elevation 1,298 feet. Several reconnaissance studies assessing the suitability of the Reynolds Creek Basin for hydropower development have been made in the past. These studies were undertaken due to recognition of the high rainfall, steep terrain, and the potential for several power development sites within the basin which make it ideal for a phased development program. 1be high cost of transmission lines from the project to Hydaburg have in the past adversely affected project economics. Recent completion of a logging access road along a large portion of the transmission corridor has helped lower construction costs and prompted this analysis. A preliminary site assessment was completed in the HDR office using USGS mapping and gaging information and through a review of previous consulting engineers reports. HDR personnel visited the proposed project site via helicopter on September 26, 1991. Their field observations helped to refine the preliminary analysis with respect to specific location of principal project features. HDR staff also met briefly with City of Hydaburg and Haida Corporation staff to discuss the project to gain useful local perspectives. 2.0 HYDROLOGY 2.1 General The Reynolds Creek drainage basin contains three lakes; Lake Marge at Elevation 1,750 feet, Lake Summit at Elevation 1,298 feet, and Lake Mellen at Elevation 873 feet. The total drainage area above the diversion site is approximately 5.2 square miles. The drainage basin is generally oriented in the southwesterly direction and is mostly alpine. The surface area of Lake Mellen is reported by the Alaska Department of Fish and Game in August of 1972 to be 128 acres. 2.2 Selection Of Gages The location of USGS gages in the vicinity of the proposed project site was investigated. USGS gage #15081995 with a period of record from 1982 to 1986 water years and a drainage area of 5.2 square miles is located 0.1 miles downstream of Lake Mellen on Reynolds Creek. (Water year is defined as the calendar from October of previous year to September of current year. For example, water year 1950 includes months from October of 1949 to September of 1950.) A comparative USGS gage on Fish Creek located near K.etdJikan (USGS #15072(00) has a period of record from 1915 to 1989 water years ad a drainage area of 32 square miles. These years were unfortunately not covered by any Pies in the vicinity of the project site. The USGS gage at Old Tom Creek (USGS #15(85100) is located near Kassan with a period of record from 1949 to 1989 water years and has a drainage area of 5.9 square miles. The USGS gage at the North Branch Trocaderro near Hydaburg (USGS #15081800) is located near Hydaburg with a period of record from 1967 to 1974 water years and has a drainage area of 17 square miles. Selection of the USGS gages are summarized in Table 1. -5- - ... - OAOBNAMB DIVERSION SITIi LAKB MIiLLBN REYNOLDS CREEK NEAR HYDABURG FISH CREEK NEAR KETCHIKAN OLD TOM CREEK NEAR KASSAN NORTH BRANCH TROCADERRO NEAR HYDABURG DIVERSION SITE LAKE 1013 TABLE 1 SELECTION OF THE USGS FLOW GAGES AND DIVERSION SITE PROJECTED FLOWS GAGE GAGEl DRAINAGE AREA ELEVATION PERIOD OF RECORD SQUARE MILE FEET YEARS -5.2 881 - 15081995 5.2 860 1982-1985 15085100 32.0 20 1916-CURRENT 15085100 5.9 10 1949-CURRENT 15081800 17.0 10 1967-1974 -1.0 950 - _.----~- AVG DISCHARGE CFS 70.9 67.7 420.6 39.6 1520 8.9 ----------------.- 2.3 Analysis Daily flows for the gaging stations were obtained by using "HYDRODATA" files. "HYDRODATA" is a laser disc database program compiled by U.S.West containing data for all USGS gaging stations. Daily flows were obtained for the Reynolds Creek Gage #15081995 for the period 1982 to 1986 and the Fish Creek Gage #15072000 for the period 1916 to 1989. These daily flows were used in HDR's "FLODUR" program to obtain average monthly flows for the gage. The average monthly flows of Fish Creek Gage and Reynolds Creek Gage for the overlapping period 1983 to 1985 were correlated using a linear regression technique. The monthly correlations thus obtained were fairly realistic with a few exceptions. A similar regression analysis was carried out between the Old Tom Creek Gage #15085100 and the Reynolds Creek Gage for the overlapping period 1983 to 1985. The monthly correlations obtained were poor. The results of the linear regression analysis of the Fish Creek Gage and the Reynolds Creek Gage were, therefore, used to simulate the flows at the diversion site. No area correction was needed since the Reynolds Creek Gage and the area above the diversion site are approximately equal (5.2 square miles). The average annual discharge for the diversion site at Lake Mellen was calculated to be approximately 70.9 cfs with an average runoff of 13.63 cfs per square mile. The average monthly discharge flows varied between .S.2 cfs in July and 94.3 cfs in December. Due to variability in the correlations the average monthly hydrograph is not distributed correctly, however, the average annual flows appear to be not affected. Table 2 summarizes bodl the average monthly and the annual flows for the period 1916 to 1989 water years. FlgUI'e5 2 and 3 show the average monthly flow hydrograph and the flow duration curve respectively. '''' .. ... -- ., - .. . YEAR! AVG i OCT NOV 1916 66.6 i 81.3 ! 68.2 i 1917 i 70.1 I 89.7 64.1 : 1918 j 71.1 85.9 136.6 1919 64.5 86.1 72.3 1920 74.4 93.2 70.2 1921 71.2 90.6 65.5 1922 64.5 81.4 79.2 1923 63.0 87.1 100.1 1924 83.7 91.3 92.1 1925 63.9 84.1 89.9 1926 86.3 94.2 83.3 1927 71.9 85.2 63.4 1928 70.0 83.4 53.7 1929 72.4 88.9 67.6 1930 67.8 84.0 89.7 1931 82.9 85.3 86.2 1932 74.3 86.5 66.8 1933 69.0 88.6 80.2 1934 74.8 87.4 99.2 1935 74.5 87.4 72.8 1939 73.9 86.0 75.1 1940 73.5 83.8 98.6 1941 69.1 91.7 67.1 1942 60.1 84.4 83.2 1943 67.4 85.9 68.6 1944 71.8 90.4 89.8 1945 66.0 82.0 71.4 1946 64.3 84.6 56.4 1947 70.0 88.9 68.7 1948 74.5 82.7 63.7 1949 66.4 85.5 72.3 1950 67.4 82.8 82.5 1951 67.6 91.3 60.0 1952 70.2 90.8 62.2 1953 68.0 88.0 66.5 1954 74.8 81.9 74.4 1955 82.5 &4.9 87.3 1956 54.6 82.5 64.8 1957 67.5 87.4 n.2 1958 67.7 91.2 76.8 1959 79.4 80.5 75.8 1960 79.6 86.0 78.2 1961 73.3 78.6 75.3 1962 68.1 77.5 74.9 1963 86.1 86.9 81.4 1964 78.2 83.6 65.6 1965 63.0 81.8 72.0 1966 69.6 84.7 61.2 TABLE 2 SIMULATED FLOW AT DIVERSION LAKE MELLEN DEC JAN FEB MAR APR MAY 92.2 45.4 I 73.7 51.7 56.5 I 73.2 45.2 64.4 70.3 33.8 105.5 70.1 514 100.8 60.7 37.7 88.0 68.4 97.1 100.1 57.5 46.4 47.7 71.0 134.7 80.9 66.1 37.5 100.9 74.8 54.5 64.1 98.8 52.3 97.8 77.2 84.3 55.8 45.7 41.1 82.2 68.0 66.0 53.9 72.8 65.1 48.3 68.3 146.9 82.9 97.2 61.7 92.0 61.4 77.4 52.3 47.1 58.7 80.5 66.3 214.8 168.7 106.4 102.1 52.9 74.8 118.0 78.4 63.5 67.5 88.0 73.5 47.0 126.7 75.0 102.9 90.3 67.3 116.7 84.2 48.4 74.5 109.7 79.1 66.9 46.9 95.5 64.6 75.0 76.4 254.4 117.8 83.8 65.8 44.8 67.5 61.1 97.5 86.1 63.8 65.3 68.3 44.3 71.8 59.4 54.5 70.7 74.7 65.6 125.9 104.8 93.8 57.0 74.0 107.0 77.3 113.1 47.3 104.9 70.1 125.5 115.2 60.1 43.9 52.2 67.6 140.0 68.8 62.6 73.4 70.2 75.6 133.7 98.2 70.3 60.5 85.6 79.2 69.0 124.2 60.9 65.4 44.5 73.5 93.7 104.4 96.9 35.5 56.4 72.4 131.2 92.3 61.1 83.7 50.5 74.6 59.0 89.5 62.4 54.9 96.5 72.9 34.0 76.8 61.8 64.0 79.9 64.7 62.6 77.7 73.8 101.4 53.1 74.9 83.3 99.5 52.1 44.7 117.3 64.5 42.5 67.9 51.0 64.1 18.5 63.5 41.7 40.5 56.6 48.4 81.7 68.4 104.5 65.0 50.1 49.9 80.4 64.7 80.1 55.2 72.4 43.5 65.3 68.0 70.7 55.4 79.1 81.6 71.8 59.2 128.1 57.4 129.8 37.3 102.7 67.4 176.6 76.5 75.0 46.3 80.6 72.0 27.3 43.2 56.3 34.9 62.4 57.3 150.6 55.8 52.0 37.1 79.0 66.3 73.7 125.9 76.5 53.5 82.2 67.2 135.0 70.7 68.4 102.5 70.9 72.1 215.5 61.9 67.3 90.0 21.2 71.1 138.2 107.4 97.1 63.1 38.0 76.5 47.3 143.4 73.9 38.5 42.2 76.7 191.8 103.0 114.9 52.8 97.5 78.9 123.3 90.9 98.7 50.8 59.1 75.8 86.3 89.3 81.3 50.4 87.0 78.8 68.3 69.0 64.5 93.3 65.9 62.0 JUN JUL AUG SEPT I 100.8 I 56.7 : 45.9 54.8 ' 107.2 52.3 67.9 i 73.2 ; 90.6 43.4 I 59.3 31.7 i 72.1 40.8 39.4 I 42.6 I 83.4 39.6 . 66.4 : 44.7 ! 98.9 45.1 38.4 76.0 ! 87.1 34.4 28.1 87.0 i 55.7 24.1 36.3 80.6 84.5 51.0 38.0 107.0 76.7 57.1 38.0 38.3 35.4 35.4 38.4 26.5 82.8 47.1 35.3 60.1 60.4 41.5 38.2 53.2 60.7 44.9 68.4 22.4 109.5 41.8 25.9 412 55.4 38.8 41.7 50.5 86.8 61.8 45.5 103.9 96.8 69.0 64.8 52.5 78.4 39.3 31.9 42.9 84.5 41.0 55.1 37.7 71.5 42.0 61.1 84.8 56.4 32.0 77.5 42.0 36.2 34.2 25.5 46.2 29.9 24.1 25.9 35.0 41.7 51.4 42.6 60.7 54.0 37.0 40.9 54.5 89.6 43.8 27.8 42.3 82.8 54.6 52.4 59.7 81.4 41.5 35.2 81.7 91.8 37.4 34.0 125.1 123.7 59.5 58.9 88.8 108.5 59.0 50.8 90.3 133.8 45.0 34.4 31.9 110.5 60.6 52.1 83.6 68.1 52.1 33.0 92.6 102.4 47.2 28.9 45.6 107.6 53.6 73.2 56.1 91.5 32.6 59.4 44.5 81.9 49.1 30.3 41.8 26.9 18.9 70.5 48.2 108.4 62.8 46.1 58.0 94.0 62.9 42.4 61.9 74.4 32.5 38.7 60.8 95.4 40.9 41.3 66.2 70.9 35.5 23.4 99.5 131.0 57.4 50.9 52.3 61.6 28.1 21.8 19.5 87.1 44.3 53.8 80.9 i YEAR I AVG, OCT NOV I 1967 i 78.8 II 87.5 66.1 1968 I 729 I 84.2 64.4 I 1969 55.8 83.7 82.3 1970 85.9 93.2 106.2 1971 68.8 88.7 59.8 1972 78.6 90.3 71.0 1973 65.6 87.0 71.7 1974 60.5 86.6 49.3 1975 73.4 75.7 79.6 1976 84.3 89.1 62.9 1977 74.7 87.7 76.5 1978 57.1 85.1 66.1 1979 66.9 82.6 82.3 1980 68.6 89.9 67.4 1981 82.0 81.6 88.8 1982 61.6 91.7 82.7 1983 63.9 86.S 57.4 1984 73.2 85.7 62.4 1985 66.7 89.8 60.2 1986 69.8 90.8 55.2 1987 72.8 83.3 65.7 1988 76.8 88.0 90.1 1989 63.2 88.7 78.4 AVG 70.9 86.3 74.6 TABLE 2 SIM:ULA TED FLOW AT DIVERSION LAKE MELLEN DEC JAN FEB MAR APR MAY 77.7 75.1 79.6 46.5 122.9 62.2 48.5 97.8 80.8 104.4 66.5 73.5 33.1 42.4 44.1 32.5 46.3 73.5 158.0 71.0 103.2 68.5 74.2 66.5 21.3 67.5 75.9 45.6 71.0 70.1 54.2 55.6 53.5 103.9 101.9 64.5 35.5 81.0 70.8 56.1. 55.1 70.8 55.8 44.5 75.8 38.9 57.7 59.0 134.1 69.9 52.4 42.9 94.3 70.9 133.0 113.3 84.0 55.4 85.5 72.5 143.6 68.0 118.0 58.9 56.7 80.5 39.7 50.3 68.8 59.6 81.5 77.5 79.3 49.4 55.6 99.6 86.7 65.1 188.9 56.6 75.6 71.6 35.1 69.9 145.8 125.9 86.5 77.9 68.2 81.6 55.4 61.8 50.5 40.0 99.8 66.5 45.5 93.7 81.6 48.1 73.0 72.8 19.1 111.3 106.2 96.9 78.0 77.5 60.1 116.3 73.7 67.7 66.2 73.1 62.5 107.7 72.9 130.2 70.6 76.8 114.4 105.2 88.0 46.6 40.2 65.8 99.S 72.8 77.2 88.3 55.0 67.0 112.1 86.5 53.S 36.4 74.6 72.6 94.3 82.3 74.4 62.0 72.3 70.7 ",. .. JUN JUL I ACG SEPT 91.5 59.5 666 113.3 i 77.4 37.2 34.5 I 107.4 63.8 50.1 73.5 43.0 112.1 46.7 60.2 73.9 123.0 50.1 66.4 89.0 120.7 67.4 81.9 783 96.4 62.5 43.8 57.2 -. 121.6 61.4 41.9 36.3 J 105.4 60.2 43.5 51.6' 97.1 80.6 59.4 78.9 96.4 43.7 25.8 44.3 38.6 25.5 39.5 55.0 80.2 34.9 26.3 60.7 39.0 37.5 43.9 45.9 53.0 32.9 46.6 95.3 84.4 35.2 25.3 46.6 38.9 33.0 80.8 56.8 81.5 51.1 47.7 62.4 76.4 40.9 36.8 39.6 66.4 32.8 33.2 37.4 111.2 32.3 24.3 ! 98.7 93.5 63.3 49.6 ' 77.5 48.6 27.6 295 49.3 •• 82.2 45.2 45.3 61.7 .. . ' - Il0l· • • FIGURE 2 ESTIMATED AVERAGE MONTHLY FLOWS LAKE MELLEN 100 ~---------------------------------------------------------~ 901-------- 80 1---- 70 1---- 60 1---- 50 1---- 40 1----- 30 1----- 20 1----- 10 1----- o~- OCT NOV DEC JAN FEB MAR APR MAY JUN JUL AUG SEP MONTH FIGURE 3 PROJECTED FLOW DURATION CURVE LAKE MELLEN 200 190 180 170 160 150 140 130 120 t -\ \ \: \ '\ ..--.. (/) 110 I...&... <.) '--' 100 3 0 90 .....J I...&... I\. , '~ ~ 80 70 60 50 40 30 20 10 0 ~ r- ~ r---. --., '-------,.~ ~ ~ , i o 20 40 60 80 100 % EXCEEDANCE , , 1 , , I, . _ , • f , , 3.0 PROJECf LAYOUT The project layout was developed using the general guideline of attempting to maximize the use of locally available materials, minimize concrete use, and provide a project which is easy to operate, reliable, and can be developed at as Iowa cost as is reasonable. The project capacity was selected to meet all known current and near term planned loads of Hydaburg with a small amount of spare capacity, and to provide the capability to easily expand the plant in the future should loads increase appreciably. The selected project arrangement includes a two turbine powerhouse, with each unit rated for 750 kW full load, for a total capacity of 1,500 kW. Only one turbine would be purchased and installed at this time, but provision will be made to easily add the second unit in the future. Therefore, the estimated installed capacity of the initial project would be 750 kW. Following is a description of the major project features selected for the Reynolds Creek Project. Refer to Figure 4, Reynolds Creek Project Site Plan. 3.1 Dam and Intake The outlet of Lake Mellen (present elevation 873 feet msl) passes through an approximately 200-foot long and 4O-foot wide ravine cut into bedrock before it drops steeply down slope. This location appears to be an excellent location for a dam. It was decided to install a simple rock fill dam taldng advantage of the ample supply of large blocky boulders found in the area. An area which would form the base of the proposed dam structure would be cleaned down to a solid rock foundation. Selected boulders would then be let into place and grouted together. Figure 6 shows the plan and section of the propoMd structure. The uncontrolled spillway would be provided at elevation 881 feet msl. The dam would raise Lake Mellen about 8 feet. This is sufficient to provide for both submergence of the proposed intake pipe and some reservoir drawdown capability for the proposed project. The intake system as proposed consists of a 24-inch diameter pipe with a screened drum type manifold intake which is designed to pass 18 cubic feet per second flow with the -7- .' . "'L' COuld ",al'''.'.I.\. ~f. \ll' ,"" :f' ........ ~ J ~...,;;---~-'"-.. --- HR I REYNOlDS CREEK iMlRIElECTRIC PROJECT f ...... ~----·-------- SITE PLAN Figuru 4 . , I , .. , ! I • LAKE MELLEN EL 881.0~ ~ 900~~~~--~~~-'--'-'--'-'--~II~--.-~-r~--~.--r~--~~-=~~\~V~ 8 •• ~ -t -I l-t-~ -----, v~v '---'--------:....- 700 i --I I + -------!-------~V ______ _ ::: 'r1--T ,-r ~ , . ~v/v 4.. -+ ~_ ~ .. t __ ,_ POW RH'-l--:::"t.."..-~""" __ ---+----_---1i __ +-_+--+ __ t---+ ________ _ i I ~ I --r ---t--+-r-----t--I--' 10+00 OtOO :==~-~-=~~-_-_-:-_----1L..-;-~=::cI-_:L--_-.L~----1~---::--:-,-:~-:-::-_-iL-: -----I..i __ ...... '; --,-1~ JillIJ ~:-_---H-Y-D-A-B-U-R-~--~-E~~;LDS CREEK 40+00 3Ot{)0 20t PLAN AND PROFILE Figure 5 ----------- 2 l a ..., , . I • El. 885 /.;= 2 fUruRE ORUIA SCREENS (FOR 2ND TURBINE) ,y-,C----------42" OIA. SST. ORulA SCREENS II< IAANlfOLO INSTALl 2 SCREENS wi 1ST ruRBINE BLIND fLANGE .. ANIFOLO fOR 2 ruruRt SCREENS 36" SLUICE PIPE r , , L. J6" SLUICE GA TE CONCRETE HEADWALL ------El. 885 PLAN ,·.,0' ~---AIR-VAC VALVE ....----VALVE BOX II< INSULA TED COVER '-----24" PENS roCK --ROCK ABu TIAEN T ON FAR SlOt: Of SPII L WAY --GROUT[o ROCK DlVfRSION GAIA fOUNOLD ON ROCK STREA .. BEO ORUIA SCREEN .. ANIFOLO El. 81lLJ- <t EL 874.5 SECTION ,·.,0' l-il{ r;;;DABURG -REYNOLDS c~~~~ , ..... ...-,.; ,---- PENSTOCK SHUTOFF VALVE C~ INTAKE P~~:::ll~NS , FIOlft': 6 '·=10' I , , , , . I • f • . , f , f J , I . , , . f , i i capability to be easily doubled in capacity to 36 cfs by adding two additional drum screen assemblies. See Figure 6. The screen manifold would be pre-assembled, helicoptered or floated into position, weighted and sunk to the lake bottom. The pipeline and the sluiceway pipe would be installed prior to dam construction and would be incorporated directly into the dam. The sluiceway pipe would be used for stream diversion during construction. The resulting impoundment would be about 128 acres in size with about 5 feet of useable drawdown storage amounting to approximately 640 acre feet. This should be sufficient storage to supply Hydaburg a constant supply of 300 kW for 40 days with zero reservoir inflow. It is unlikely, therefore, that the full storage capacity of this proposed reservoir would be used under the present load scenarios experienced by Hydaburg. This arrangement would allow for considerable flexibility in the event of significant future load growth. 3.2 Penstock A 24-inch penstock exits the dam structure and is expected to follow a fairly direct route down a steep slope to the proposed powerhouse location. A shutoff valve and air/vacuum release valve are placed in insulated vaults just downstream of the dam. The pipeline will be buried for its entire length to provide better restraint and protection from the elements. Total pipeline length is 2,600 feet. See Figure 5 for pipeline layout. An access road will parallel the penstock in areas where the slope is 12 percent or less, but several high gradient switchbacks will be necessary to get the access road up to the dam site location. It is recommended that an access road be installed to the dam site to facilitate both constnlCtion and long-term operations and maintenance. Peak design flow for the penstock is 36 cis, but a full load flow of 18 cis will be all that is necessary for the 750 kW plant A 18-to 2O-inch pipe would be required for a 18 cfs design flow, so it was felt that installation of the 24-inch pipe at this time would provide the ability to double plant output in the future for a very small incremental cost -8- 3.3 Powerhouse The proposed powerhouse is a 30 feet by 46 feet insulated metal building on a concrete slab foundation located at approximate elevation 200 feet ms!. Refer to Figures 7 and 8. The exact location of the powerhouse will need to be field verified to provide a geologically solid foundation as well as having the hydraulic ability to return turbine tailrace outflows to the base of the first impassable anadromous fish barrier on Reynolds Creek. Previous studies and field observations indicated that this first fish barrier is near elevation 200, but this will have to be verified by actual surveying before design work begins. The powerhouse as proposed will house the 750 kW turbine/generator set as well as switchgear and controls. Space for installation of a future 750 kW unit will be provided and a wye connection to the penstock for the second unit will be made and blind flanged. The powerhouse location at elevation 200 feet provides a gross head of approximately 681 feet. 3.4 Switchyard and TransmissioD Output from the proposed generator will be at 4,160 volts. Switchgear and a step up transformer located outdoors next to the powerhouse in a fenced enclosure will increase line voltage to 35 kV for transmission to the new Hydaburg substation. Refer to Figure 9, the electrical one-line diagram. The overhead powerline would follow a new access road from the powerhouse along the edge of Copper Harbor north along Hetta Inlet at about elevation 100 feet ms!. 3.3 miles from the powerhouse, the transmission line would make a 1.0 mile submarine crossing of Hetta Inlet and emerge back to an overhead line at Deer Bay. The line would then follow an existing logging road 7.1 miles to Hydaburg. At Hydaburg, the line would enter a small substation where it would be transformed down to 2,400 volts, the distribution voltage for the City of Hydaburg. -9- - .. .. ... i I~ I o , in LAmo ... AREA '2' teCH O'oUlHEAD IIOWNG DOOR ---2."' ptNSIOCK -------U."' BRAHCH o I '", ~ ~ABURO -REYNOLDS'C;-;'~~~u r::WEAHOUSE PLAN V~:~-. [ ............. -. F------· Figura 7 r II "" t-r-l- f' ~ [ r I· . . • . ',. ~ -..... ... ' .:'" " . ~ ~ ,. .. ,. , ., - ':1 r" ' . .. .. .: f-. " ,'-." .... .' :1,· ,. . .' &QnON A EL. 200,~ 18' D .. " SECDON 8 , , , f , I • , , . , , , I " f' '. . . ' .. - [1 4b I- . t.,;. . .. . ~ (;r r I . '\ ;T ,-,. '. : ! . . . . .', , ' . . .. 'j PR[f ABRICA T£O RIOIG fRAME METAL 8UILDING W/INSUlATEO PANEL SIDING ..... £TAL ROOfiNG ' .. '1 : I l·' . ~ ~----.. -.. -.--.-.. --.- I j 7 I HR I HYDABURG -REYNOLDS CREEK CWERHOUSE SECTlO~S ,) ) ,j ~ -----2==:.:=.: ...... -....... :1 [~M~ 1 ~ EJ .. _-~-~.: I" : =-= '~i ~-----'::)-~~·-"-"-"(~ii-..>--j H¥f~"----_-C)-_/ 1 _____________ _ I L-----~r~~~~~~~~~~~~~~T- II '¥ ----------,~ 1 1 I 1 1::::;.~'I:r------, 1 : ..... :: 1 : <iR ~ -1 : 0~ cL .L 1 : 1 I: [Ji0-~~ :~~ ~: : 1 )7F~----' 1 I ,II-~--.-.I .. -~~.;:.J.-'T'---~--<~,J ',",\ I '. ___ 1 1 1 ~I±.l-....... 1 1 • 1 ~-i -1 1 : L--0-...J-of- 1 1 1 I 1 1 1 -I L ________________ ~~ ------------------ ...... 8 I11lUoY ... ,...,., -_ .. :-=,=.::a.u ... Wl'''''1IL4IC1IW: .. -.O."U" __ n ....... II _1....cE.u." .' .-....., ... -.A' • rma .... ., • ...... -....z ... , · ........ , ~ 0ItmI\IQ.1",.-u, :-::::r:::::a ~ 11m'" _ PIlJI .... .:u,y .r ....,._ .... 1' '" "CI.GC'I'Ml,Ay · ~~ ..... , «@!If) --~- H t 1 1 T , " o 0 1 ..... 1Wl..A"S....a fO_a .. ~rv. _ ............ (6 .... r ........... 1D1UI __ ' ........... ra. .. , ..... ~ .... -.. ----I MO..'" I ~-I_~ __ ~I-G:! REYNOLDS CREEK HYDROEl£CTRIC PROJECT p,tftc, Of .ul •• ~, ~ ALASKA I N( HGY AlIlftORllY 3.5 Communications A four-pair telephone cable would be installed parallel to the transmission line to provide plant communications. A simple SCADA system would allow staff in Hydaburg to monitor plant generation and to alert the staff of any alarms or shutdowns at the plant. Normal access to the plant would be by car to Deer Bay, by boat to Copper Harbor, and by A TV from Copper Harbor to the plant site. 4.0 POWER AND ENERGY GENERATION 4.1 Analysis The project power and average energy production for the simulated period of hydrological record (1914 to 1989) were determined using the HDR Hydropower Evaluation Program (HEP). HEP is a computer model developed by HDR for computing average and annual power generation for a high head run-of-river hydropower project. The simulated daily flow above the diversion site and project development information (such as pipe length, friction factor, diameter, diversion and powerhouse elevatio~ fish flow, turbine efficiency curve, and mechanical losses) are input into the model to obtain the energy production. A bypass release (minimum instream flow) of 5 els was assumed for environmental purposes throughout the year. This bypass release reduces the net water available for energy production. The maximum turbine flow for the first phase (750 kW) was assumed to be 18 els. The minimum turbiDe flow was assumed as 2 cfs. The gross head available was 681 feet. The friction factor (Manning's "n") of 0.012 for steel pipe was used to compute the friction loss throughout the entire length of the pipe. Minor headloss in the intake structure and pipeline due to bends and other fittings were estimated at 4 feet. A twin-jet pelton turbine efficiency curve similar to those used by Canyon Industries of Deming, Washington was assumed. Generator losses were estimated at 5 percent, transformer and -10- ... - .. ..... ... switchyard losses at 1 percent, and transmission line loss at 2 percent primarily due to its long length. The station power requirements loss including downtime for repairs and expected power outages were assumed as 5 percent. Station power requirements for lighting, heating, and ventilation were assumed negligible when compared to downtime losses. The simulated daily flow above the diversion site and the project development information were used in the HEP to determine the expected rated power capacity of the project. A rated power of 750 kW was estimated for the project with an average production of 5,955,000 kWh of electrical energy per year. Without considering any use of the storage reservoir, the plant capacity factor is 0.98. With the proposed storage capacity in Lake Mellen, all of this energy is essentially 100 percent firm. It is expected that actual plant operation would be adjusted to meet the needs of Hydaburg as closely as possible, and so for the first few years, annual output would be closer to 1,500,000 kWh. Sufficient storage and plant capacity are available so that full plant load of 750 kW should be available every day of the year. Table 4 shows the power generation output and complete energy production assumptions and tabulated energy production for all the years of simulated hydrological period of record. H and when the project is expanded to 1,500 kW rating, annual energy production should average 11,278,000 kWh with a plant capacity factor of 0.93. Table 5 shows projected energy generation for this case. 4.2 Loads A brief study of electrical demand at the City of Hydaburg was performed. From data supplied by ABA, annual load is about 1,300,000 kWh, for an average load of 150 kW. Peak demand is about 370 kW currently. A refrigeration facility in town with a load of about 140 bp might operate sometime in the future, and could be more likely to operate if a secure source of electricity were available. A visitor's center with a load of up to 10 kW is also proposed for Hydaburg, but is unlikely to be operational before 1995 according to US Forest Service sources. Allowing for 5 percent load growth per year and assuming all known possible loads are on line, the projected peak 1994 load is 545 kW. Further, -11- , TABLE 4 POWER GENERATION LAKE MELLEN, 750 Kw THE EFFECT[VE CAPAC[TY OF THE UNITS [S 750 KILOWATTS S[MULATED PRODUCTION [N MEGAWATT-HOURS YEAR OCT NOV DEC IAN FEB MAR APR MAY 1916 515.0 498.3 515.0 515.0 481.7 515.0 412.1 515.0 1917 515.0 498.3 508.9 515.0 465.1 515.0 498.3 515.0 1918 515.0 498.3 478.7 515.0 465.1 515.0 470.6 515.0 1919 515.0 498.3 515.0 515.0 465.1 515.0 328.9 515.0 1920 515.0 498.3 438.3 515.0 481.7 515.0 447.2 515.0 1921 515.0 498.3 513.7 515.0 465.1 515.0 498.3 515.0 1922 515.0 498.3 463.0 515.0 465.1 515.0 432.8 515.0 1923 515.0 498.3 501.4 515.0 465.1 515.0 343.2 513.7 1924 515.0 498.3 515.0 515.0 481.7 515.0 498.3 481.7 1925 515.0 498.3 441.1 515.0 465.1 515.0 498.3 515.0 1926 515.0 498.3 515.0 515.0 465.1 515.0 299.0 515.0 1927 515.0 498.3 505.7 515.0 465.1 515.0 470.6 515.0 1928 515.0 498.3 499.5 515.0 481.7 515.0 454.0 515.0 1929 515.0 498.3 515.0 515.0 465.1 515.0 469.4 515.0 1930 515.0 498.3 451.9 515.0 465.1 515.0 436.6 515.0 1931 515.0 498.3 515.0 515.0 465.1 515.0 305.5 515.0 1932 515.0 498.3 515.0 515.0 481.7 515.0 498.3 515.0 1933 515.0 498.3 505.0 515.0 465.1. 515.0 498.3 515.0 1934 515.0 498.3 515.0 515.0 465.1 515.0 497.1 515.0 1935 515.0 498.3 515.0 515.0 465.1 515.0 498.3 515.0 1939 515.0 498.3 515.0 515.0 465.1 515.0 379.8 515.0 1940 515.0 498.3 515.0 515.0 481.7 515.0 498.3 515.0 1941 515.0 498.3 515.0 515.0 465.1 515.0 498.3 515.0 1942 515.0 498.3 514.5 515.0 465.1 515.0 371.7 515.0 1943 515.0 498.3 508.9 515.0 465.1 515.0 398.2 515.0 1944 515.0 498.3 515.0 515.0 481.7 515.0 395.9 515.0 1945 515.0 498.3 442.5 515.0 465.1 515.0 498.3 515.0 1946 515.0 498.3 440.0 515.0 465.1 515.0 488.5 515.0 1947 515.0 498.3 510.5 515.0 465.1 515.0 341.8 515.0 1948 515.0 498.3 515.0 515.0 481.7 515.0 498.3 515.0 1949 515.0 491.3 501.3 515.0 465.1 515.0 270.1 515.0 1950 515.0 ..... 3 489.0 515.0 465.1 515.0 497.1 515.0 1951 515.0 498.3 5OS.0 515.0 465.1 515.0 457.5 515.0 1952 515.0 498.3 452.3 515.0 481.7 515.0 381.6 515.0 1953 515.0 498.3 515.0 515.0 465.1 515.0 447.6 515.0 1954 515.0 498.3 515.0 515.0 465.1 515.0 484.8 515.0 1955 515.0 498.3 515.0 515.0 465.1 515.0 403.0 515.0 1956 515.0 498.3 348.3 515.0 481.7 515.0 351.4 466.1 1957 515.0 498.3 510.0 515.0 465.1 515.0 438.6 515.0 1958 515.0 498.3 515.0 515.0 465.1. 515.0 398.2 513.7 1959 515.0 498.3 515.0 515.0 465.1 515.0 467.0 515.0 1960 515.0 498.3 515.0 515.0 481.7 515.0 182.7 515.0 1961 515.0 498.3 515.0 515.0 465.1 515.0 285.8 515.0 1962 515.0 498.3 514.0 515.0 465.1 515.0 389.8 515.0 1963 515.0 498.3 515.0 515.0 465.1 515.0 476.3 515.0 ruN ruL AUG SEP TOTAL : 498.3 515.0 515.0 498.3 5993.5 ' 498.3 515.0 515.0 490.4 I 6049.2 : 498.3 515.0 515.0 492.6 5993.5 I -498.3 515.0 515.0 476.5 5871.9 . 498.3 515.0 515.0 498.3 5952.0 498.3 515.0 515.0 498.3 6061. 9 498.3 515.0 515.0 498.3 5945.6 498.3 497.5 506.3 498.3 5867.1 498.3 515.0 515.0 498.3 6046.5 498.3 515.0 515.0 480.5 5971.5 498.3 515.0 515.0 404.2 5769.6 498.3 515.0 514.5 494.8 6022.2 498.3 515.0 514.0 400.3 5920.9 498.3 515.0 515.0 454.0 5989.8 498.3 515.0 515.0 402.1 5842.1 498.3 515.0 515.0 497.4 5869.3 498.3 515.0 515.0 498.3 6079.8 •• 498.3 515.0 515.0 498.3 6053.2 498.3 515.0 515.0 497.9 6061.4 498.3 515.0 515.0 472.2 60370 .. 498.3 515.0 515.0 498.3 5944.6 498.3 503.0 515.0 491.6 6061.1 463.9 515.0 510.7 478.3 6004.4 478.4 483.0 511.1 473.8 5855.7 • 498.3 515.0 515.0 494.6 5953.2 498.3 515.0 515.0 498.3 5977.4 498.3 515.0 515.0 463.0 5955.3 .. 498.3 515.0 515.0 456.2 5936.2 498.3 511.8 515.0 498.3 5899.0 498.3 515.0 515.0 498.3 6079.8 498.3 515.0 515.0 498.3 5821.3 498.3 515.0 515.0 492.1 6029.7 498.3 515.0 515.0 452.2 5966.2 498.3 515.0 515.0 498.3 5900.4 498.3 515.0 515.0 498.3 6012.4 498.3 515.0 515.0 476.4 6027.7 498.3 515.0 515.0 498.3 5967.8 -498.3 514.5 515.0 486.6 5705.0 498.3 515.0 515.0 465.4 5965.5 .., 378.8 428.0 515.0 498.3 5755.2 498.3 515.0 515.0 498.3 6031.8 498.3 515.0 515.0 498.3 5764.1 •• 498.3 514.0 514.0 498.3 5848.7 498.3 515.0 515.0 495.3 5950.7 .. 498.3 515.0 509.4 473.2 6010.4 .... TABLE 4 (Cont'd) POWER GENERATION LAKE MELLEN, 750 Kw THE EFFECTIVE CAPACITY OF THE UNITS IS 750 KILOWATTS SIMULATED PRODUCTION IN MEGAWATT-HOURS YEAR I OCT NOV DEC JAN FEB MAR APR MAY 1964 I 515.0 498.3 514.5 515.0 481.7 515.0 418.8 515.0 1965 515.0 498.3 463.2 515.0 465.1 515.0 428.2 515.0 1966 515.0 498.3 512.7 515.0 465.1 515.0 431.9 512.7 1967 515.0 498.3 476.5 515.0 465.1 515.0 498.3 515.0 1968 515.0 498.3 515.0 515.0 481.7 515.0 427.5 515.0 1969 515.0 498.3 436.2 515.0 465.1 515.0 345.3 515.0 1970 515.0 498.3 515.0 515.0 465.1 515.0 448.0 515.0 1971 515.0 498.3 408.6 515.0 465.1 515.0 488.5 515.0 1972 515.0 498.3 462.4 515.0 481.7 515.0 465.1 515.0 1973 515.0 498.3 482.8 515.0 465.1 515.0 416.2 515.0 1974 515.0 498.3 492.2 515.0 465.1 515.0 435.0 467.0 1975 515.0 498.3 515.0 515.0 465.1 515.0 498.3 515.0 1976 515.0 498.3 512.0 515.0 481.7 515.0 481.7 515.0 1977 515.0 498.3 515.0 515.0 465.1 515.0 398.7 515.0 1978 515.0 498.3 471.0 515.0 465.1 515.0 462.9 515.0 1979 515.0 498.3 514.5 515.0 465.1 515.0 479.5 512.7 1980 515.0 498.3 515.0 515.0 481.7 515.0 190.6 488.4 1981 515.0 498.3 515.0 515.0 465.1 515.0 465.1 515.0 1982 515.0 498.3 514.5 515.0 465.1 515.0 481.7 515.0 1983 515.0 498.3 515.0 515.0 465.1 515.0 451.5 515.0 1984 515.0 498.3 420.3 515.0 481.7 515.0 479.4 515.0 1985 515.0 498.3 478.3 ·515.0 465.1 515.0 447.2 515.0 1986 515.0 498.3 391.8 515.0 465.1 515.0 437.3 515.0 1987 515.0 498.3 515.0 515.0 465.1 515.0 337.1 515.0 1988 515.0 498.3 515.0 515.0 481.7 515.0 378.2 515.0 1989 515.0 498.3 514.0 515.0 465.1 515.0 498.3 515.0 AVG 515.0 498.3 494.0 515.0 469.3 515.0 428.8 512.6 JUN 498.3 498.3 498.3 498.3 498.3 491.7 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 498.3 495.8 NOTE: PRODUCTION IS COMPUTED FROM SYNTHESIZED DAILY FLOW RECORDS % OF THE TIME PLANT IS SHUT DOWN FOR LOW FLOWS: 1.0 THE PLANT FACTOR IS .98 JUL AUG SEP I TOT AI. I 515.0 515.0 494.1 5995.5 I 514.0 500.7 333.0 5760.8 . 515.0 515.0 498.3 5992.2 i 515.0 515.0 498.3 6024.7 . 515.0 515.0 498.3 6008.9 i 515.0 515.0 498.3 5824.7 515.0 515.0 498.3 6012.8 515.0 515.0 490.9 5939.5 515.0 515.0 488.0 5983.6 515.0 515.0 498.3 5948.9 515.0 515.0 498.3 5929.1 515.0 515.0 496.9 6061.7 515.0 515.0 498.3 6060.1 515.0 514.5 498.3 5963.0 510.0 515.0 494.1 5974.5 515.0 505.0 496.1 6029.4 515.0 515.0 498.3 . 5745.5 492.3 515.0 498.3 6007.2 515.0 515.0 472.5 6020.2 515.0 515.0 498.3 6016.4 515.0 515.0 498.3 5966.1 515.0 515.0 485.1 5962.2 515.0 515.0 468.4 58491 515.0 513.0 498.3 5900.0 515.0 515.0 498.3 5959.6 515.0 515.0 498.3 6062.2 I 512.4 514.2 484.8 59552 TABLE 5 POWER GENERATION LAKE MELLEN. 1500 Kw THE EFFECTIVE CAPACITY OF THE UNITS IS 1500 KILOWATTS SIMULATED PRODUCTION IN MEGAWATT-HOURS YEAR OCT NOV DEC JAN FEB MAR APR MAY JUN JUL 1916 1029.6 996.4 1021.0 1028.5 963.2 1025.7 760.0 1029.6 996.4 1029.1 1917 1029.6 996.4 894.6 1029.6 930.0 873.6 996.4 1029.6 996.4 995.0 1918 1029.6 996.4 756.6 1029.6 930.0 930.4 935.0 1027.3 996.4 957.6 1919 1029.6 996.4 1015.1 1029.6 930.0 835.6 637.5 1029.6 996.4 966.2 1920 1029.6 996.4 707.2 1029.6 963.2 943.1 878.8 1029.6 996.4 873.4 1921 1029.6 996.4 904.2 1029.6 930.0 930.1 996.4 1029.6 996.4 931.8 1922 1029.6 996.4 688.9 1029.6 930.0 965.1 863.9 1029.6 996.4 876.9 1923 1029.6 996.4 828.9 1029.6 930.0 1008.3 651.8 101 \.l 936.7 593.2 1924 1029.6 996.4 1029.6 1029.6 963.2 1018.1 992.4 963.2 996.4 960.9 1925 1029.6 996.4 746.2 1029.6 930.0 1009.9 985.3 1029.6 996.4 927.5 1926 1029.6 996.4 1029.6 1029.6 930.0 1029.6 570.2 1029.6 846.0 793.6 1927 1029.6 996.4 970.2 1029.6 930.0 1029.6 924.0 1029.6 996.4 971.4 1928 1029.6 996.4 760.0 1029.6 963.2 968.0 826.2 1029.6 964.2 877.5 1929 1029.6 996.4 1029.6 1029.6 930.0 1029.6 917.0 1029.6 981.4 941.2 1930 1029.6 996.4 775.9 1019.1 930.0 1012.1 824.5 1029.6 994.2 934.5 1931 1029.6 996.4 1029.6 1029.6 930.0 1021.1 5n.7 1022.2 984.0 871.9 1932 1029.6 996.4 999.2 1029.6 963.2 1026.8 970.7 1029.6 996.4 1024.0 1933 1029.6 996.4 834.5 1029.6 930.0 1013.3 996.4 1029.6 996.4 1027.4 1934 1029.6 996.4 963.7 1029.6 930.0 1029.6 965.4 1029.6 989.4 883.6 1935 1029.6 996.4 1014.9 1029.6 930.0 1016.2 996.4 1028.0 996.4 875.3 1939 1029.6 996.4 1028.5 1029.6 930.0 1016.9 717.1 1027.4 996.4 968.6 1940 1029.6 996.4 1024.3 1029.6 963.2 1024.8 996.4 1029.6 923.1 695.6 1941 1029.6 996.4 1022.0 1029.6 930.0 947.7 991.1 1029.6 609.4 851.8 1942 1029.6 996.4 954.4 1029.6 930.0 1029.6 706.3 1029.6 724.2 586.6 1943 1029.6 996.4 900.3 1029.6 930.0 908.9 755.3 1014.8 970.8 975.7 1944 1029.6 996.4 1029.6 1029.6 963.2 977.6 722.0 1029.6 996.4 957.5 1945 1029.6 996.4 743.8 1029.6 930.0 1023.5 996.4 1029.6 994.2 964.3 1946 1029.6 996.4 694.7 1029.6 930.0 1029.6 926.6 1029.6 996.4 1003.2 1947 1029.6 996.4 &46.8 1029.6 930.0 1029.1 634.0 1029.6 965.8 829.6 1948 1029.6 996.4 1016.3 1029.6 963.2 950.5 996.4 1029.6 990.5 870.0 1949 1029.6 996.4 120.8 1029.6 930.0 1025.2 422.9 1029.6 996.4 1029.6 1950 1029.6 996.4 775.5 1015.2 930.0 996.3 969.5 1028.5 996.4 1021.4 195 I 1029.6 996.4 952.3 1029.6 930.0 868.3 892.3 1029.6 996.4 983.3 1952 1029.6 996.4 758.8 1029.6 963.2 876.8 733.5 1029.6 996.4 985.7 1953 1029.6 996.4 992.3 1029.6 930.0 1028.0 837.3 1013.2 996.4 976.5 1954 1029.6 996.4 1029.6 1029.6 930.0 912.3 951.3 1028.5 996.4 1015.5 1955 1029.6 996.4 1029.6 1029.6 930.0 982.1 801.1 1024.0 996.4 1029.6 1956 1029.6 996.4 519.8 1017.5 963.2 882.7 666.8 916.3 996.4 809.6 1957 1029.6 996.4 915.8 1024.7 930.0 896.9 862.3 1017.4 996.4 970.1 1958 1029.6 996.4 930.9 1029.6 930.0 953.5 m.9 1007.1 560.9 433.4 1959 1029.6 996.4 981.7 1029.6 930.0 1029.6 919.8 1029.6 996.4 1025.1 1960 1029.6 996.4 1029.6 1029.6 963.2 942.1 364.2 1029.6 996.4 998.6 1961 1029.6 996.4 1012.5 1029.6 930.0 1023.4 S40.5 1029.6 989.5 806.4 1962 1000.8 996.4 918.9 1029.6 930.0 908.9 681.0 1029.6 996.4 936.6 1963 1029.6 996.4 1020.8 1029.6 930.0 1025.7 940.8 1029.6 989.6 821.5 AUG SEP TOTAL - 953.3 858.0 11691.0 969.1 831.6 11572.1 981.2 704.2 11274.5 855.5 699.1 11020.8 912.5 985.8 11345.7 835.9 927.2 11537.4 .. 708.5 947.4 11062.5 694.9 896.5 10607.0 815.7 996.4 11791.7 908.6 199.5 11388.1 846.9 549.7 10680.9 739.4 859.4 11511.7 779.4 685.7 10909.5 935.6 523.7 11373.5 652.6 650.0 10848.5 852.6 824.6 11169.3 883.1 996.4 11945.1 997.4 806.9 11687.7 757.8 854.9 11459.8 936.8 692.9 11542.7 .. 999.6 996.4 11736.7 953.4 779.3 11445.4 626.4 673.3 10737.0 648.7 717.4 10382.6 946.5 844.9 11302.9 939.0 996.4 11667.1 693.9 716.9 11148.3 .. 928.3 745.3 11339.4 764.1 953.6 11038.1 773.5 972.5 11618.3 937.0 914.6 11161.9 843.3 875.6 11477.9 813.5 677.1 11198.6 855.6 961.5 11216.9 779.6 954.9 11563.9 738.0 763.3 11420.6 1001.8 928.6 11779.0 913.2 803.3 10515.0 761.9 651.6 11053.1 989.5 855.2 10494.1 •• 981.4 996.4 11957.8 876.3 947.7 11203.5 731.9 918.2 11037.8 889.1 869.6 11186.8 576.0 897.6 11293.3 TABLE 5 (cont'd) POWER GENERATION LAKE MELLEN, 1500 Kw THE EFFECTIVE CAPACITY OF THE UNITS IS 1500 KILOWATTS SIMULATED PRODUCTION IN MEGAWATT-HOURS YEAR OCT NOV DEC JAN FEB MAR APR MAY JUN JUL 1964 1029.6 996.4 906.0 1029.6 963.2 1026.9 804.1 1029.6 996.4 1027.4 1965 1029.6 996.4 708.2 1029.6 930.0 986.7 825.8 1029.6 989.0 710.6 1966 1029.6 996.4 969.3 1027.5 930.0 1011.8 857.0 1009.4 996.4 994.7 1967 1029.6 996.4 822.1 1029.6 930.0 953.0 996.4 1027.9 996.4 975.9 1968 1029.6 996.4 935.3 1029.6 963.2 1029.6 812.2 1029.6 995.9 816.9 1969 1029.6 996.4 680.7 1019.1 930.0 832.8 649.2 1029.6 869.4 852.6 1970 10296 996.4 1025.7 1029.6 930.0 1025.6 879.3 1029.6 996.4 985.3 1971 1029.6 996.4 497.0 1029.6 930.0 990.8 939.0 1029.6 996.4 1020.6 1972 1029.6 996.4 687.6 1029.6 963.2 978.5 926.8 1029.1 996.4 1029.6 1973 1029.6 996.4 776.5 1029.6 930.0 1029.6 801.2 1029.6 996.4 1027.4 1974 1029.6 996.4 838.5 1019.7 930.0 920.5 829.8 898.0 996.4 1029.6 1975 1022.2 996.4 1029.6 1029.6 930.0 1017.2 996.4 1029.6 996.4 1025.2 1976 1029.6 996.4 913.2 1029.6 963.2 972.3 950.2 1029.6 996.4 1029.6 1977 1029.6 996.4 999.5 1029.6 930.0 1027.4 755.5 1029.6 974.8 878.5 1978 1029.6 996.4 726.8 1016.9 930.0 1025.1 910.9 1029.6 841.0 632.0 1979 1029.6 996.4 972.1 1029.6 930.0 1028.5 937.1 1004.8 996.4 857.4 1980 1029.6 996.4 1021.6 1029.6 963.2 1029.6 372.8 969.4 859.0 795.1 1981 1029.1 996.4 958.2 1029.6 930.0 1029.6 913.1 1029.6 893.4 693.1 1982 1029.6 996.4 916.8 1029.6 930.0 977.3 957.5 1029.6 996.4 865.7 1983 1027.9 996.4 933.6 1029.6 930.0 1020.6 869.8 1029.6 867.9 773.3 1984 1029.6 996.4 437.1 1029.6 963.2 1029.6 932.5 1029.6 994.8 979.5 1985 1029.6 996.4 790.0 1029.6 930.0 1022.5 877.6 1029.6 995.9 962.3 1986 1029.6 996.4 610.8 1029.6 930.0 1029.6 845.5 1029.6 996.4 838.2 1987 1029.6 996.4 1018.3 1029.6 930.0 1012.5 603.9 1016.1 996.4 813.7 1988 1029.6 996.4 1029.6 1029.6 963.2 1029.6 716.1 1029.6 996.4 952.5 1989 1029.6 996.4 896.4 1029.6 930.0 837.5 992.4 1029.6 953.8 700.0 AVG 1029.1 996.4 888.1 1028.5 938.4 984.2 831.3 1022.0 964.7 903.3 NOTE: PRODUCTION IS COMPUTED FROM SYNTHESIZED DAILY FLOW RECORDS % OF THE TIME PLANT IS SHUT DOWN FOR LOW FLOWS: \.0 THE PLANT FACTOR IS .93 AUG SEP i TOTAL i 986.0 832.2 11627.5 ; 528.7 394.4 10158.8 I 926.0 959.2 [1707.4 i 977.3 996.4 ! 11731.1 i 709.4 996.4 11344.2 i 963.8 89\.8 i 10745.0 868.8 910.5 [1707.0 I 910.9 825.2 11195.2 1029.6 8969 11593.5 985.1 911.2 11542.7 948.0 827.3 11263.9 897.6 809.0 11779.4 1017.2 973.7 11901.3 640.5 846.7 111383 863.9 826.5 10828.8 650.1 957.1 ! 11389.1 889.8 917.3 10873.7 848.2 892.8 11243.2 632.4 755.7 11117.2 1022.8 947.9 11449.5 938.1 919.5 11279.6 813.0 786.0 11262.5 849.4 65 \.8 10837.0 595.8 933.9 10976.3 969.4 915.7 11657.9 754.5 872.9 11022.9 847.9 844.4 [1278.4 by assuming a very high 5 percent load annual growth, the proposed project at 750 kW is still expected to meet all of Hydaburg's known needs through the year 2000. 5.0 COST ESTIMATE The cost estimate for the proposed project was prepared using past project experience, the Northwest Pipe & Casing Company Pipe Manual, average U.S. Bureau of Reclamation Cost Indexes, and cost quotations from major suppliers including Canyon Industries, Northwest Pipe & Casing, and Perelli Jacobson Contractors. At this level of study, the costs are estimated to be accurate to within plus or minus 30 percent. Costs of various project features were developed by determination of unit quantities required for each major structure and application of unit costs appropriate for the area. Vendor quotations were obtained for some equipment such as the turbine generator, switchgear, pipe, submarine crossing, intake screen assemblies, etc. Results were tabulated in the FERC format in a Lotus 123 spreadsheet that could be used directly in exhibits for a FERC Ucense Application should that project proceed to that point. Total project costs including design, licensing, construction, and start-up are $7,680,000 in January 1992 dollars. Escalation to July 1993 prices at 5 percent per year results in a total project cost in 1993 of $8,260,000. See Table 6. The operation and maintenance costs for the first year of project operation are estimated to be $184,000. Table 7 gives a breakdown of this estimate. 6.0 DEVELOPMENT ISSUES" SCHEDULE 6.1 Schedule A general development schedule for this project suggests about four months is required to perform detailed preliminary design of the project including some initial site surveying and geotechnical review. The product of this exercise would be performance plans and specifications and a project description adequate for both use in obtaining permits and -12- II' • • .. ... ' - .. TABLE 6 DETAILED COST ESTIMATE -LAKE MELLEN ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT REYNOLDS CREEK DETAILED COST ESTIMATE (January 1992 Dollars) FERC I AIC No. Description 330 Land and Land Rights 330.5 Mobilization and Logistics 331 Structures and Improvements 332 Reservoirs, Dams, and Waterways 333 Turbines, and Generators 334 Accessory Electrical Equipment 335 Misc. Mechanical Equipment 336 Roads, Railroads, and Bridges 350 Land and Land Rights (Transmission) 352 Transmission Structure and Improvements 353 Substation Equipment 355 Poles and Fixtures 356 Overhead Conductors and Devices 359 Line Clearing, Mob., and Demob. ESTIMATED COSTS SUBTOTAL Contingency Allowance (30 % ) TOT AL ESTIMATED DIRECT COST (rounded) Engineering and Administration ( •• 21. ° % ) TOTAL PROJECT COST JAN 1992 (rounded) TOTAL PROJECT COST JUL 1993 (rounded) Escalation at 5 % to July 1993 •• Covering environmental studies and licensing (8 %), design and specification (8 %), and construction management (5 %). Amount ($) 50,000 334,400 320,400 816,095 200,000 15,000 20,000 278,500 0 39,640 290,000 1,312,500 1,147,200 60,000 $4,883,700 $1,465,100 $6,349,000 $1,333,300 $7,680,000 $8,260,000 FERC Acc No 330 .01 330 .5 .51 .52 .53 .54 .55 .56 .57 .58 .59 .60 .61 331 331 .1 .11 .12 .13 .14 .15 .16 .17 .18 .19 331 .2 .21 TABLE 6 (cont'd) DET AILED COST ESTTh1A TE -LAKE MELLEN ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT REYNOLDS CREEK DET AILED COST ESTIMATE (January 1992 Dollars) Description LAND AND LAND RIGHTS Land Rights -Legal and Administrative Costs Subtotal -Acc No. 330 -Land and Land Rights MOBILIZATION AND LOGISTICS Storage and Helipads Construction Buildings Construction Power Temporary Water System Construction Surveys Rock: Crusher Heavy Lift Helicopter Regular Helicopter Barge Transportation Subsistence Crew Camp Costs Subtotal -Acc No. 330.5 -Mobilization and Logistics STRUCTURES AND IMPROVEMENTS Powerhouse (30'X 46') CleariDa (PowerboueJSwikhyard) Excavatial (uaume DO blasting) CoacnIfIJ (foclMdina reintbrciDg) Structural Steel Metal Fabricatioal Furnishings and Fixtures Pre-eng'd Metal BDildiDg HV AC and Plumbing Grounding Grid Subtotal -Powerhouse Powerhouse Site/Switchyard Fill Quantity Unit 1 L.S. 1 L.S. 1 L.S. 1 L.S. 1 L.S. 1 L.S. 1 L.S. 3 HOUR 100 HOUR 1 L.S. 200 DAYS 1 L.S. 2 ACRE 300 C.Y. 150 c.y. 10,000 LB. 1,000 LB. 1 L.S. 1,380 S.F. 1 L.S. 1 L.S. 200 C.Y. Unit Amount .. ' Price (S) i I ~ $50,000 50,000 '" 50,000 ~. '" "'" S5,000 5,000 '* $30,000 30,000 $30,000 30,000 .. S5,000 5,000 It S50,000 50,000 S10,000 10,000 .. $1,800 5,400 '" $650 65,000 $20,000 20,000 • $70 14,000 .. SI00,ooo 100,000 .' 334,400 .' .. IIJ.; S5,000 10,000 $25 7,500 .. S1.000 150,000 ... $4.00 40,000 S5.00 5,000 f- $4,000 4,000 .. $45 62,100 S1O,OOO 10,000 .. S10,000 10,000 ... 298,600 • .... S10 2,000 .. .. .... FERC Acc No .22 .23 ... .24 . 25 .26 332 332 .31 .311 .312 . 313 .314 .315 .316 .317 .318 .319 . 3110 .3111 .3112 332 .34 .341 .342 .343 .344 .345 .346 .347 TABLE 6 (cont'd) DETAILED COST ESTIMATE -LAKE MELLEN ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT REYNOLDS CREEK DETAILED COST ESTIMATE (January 1992 Dollars) Description Crushed Rock Surfacing Drainage/Containment Chain Link Fencing Gate Foundations Subtotal -Powerhouse Site/Switchyard Subtotal -Acc No. 331 -Stuctures and Improvements RESERVOIRS, DAMS, AND WATERWAYS Grouted Rock Dam Clearing Rock Placement and Grouting Drum Screens Intake Manifold 24-inch Diameter Steel Pipe 24-inch diameter Butterfly Valve V Beuum Valve 36-inch Low-Level Outlet 36-inch Sluice Gate Concrete Headwall Revegetation and Erosion Control Diversion and Care of Water SubtotIl·-GnJated Rock Dam Buried r..toct (2,600" Long) Clearing ~ wide) Trench Excavation (assume no drilling or blasting) Backfill Common Bedding 24-inch Diameter Steel Penstock Bifurcation to two 18-inch branches Concrete in Thrust Blocks Revegetation and Erosion Control Quantity I Unit 100 C.Y. 1 L.S. 80 L.F . 1 EACH 10 C.Y. 0.5 ACRE 600 C.Y . 2 EACH 4,000 LB. 3,500 LB 1 EACH 1 L.S. 50 LF 1 L.S . 1 L.S. 0.5 ACRE 1 LS 2 ACRE 7,000 CY 4,770 C.Y. 1,865 C.Y. 130,000 LB. 4,000 LB. SO C.y. 2 ACRE Unit I Amount Price I ($) $20 2,000 $5,000 5,000 $30 2,400 $400 400 $1,000 10,000 21,800 320,400 $5,000 2,500 $100 60,000 $10,000 20,000 $4.50 18,000 SO. 72 2,520 $5,000 5,000 $2,000 2,000 $50.00 2,500 $3,000 3,000 $10,000 10,000 $10,000 5,000 $20,000 20,000 130,520 $5,000 10,000 $25 175,000 $10 47,700 $2S 46,625 $2.50 325,000 $4.00 16,000 $1,000 50,000 $5,000 10,000 FERC Acc No 332 . 35 .351 .352 333 334 .01 335 .01 336 .01 .02 .03 .04 350 .01 TABLE 6 (cont'd) DETAILED COST ESTIMATE -LAKE MELLEN ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT REYNOLDS CREEK DETAILED COST ESTIMATE (January 1992 Dollars) Description Subtotal -Penstock Tailrace Excavation (assume soil only, no rock) Riprap Subtotal -Tailrace Subtotal -Acc No. 332 -Reservoir, Dams, & Waterways TURBINSS AND GENERATORS Subtotal -Ace No. 333 -Turbines and Generators ACCESSORY ELECTRICAL EQUIPMENT Battery Pack and Recharger Subtotal -Acc No. 334 -Accessory Electrical Equipment MISCELLANEOUS MECHANICAL EQUIPMENT Miscellaneous Equipment Subtotal -Acc No. 335 -Miscellaneous Mechanical Equipmen ROADS Cleariq 30' ShoreliDaa..l MotmtaiD RoId Grade ad surfice· exist. Hydaburg logging road Subtotal -Acc No. 336 -Roads LAND AND LAND RIGHTS Land Rights -Transmission Line Subtotal -Acc No. 350 -Land and Land Rights Quantity Unit 200 C.Y. 50 C.Y. 1 L.S. 1 L.S. 1 L.S. 17.0 ACRE 3.3 Mll..E 1.3 MILE 7.1 MILE 1 L.S. - ~<, Unit Amount Price ($) "'"' ~ 680,325 .... (., $20 4,000 $25 1,250 II> 5,250 .. 816,095 '" $200,000 ., .... 200,000 .. .., $15,000 15,000 III 15,000 ... .. $20,000 20,000 .' .. 20,000 ... .. $5,000 85,000 $50,000 165,000 .. $60,000 78,000 l1li $5,000 35,500 .. 278,500 ., iii $0 0 .. 0 . ' III "" FERC Ace No 352 352 . 1 .11 . 12 .13 .14 .15 353 353 .1 .11 .12 353 .2 355 355 .1 .11 .12 .13 TABLE 6 (cant'd) DETAILED COST ESTIMATE -LAKE MELLEN ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT REYNOLDS CREEK DETAILED COST ESTIMATE (January 1992 Dollars) Description STRUCTURES AND IMPROVEMENTS (TRANSMISSION FACILITY) Hydabyrg Substation Site Preparation and Grading Concrete in Equipment Pads Crushed Rock Surfacing Chain Link Fence Gate Subtotal -Hydaburg Substation Subtotal -Ace No. 352 -Struct. and Imp. (Transmission Facility) SUBST A nON EQUIPMENT AND STRUCTURES Reynolds Creek Switchyard Transformer, 4,500 kVA (4.16I3skV) Switches and Misc. Equip Subtotal -Reynolds Creek SwiCChyard HYDABURG swrrCHY ARD Transformer (34.5 kVI2.4kV) Switches, Breaken, and Misc. Equip Subtotal -Hydaburg Switchyard Subtotal -Ace No. 353 -Substation Equipment POLES AND FIXTURES Reynolds Creek Powerhouse to Hydaburg 34.5 kV, 10.3 mile Poles Guys, Anchon, and other Material Installation Powerhouse Side Marine Crossing (underwater) Hydaburg Side Quantity Unit 1 L.S . 10 C.Y. 100 C.Y. 80 L.F. 1 EACH 1 L.S. 1 L.S. I L.S. I L.S. 1 L.S. 1 L.S. 3.3 MaE 1 LS 7.1 MaE Unit Amount Price ($) $25,000 25.000 $1,000 10,000 $20 2,000 $28 2,240 $400 400 39,640 39,640 $70,000 70,000 $50,000 50,000 120,000 $70,000 70,000 $100,000 100,000 170,000 290,000 $180,500 180,500 $162,000 162,000 $50,000 $165,000 $450,000 $450,000 $50,000 $355,000 FERC Acc No 356 356 .1 .11 .12 .13 .14 359 .01 .02 TABLE 6 (cont'd) DETAILED COST ESTIMATE -LAKE MELLEN ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT REYNOLDS CREEK DETAILED COST ESTIMATE (January 1992 Dollars) Description Subtotal -Acc No. 355 -Poles and Fixtures OVERHEAD CONDUcrORS AND DEVICES Reynolds Creek Powerhouse to Hydaburg 34.5 kV, 11.4 milel Conductors Insulators Hardware and Miscellaneous Installation Subtotal -Ace No. 356 -Overhead Conductors and Deviees LINE CLEARING, MOBn.IZE, AND DEMOBn.IZE Mobilize and Demobilize Light Clearing Quantity Unit 1 L.S. 1 L.S. 1 L.S. 10.4 MILE 1 L.S. 4 ACRE Subtotal -Ace No. 359 -Line Clearing, Mob., and Demob. .... .... ... Unit Amount Price ($) ,.. "" 11.312,500 .' I "" $270,000 270,000 • $180,500 180,500 .. $135,100 135,100 II" $54,000 561,600 '" 1,147,200 1M' ... $40,000 40,000 $5,000 20,000 .. 60,000 • • .. tfJ! . .. .. TABLE 7 HYDABURG HYDRO INVESTIGATION REYNOLDS CREEK PROJECT FIRST YEAR O&M COSTS ITEM Hydro Maintenance (2 % of equipment costs) Road Maintenance Insurance Labor (One full time operator) Subsistence FERC and Other Permit Fees Fuels/Oils/Consumables Administrative Costs Total First Year Costs COST $42,000 $20,000 $45,000 $50,000 $12,000 $2,000 $5,000 $&,000 ============ $184,000 licenses for the project and for refining cost estimates for the project to plus or minus 15 percent. A go/no go decision should be made at this point to decide whether or not to proceed with project development. If the decision is made to proceed, the licensing and permitting process would begin and all required approvals to proceed with construction could be obtained within one to two years of application, with the exception of the FERC license. Some issues which could be raised during licensing include: 1) Instream flow requirements 2) Verification of impassable barrier on Reynolds Creek 3) Loss of habitat or wetlands due to the raising of Lake Mellen 4) Protection of wildlife from project impacts (eagles, bear, deer, elk) 5) Erosion and sedimentation control during construction 6) Stream diversion and construction timing 7) Social and economic impacts 8) Water quality during and after construction 6.2 Permits and UceDses Based on the information currently available, the project as proposed would not be exempt from FERC licensing requirements due in large part to the marine cable crossing (navigable waterway) on the transmission line being under federal jurisdiction. We would expect that a three stage consultation and license process could be accomplished in 24 to 48 months.. If Ipplicable, FERC Exemption from licensing could be obtained under approximately the same timeframe. Major permits that would be required include: 1) Water Rights -Alaska DNR 2) Alaska Coastal Management Program Compliance 3) 401 Oean Water Certification (DEC) 4) Authority to construct or modify a dam -Alaska DNR -13- '"' - ... .. • • 5) FERC license to construct or Exemption from licensing 6) Army Corps of Engineers -Permit to place dredge or fill in rivers 7) U.S. Coast Guard Marine Crossing Permit Once all project permits are received, final design and construction can proceed. Construction should be planned to begin in late March or early April to take full advantage of the summer construction period. Every attempt should be made to have completed access to the dam site so dam construction could proceed during July and August, the low flow months. Final design should take about 3 to 4 months to prepare plans and specifications that could be put out for construction bids. Construction could be performed in one construction season if it were carefully planned and well organized. Several issues would need to be addressed early in the development of this project in order to keep the whole development moving smoothly. These issues include: 1) Ownership of the Project. Possible Owners include: a) Private Developer; b) City of Hydaburg; c) Haida Corporation; d) Alaska Energy Authority; e) Alaska Power and Telephone; or f) Sealaska Corporation; or g) some combination of the above. Ownership will affect financing methods, operations, permitting, and bidding requirements to name a few. 2) Land Rights: Hydaburg Oty staff indicated that all project lands are believed to be currently owned by the Sealaska Corporation, but that Sealaska was in favor of the project and open to JlelOtiations. Apparently, a patented mining claim exists at the head of Copper HariJor that may have to be crossed with the access road and transmission line. Oearly, decisions about land ownership, easements, or right-of-ways need to be made, but detailed investigation of land rights issues is outside the scope of this study. Costs for land owner negotiations are included in project cost estimates. 3) Presently, Alaska Power and Telephone is authorized by the APUC to sell electricity in Hydaburg. -14- 4) Financing and Sources of Funding: The sources of funding for the projeC4 whether they be bond sales, outside financing, grants, subsidies or some combination of these, will affect the economic evaluation of the project and to some extent project schedules and overall costs. Basic agreement on the approach to financing will clarify other issues and focus the development effort. IV. LAKE 1013 PROJECf 1.0 LAKE 1013 PROJECf DESCRIPTION The Lake 1013 Basin is located about 4 miles due north of Hydaburg. The outlet of Lake 1013, an unnamed creek, flows out of Lake 1013 in a generally southwesterly direction, crosses the Hydaburg-Craig Road and empties into the Pacific. The total drainage basin is approximately one square mile. It is believed that this site has not been previously studied for hydropower development A preliminary site assessment of the 1013 Site was completed in the HDR office using USGS mapping and gaging information. HDR personnel visited the proposed project site via helicopter on September 26, 1991. Their field observations helped to refine the preliminary analysis with respect to specific location of principal project features. HDR staff also met briefly with City of Hydaburg and Haida Corporation staffs to discuss the project. During the site reconnaissance, it was noted that a sensitive barometrically corrected altimeter carried to the site indicated the Lake 1013 elevation to be 940 feet msl. The altimeter in the helicopter indicated elevation 975 msL It is possible that the USGS maps of the area are inaccurate and that the actua1lake elevation is closer to 940 feet than 1,013 feet Although both altimeters used in this case were corrected for barometric pressure that day, these instruments generally can experience considerable fluctuations over a day. Both altimeters were set at the same time at equal levels before take-off. Until actual physical site surveys are done, the actual lake elevation will not be accurately -15- ... .... .. - .. known. In order to maintain a conservative approach, it was decided to use 940 feet as the lake elevation for this study. It was also observed during the site reconnaissance that an excellent dam site exists on the outlet to Lake 1013 about 200 feet downstream of the lake outlet. The outlet stream drops into a narrow, shallow canyon that could serve as abutments to a small rockfill dam. This is discussed in more detail later in the report. 2.0 HYDROLOGY 2.1 Selection or Gages Location of USGS gages in the vicinity of the proposed project sites were investigated. A USGS gage (#15081995) with a period of record from 1982 to 1986 and a drainage area of 5.2 square miles is located 0.1 miles downstream of Lake Mellen on Reynolds Creek. USGS gage on Fish Creek near Ketchikan (USGS #15072(00) is located near Ketchikan with a period of record from 1915 to 1989 and a drainage area of 32 square miles. The Fish Creek Gage has missing a period of record between 1937 to 1938. These years were unfortunately not covered by any other gages in the vicinity of the project site. The USGS gage on Old Tom Creek (USGS #150851(0) is located near Kassan with a period of record from 1949 to 1989 and with a drainage area of 5.9 square miles. The USGS gage on the North Branch Trocaderro near Hydaburg (USGS #150818(0) is located near Hydaburg with a period of record from 1967 to 1974 and has a drainage area of 17 square miles. Selection of the USGS gages are summarized in Table 1. 2.2 No USGS gage exists on the unnamed creek downstream of Lake 1013. North Branch Trocaderro Gage #15081800 with a period of record from 1967 to 1974 is the nearest gaging station to Lake 1013. To ensure similar hydrological characteristics between the North Branch Trocaderro and the project site at Lake 1013, mean annual precipitation -16- GAOBNAMB PIVP$lQ" .1T8 ••••...... ~~~ ........ REYNOLDS CREEK NBAR HYDABURG PISH CREEK NEAR KETCHIKAN , OLD TOM CREBIC. NBARKASSAN NORTH BRANCH TROCADERRO NEAR HYDABURG DIVSllSION slTa LAKE lO13 'If , , TABLE 1 SELECTION OF THE USGS FLOW GAGES AND DIVERSION SITE PROJECTED FLOWS GAGE GAGEl DRAINAGE AREA ELEVATION PERIOD OF RECORD SQUARE MILE FEET YEARS ... S.2 881 ~ 15081995 5.2 860 1982-1985 15085100 32.0 20 1916-CURRENT 15085100 5.9 10 1949-<URRENT 15081800 17.0 10 1967-1914 ~ 1.0 950 - AVG DISCHARGE CFS 70.9 61.1 420.6 39.6 152.0 8.9 for both sites was examined using the Water Resources Atlas for Alaska prepared by the U.S. Department of Agriculture. The mean annual precipitation for both the sites was approximately equal to 120 inches. Therefore, the North Branch Trocaderro Gage is suitable to be used to simulate flows at the proposed diversion site. The average monthly flows for the period 1968 to 1974 for the North Branch Trocaderro Gage was correlated with the Fish Creek Gage #15072000 for the overlapping period 1968 to 1974 using a linear regression technique. The monthly correlations obtained were fair. Similar analysis was carried out for the Old Tom Creek and the North Bay Trocaderro Gages for the same period 1968 to 1974. The correlations obtained were poor. The results obtained from the linear regression analysis for the Fish Creek Gage and the North Branch Trocaderro Gage and an area ratio multiplier (North Branch Trocaderro Gage/Lake 1013 drainage area) were used to obtain simulated daily flows at the diversion site for Lake 1013. Using the daily flows in the "FLODUR" program average annual and monthly flows were generated. The average annual discharge for the diversion site at Lake 1013 was calculated to be approximately 8.9 cfs with an average runoff of 8.65 cfs per square mile. The mean monthly flow varied between 4 cfs in July to 16.9 cfs in October. Table 3 summarizes the average monthly and annual flows. Figures 10 and 11 show the average monthly flow hydrograph and the flow duration curve, respectively. 3.0 PROJECT lAYOUT The project layout was developed using the general guideline of attempting to maximize the use of IocaDy available materials, minimizing concrete use, and to provide a project which is easy to operate, is reliable, and can be developed at as low a cost as is reasonable. The project capacity was selected to maximize to the extent possible the use of the available water in the Lake 1013 Basin. The selected project arrangement includes a single turbine powerhouse with the unit rated for 600 kW full load. See Figure 12, the -17- YEAR AVG: OCT: NOV 1916 8.6 : 202 : 11.0 1917 7.5 14.6 I 8.7 1918 11. 1 172 49.0 1919 9.0 17.1 13.3 1920 7.4 12.1 12.0 1921 7.5 14.2 9.5 1922 8.3 20.1 17.3 1923 10.1 16.4 28.6 1924 10.7 13.5 24.3 1925 8.6 18.3 23.0 1926 11.0 11.3 19.4 1927 7.9 17.7 8.4 1928 8.5 18.8 3.1 1929 7.0 15.2 10.6 1930 8.8 18.5 23.0 1931 11.2 17.5 21.1 1932 9.7 16.7 10.2 1933 8.6 15.4 17.7 1934 10.8 16.1 28.3 1935 8.5 16.3 13.7 1939 9.9 17.0 14.7 1940 9.6 18.6 27.9 1941 7.2 13.3 10.3 1942 9.0 18.1 19.4 1943 9.0 17.1 11.3 1944 9.3 14.2 23.1 1945 7.9 20.0 12.7 1946 7.9 18.0 4.5 1947 9.1 15.1 11.2 1948 8.5 19.3 8.5 1949 10.3 17.4 13.2 1950 8.8 19.3 19.0 1951 7.2 13.5 6.4 1952 8.7 13.8 7.7 1953 8.8 15.8 10.1 1954 9.1 19.9 14.6 1955 10.3 18.0 21.6 1956 7.8 19.5 9.2 1957 8.0 16.1 16.0 1958 9.2 13.7 15.7 1959 9.8 20.7 15.2 1960 10.6 17.2 16.5 1961 10.7 22.1 14.9 1962 10.0 22.8 14.7 1963 9.7 16.5 18.3 1964 9.5 18.5 9.5 1965 7.5 19.9 13.1 1966 9.0 18.0 7.1 TABLE 3 SIMULATED FLOW AT DIVERSION LAKE 1013 DEC JAN FEB MAR APR MAY 9.5 1.9 8.0 5.9 13.7 7.2 6.6 5.3 7.4 4.0 4.8 8.8 7.0 12.3 5.5 4.5 7.5 9.7 9.7 1\.8 5.1 5.1 19.9 8.3 12.0 8.4 6.4 4.4 5.7 6.3 7.2 5.2 12.6 6.0 5.8 5.2 8.8 3.9 2.7 4.8 8.6 9.9 7.8 3.4 7.8 7.2 22.0 9.6 12.6 8.8 12.6 6.9 6.7 13.6 8.6 3.2 2.7 6.5 8.5 10.8 16.5 24.8 14.5 11.4 16.3 6.4 10.9 7.9 5.9 7.5 7.3 7.0 6.6 16.9 8.2 11.5 7.1 10.3 10.9 9.0 2.9 8.2 4.1 4.1 7.9 2.2 12.4 7.3 9.4 5.5 18.9 15.3 9.9 7.5 15.9 10.2 7.5 11.6 10.5 7.1 11.0 9.7 6.5 6.9 5.1 6.1 10.1 6.5 7.8 16.8 14.1 10.3 12.4 6.6 10.3 7.7 15.8 5.4 4.9 8.8 11.3 14.8 5.5 5.0 14.2 10.1 12.2 6.2 5.8 8.3 10.4 6.0 11.8 11.6 7.4 6.7 7.7 4.0 8.0 16.5 5.5 7.2 15.5 7.0 9.6 12.7 12.6 4.2 12.8 7.7 11.6 10.5 5.6 9.2 13.7 6.4 7.5 10.0 5.7 6.2 5.9 7.3 6.0 7.7 5.6 7.1 8.6 11.6 7.7 7.9 8.1 11.3 17.5 6.3 8.9 12.0 3.7 5.0 2.9 11.7 6.4 6.0 3.6 7.2 23.9 12.2 6.4 1.0 4.6 5.5 8.4 9.7 10.1 5.4 3.4 5.5 8.7 11.6 8.6 3.6 7.7 5.1 17.0 10.0 8.1 3.7 9.1 9.1 10.0 14.5 11.7 3.8 19.0 4.4 5.3 10.4 14.4 7.6 8.3 5.3 12.0 7.8 5.5 1.5 4.6 4.1 12.5 16.0 12.8 3.7 3.8 4.3 9.5 10.8 8.3 16.9 8.6 6.1 15.0 10.4 12.0 6.5 7.0 11.3 10.1 7.7 16.6 4.8 6.8 10.2 20.3 8.4 12.2 13.4 12.7 7.0 21.5 5.4 6.7 20.0 8.0 4.4 15.0 5.2 15.3 12.6 16.1 5.9 5.9 4.2 11.1 10.3 13.0 5.7 12.2 5.8 9.0 10.0 9.5 5.7 7.9 4.2 7.9 6.2 6.1 10.3 13.0 13.1 JUN HlL AUG I SEP ..,. 6.5 5.6 4.5 ! 9.0 : 7.1 4.6 671 IIA 5.7 3.0 5.9 6.0 : 4.3 2.6 3.9 7.3 5.4 2.5 6.5 7.7 : 6.3 3.4 3.9 11.7 ! 5.5 1.4 2.8 132 . 3.0 0.1 3.6 12.3 I 5.3 4.5 3.9 I 15.8 I 4.6 5.6 3.8 68 I 1.6 1.4 3.8 5.3 i 5.2 3.9 3.5 9.7 3.5 2.7 3.8 8.8 I 3.5 3.4 6.9 4.7 .. 7.3 2.8 2.5 7.3 3.0 2.3 4.1 8.5 5.4 6.3 4.5 15.3 6.2 7.8 6.4 8.7 4.9 2.3 3.2 7.4 5.3 2.7 5.5 6.7 4.3 2.9 6.1 12.9 3.0 1.5 7.7 7.2 1.6 1.3 2.4 7.7 1.0 0.4 2.4 6.4 .. 2.2 4.5 4.3 9.5 3.0 2.0 3.9 8.9 5.7 3.1 2.7 7.4. 5.2 5.1 5.2 9.6 5.1 3.1 3.5 12.5 ... ' 5.9 2.1 3.3 18.1 8.3 6.1 5.9 13.4 7.2 5.9 5.0 13.7 9.1 3.4 3.5 6.0 7.2 6.3 5.2 12.8 4.1 4.6 3.2 13.9 6.8 3.8 2.8 7.7 7.1 5.0 7.2 9.2 5.9 1.2 5.9 7.6 5.0 4.1 3.0 7.2 Iiiit·· 1.0 0.0 7.0 8.1 7.3 6.5 4.6 9.0 6.0 6.7 4.3 9.8 4.6 1.1 3.7 9.7 6.2 2.6 4.2 10.5 4.2 1.5 2.2 14.8 9.0 5.5 5.1 8.6 3.5 0.5 2.0 4.4 5.5 3.2 5.4 12.3 .. *'": YEAR : AVG I OCT I NOV i 1967 1 8.8 i 16. 1 ~ 9.9 1968 I 9.3 18.2 : 8.9 1969 I 8.1 i 18.5 18.9 1 1970 1\,2 12.1 32.1 i 1971 i 8.1 15.2 6.4 1972 8.9 14.2 12.5 1973 8.8 16.4 12.9 1974 7.7 16.7 0.8 1975 9.2 24.1 17.3 1976 9.6 15.1 8.0 1977 9.1 15.9 15.7 1978 6.6 17.7 9.8 1979 8.6 19.4 18.8 1980 9.0 14.5 10.5 1981 10.7 20.0 22.5 1982 7.1 13.2 18.9 1983 7.6 16.6 4.9 1984 8.9 17.3 7.9 1985 8.1 14.5 6.5 1986 7.7 13.8 4.0 1987 10.3 18.9 9.7 1988 10.7 15.9 23.1 1989 7.6 15.3 16.7 Ava 8.9 16.9 14.6 TABLE 3 SIM:ULA TED FLOW AT DIVERSION LAKE 1013 DEC JAN FEB MAR APR MAY 8.5 7.3 9.1 5.3 1.8 12.9 6.8 I\.6 9.3 11.5 11.8 7.0 6.0 \.4 2.0 3.8 16.5 7.0 13.3 6.5 13.8 7.7 9.9 10.7 5.2 6.0 8.4 5.2 10.1 8.9 7.1 3.7 4.0 I\.6 5.3 11.7 6.0 8.5 7.4 6.3 13.0 8.4 72 1.7 8.5 4.5 12.8 14.6 12.0 6.4 3.9 4.9 6.4 8.4 11.8 14.4 10.0 6.2 7.9 7.5 12.5 6.0 16.8 6.7 13.5 3.4 6.4 2.9 7.0 6.6 8.5 5.0 8.6 2.5 4.5 10.9 7.6 I\,4 15.1 3.8 8.4 8.0 22.3 8.9 12.6 16.8 10.5 8.7 10.6 2.8 7.2 4.8 3.4 4.5 5.6 10.7 6.5 10.9 9.5 5.5 10.0 7.3 5.1 14.2 14.3 10.5 8.9 4.9 7.6 15.1 8.0 7.6 12.4 7.2 7.6 13.4 7.9 14.3 10.8 5.3 10.7 13.0 10.9 5.2 19.3 10.9 9.8 7.0 8.7 9.8 14.2 10.3 10.6 9.4 4.2 4.2 9.5 7.5 9.5 8.7 8.1 7.0 ILl 8.5 JUN, JUL' AUG. SEP 5.9 6.0 1 6.6 I 16.":' ~ 4.8 I 2.1 I 3.3 15.8 I 3.7 4.5 I 7.3 i 7.4, 7.4 3.6 1 6.1 i 11.~ : 8.3 4.2 6.7 i 13.3 i 8.2 7.6 8.3 121 : 6.2 6.7 4.3 95 I 8.2 6.4 4.1 I 6.61 7.0 6.1 4.4 8.6 I 6.2 10.0 5.9 12.2 I 6.3 3.1 2.5 7.6 I 1.8 0.3 3.9 9.0 I 5.1 1.5 2.5 9.7 1.8 2.1 4.4 7.8 3.0 1.7 4.6 14.3 5.4 1.6 2.4 7.8 \.8 1.1 8.0 9.2 5.0 4.5 4.8 9.9 4.7 2.6 3.7 7.0 3.9 1.2 3.3 6.8 7.4 1.0 2.3 147 6.0 6.7 4.9 11.9 2.5 0.3 3.0 8.2 5.1 3.5 4.5 9.9 , 1 I FIGURE 10 ESTIMATED AVERAGE MONTHLY FLOWS LAKE 1013 18 ~-----------------------------------------------------------~ 17 1--- 16 1--- 15 1---- 14 1---- 13 1---- 12 1---- 11 10 1---- 9 1---- 8 1---- 7 1---- 6 1---- 5 1---- 4 1---- 3 1---- 2 1---- 1 o L--__ OCT NOV DEC JAN FEB MAR APR MAY JUN JUL AUG SEP MONTH , ,; , ( j I. i 1 t j I , j FIGURE 11 PROJECTED FLOW DURATION CURVE LAKE 1013 30 1 28 26 24 22 20 \ \ \ \ "\ 18 "...... (J) L.... 16 0 ........, 3: 14 0 --1 L.... 12 10 8 6 4 2 0 1\ \ , '" '~ "'" ~ ~ ~ I--- ~ r---------- ~ ~ ~ o 20 40 60 80 100 % EXCEEDANCE ...---:::----::-----,,' ~~~------------------------,~ ... l"i l{ I:~KE 1013 HYDROELECTRIC PROJECT .--, ..... --------: I SITE PLAN I Flgur.12 •• site plan. Following is a description of the major project features selected for the Lake 1013 Project: 3.1 Dam and Intake The outlet of Lake 1013 (present elevation assumed to be 940 feet msl) flows about 200 feet through gently sloping open forest land until it drops into a narrow rock canyon from 10 to 15 feet deep. This small canyon with rock abutments appears to be an excellent location for a dam. It was decided to install a simple rock fill dam taking advantage of the ample supply of large blocky boulders found in the area. An area which would form the base of the proposed dam structure would be cleaned down to a solid rock foundation. Selected boulders would then be set into place and grouted together. Figure 14 shows the plan and section of the proposed structure. The uncontrolled spillway would be provided at elevation 950 feet IDSl. The dam would raise Lake 1013 about 10 feet. This is sufficient to provide for both submergence of the proposed intake pipe and some reservoir drawdown capability for the proposed project. The Lake 1013 Basin is very shallow and it was felt from the field reconnaissance that raising Lake 1013 by more than 10 feet could result in the lake overflowing its basin into the adjacent drainage. The intake system as proposed consists of a 1S-inch diameter pipe with a screened drum type manifold intake which is designed to pass 14 cubic feet per second flow. See Figure 14. The screen manifold would be pre-assembled, helicoptered or floated into position, weighted and sunk to the lake bottom. The pipeline and the sluiceway pipe would be installed prior to dam. construction and would be incorporated directly into the dam. The sluiceway pipe would be used for stream diversion during construction. The resulting impoundment would be about 40 acres in size with about 7 feet of useable drawdown storage amounting to approximately 280 acre-feet. This should be sufficient storage to supply Hydaburg a constant supply of 300 kW for 20 days with zero reservoir inflow. It is likely that the full storage capacity of this proposed reservoir would be used under the present load scenarios experienced by Hydaburg during the low flow months of the year. A complete drawdown power study was not performed as part of the scope of this study, -18- ~----------------------~~-~--.~~ .-~~~~--~-. ~ >-• ~o_ o j~ '" it . .,,~ o , • r El. 954 36-SLUICE PIPE CONCRETE HEADWALL ~----EL 954 PLAN N_T.S. ...__----AIR-VAC VALVE ____ ---VAlVE BOX" INSULA TEO COVER "-----IS-PENSTOCK PENSTOCK SHUTOff VALVE N.T.S. \ 1 r , , , , , " f , f 36-oiA. SST. DRUM SCREENS " MANIFOlD ROCK ABUTU[NT ON fAR SIDE or SPILLWAY GROUTED ROCK DIllfRSION !lAM ,OUNOtl) ON ROCK STR[AMB[D DRUM SCRHN MANlf 01 D .---.4~::---.--::~ ____ ---",EL",.-,9=5=OT~· ____ ~~_ SECllON N.T.S. -, ........... --r'-·· -.-.--~ ~;DABURC3 -LAKE_l~~~ __ n_ CASION I INTAKE PLAN + SECTIONS I FIGl.ft 14 , • r , " -i 1 ~ but should be performed as part of detailed a feasibility study. More complete streamflow data will be necessary to perform such a study. 3.2 Penstock An 18-inch penstock exits the dam structure and is expected to follow a fairly direct route down a moderate slope to the proposed powerhouse location. A shutoff valve and air jvacuum release valve are placed in insulated vaults just downstream of the dam. The pipeline will be buried for its entire length to provide better restraint and protection from the elements. Total pipeline length is 5,500 feet. See Figure 13 for pipeline layout. An access road will parallel the penstock all the way up to the dam. The slope will be 12 percent or less in most areas, but several somewhat steeper sections will likely be necessary to get the access road up to the dam site location. It is recommended that an access road be installed all the way to the dam site to facilitate both construction and long term operations and maintenance. Peak design flow for the penstock is 14 cis. 3.3 Powerhouse The proposed powerhouse is a 20 foot by 26 foot insulated metal building on a concrete slab foundation located at approximate elevation 300 feet ms!. Refer to Figure 15. The exact location of the powerhouse will need to be field verified to provide a geologically solid foundation as well as the having the hydraulic ability to return turbine tailrace outflows to the base of the first impassable anadromous fish barrier on the Lake 1013 outlet creek. Field observations from the helicopter indicated that this first fish barrier is near elefttian 300, but this will have to be verified by on ground surveying and agency agreement before beginning final design work. The proposed powerhouse will contain the 600 kW turbine/generator set as well as switchgear and controls. The powerhouse location at elevation 300 provides a gross head of 650 feel -19- If 1 10001-____ _ 900~------~----- .OO~------_+-------- 700 6001--______ -+ ______ . __ _ -~. -, ---/" -,~ I; :, ' 1\ / 500 ____ __ -----JIII-r------+-------+-----I-------t----__ +-___ -1-_____ ~ __ --1____ _ _ ____ ----./ 30+00 20+00 10+00 400 POW£ft HOUSE ~ 30 0 1-------~=__::_=_:-=-=-=-=-_i,:,:::,:::;:=---..;u1l!::...----11------------- 200~ ______________ ~ ______________ ~ ______ ~~ ________ ~ ____ ~ 60+00 50+00 40+00 . i _. -------- 0+00 Figure IJ ... ! A L I. 10·W. x 10·H. ROlL-UP INSUlA lED WET Al DOOR 11'· lsa.AnON VAllot: 15'-0· 26' O· ~I WAIN DOOR A J fiR SECllON M N.T.S. -INSUUt1ID .. fT AL BUILDING ~ 1013 HYDROB..ECTlIC PAO.JECT r~~~ ~~ II .... L-_________________ ~ _________________________________________________________________________________________________________ ~ __ .:FI~o:ur:9~1:5 ____ _ 3.4 Switchyard and Transmission Output from the proposed generator will be at 4,160 volts. Switchgear and a step up transformer located outdoors next to the powerhouse in a fenced enclosure will increase line voltage to 35 kV for transmission to the new Hydaburg substation. Refer to Figure 16, the one-line diagram. The overhead powerline would follow a new access road from the powerhouse down to the Craig-Hydaburg Road and then south to Hydaburg for a total length of 3.7 miles. At Hydaburg, the line would enter a small substation where it would be transformed down to 2,400 volts, the distribution voltage for the City of Hydaburg. 3.5 Communications A four-pair telephone cable would be installed parallel to the transmission line to provide plant communications. A simple SCADA system would allow staff in Hydaburg to monitor plant generation and to alert the staff of any alarms or shutdowns at the plant. Normal access to the plant would be by car or all terrain vehicle in winter. 4.0 POWER AND ENERGY GENERATION 4.1 ~aJysis The pro jed power and average energy production for the simulated period of hydrological record (1916 to 1989) were determined using the Hydropower Evaluation Program (HEP). HEP is a oomputer model for oomputing average and annual power generation for a high head run-of-river hydropower project, developed by HDR. The simulated daily flow above the diversion site and project development information (such as pipe length, friction factor, diameter, diversion and powerhouse elevation, fish flow, turbine efficiency curve, and mechanical losses ) are input into the model to obtain the energy production. -20- ... - ... - wi/! .. , 1 BIIlAT_ ...... ' · -... :-:-=':QWIDPI _ _,,., -..eft( .. __ m _ .. n ...... .. II ...... IIILAl" ., .-....,,....ur.T to ... ...,,. LEGEND • ...... -..u..z ...... ., · -....~, ~ ....... , .. ~, .. ~'RIII'''''''M.I.'''''''T • _''''IIALMCI:IIUI.'f _ ........... " ., ................ , II ,.a.DI:t ...... " SI _~"'-II"""T NOTES /' , o 0 I ntI ..... ,.~ IIIO_ ...... .-n. .... ,...... t:II ... fOr. ~ NlIClUI MIl .... , ... aA..#r.RIl W<E lOll HYDROELECTRIC PROJECT ~lncw 01 Wo ... III'ond •...... Q "I "oK" f N[RCY "U1HORIIY Clij:~~ lil{, .... _.... f IGURf 16 A bypass release (minimum instream flow) of 1 cfs was assumed for environmental purposes throughout the year. This bypass release reduces the net water available for energy production. The maximum turbine flow was taken as 14 cfs for full load conditions. The minimum turbine flow was assumed as 2 cfs. The gross head available was 650 feet. The friction factor (Manning's "n") of 0.012 for steel pipe was used to compute the friction loss throughout the entire length of the pipe. Minor headloss in the intake structure and pipeline due to bends and other fittings were estimated at 4 feet. A standard twin-jet pelton turbine efficiency curve was assumed. Generator losses were estimated at 5 percent, transformer and switchyard losses at 1.0 percent, and transmission line loss at 1.0 percent. Transmission losses will be less than the Reynolds Creek Project due to a much shorter transmission line. The station power requirements loss including downtime for repairs and expected power outages were assumed as 5 percent. Station power requirements for lighting, heating, and ventilation were assumed negligible when compared to downtime losses. The simulated daily flow above the diversion site and the project development information were used in the HEP to determine the expected rated power capacity of the project. Table 8 summarizes the results. A rated power of 600 kW was estimated for the project with an average production of 2,046,000 kWh of electrical energy per year. Assuming no contribution from the storage reservoir, the plant factor obtained was 0.47. If the plant was operated at Hydaburg's current peak load of 340 kW all year, the resulting plat factor, again ignoring storage, would be 0.60. At Hydaburg's average load of 150 kW, plat factor would be 0.76. Including the effects of the storage reservoir into this analysis will further increase capacity factor and firm energy. It was beyond the scope of this study to construct a reservoir drawdown model for this project, especially in light of the limited actual hydrology information available. However, it is clear, for example, that the reservoir capacity with no inflow could generate 200 kW continuously for 28 days, so the reservoir will greatly improve the load following ability of this project. The plant would be expected to be in operation throughout the year except during maintenance. -21- w, ... ' ... .. ... - I TABLE 8 POWER GENERATION LAKE 1013 THE EFFECTIVE CAPACITY OF THE UNITS IS 532 KILOWATTS SIMULATED PRODUCTION IN MEGAWATT-HOURS YEAR OCT NOV DEC IAN FEB MAR APR MAY IUN IUL 1916 363.0 233.7 235.5 9.3 141.3 128.7 260.2 167.3 144.6 108.2 1917 331.0 197.9 153.4 105.8 138.3 62.3 93.4 209.7 155.4 86.1 1918 364.4 353.7 150.6 207.7 103.2 79.6 155.6 206.8 118.1 43.5 1919 354.0 257.5 223.0 161.2 92.2 75.0 280.3 190.0 72.2 29.3 1920 310.1 154.9 217.6 184.1 128.4 75.8 92.8 132.8 107.8 38.8 1921 345.8 105.2 169.9 101.8 287.1 114.0 123.8 106.5 135.2 61.9 1922 365.5 276.7 194.0 62.3 20.1 91.5 160.2 228.3 Ill. 7 2.1 1923 334.2 333.7 179.2 45.3 118.2 165.1 274.7 202.4 40.5 0.0 1924 334.2 311.3 281.3 174.5 261.2 160.3 145.1 271.1 98.8 87.0 1925 364.8 213.9 199.5 38.2 21.1 147.7 196.7 260.8 81.4 115.9 1926 272.9 303.1 314.7 336.4 182.1 264.8 241.2 130.1 5.3 27.6 1927 344.1 133.9 256.4 128.6 115.0 183.5 147.7 161.6 101.8 62.3 1928 358.4 56.6 148.8 221.7 147.3 186.1 117.6 237.2 50.0 48.2 1929 351.7 201.9 247.3 150.4 26.9 201.6 66.0 67.9 49.3 60.8 1930 350.4 298.3 188.8 24.6 210.0 160.3 186.8 116.0 124.2 40.9 1931 334.7 292.3 363.2 299.8 215.9 173.0 275.3 232.7 30.7 31.3 1932 346.5 182.2 183.2 205.9 114.0 168.6 262.4 241.1 109.8 130.8 1933 349.9 312.1 151.2 143.4 92.7 134.2 244.5 150.2 131.9 186.8 1934 352.2 289.8 189.2 227.7 261.6 261.7 306.5 148.5 87.1 34.4 1935 346.2 253.2 249.5 69.8 253.1 113.8 121.2 191.6 106.5 44.5 1939 369.2 267.8 267.6 275.6 100.7 99.8 268.1 214.0 70.7 28.6 1940 360.6 349.0 268.9 106.2 117.0 199.7 260.3 117.5 41.9 29.3 1941 329.1 215.3 234.9 220.1 140.2 148.7 170.3 71.1 25.2 9.2 1942 364.6 310.2 193.9 217.1 106.3 175.0 304.5 164.7 1.1 2.1 1943 356.6 139.9 203.8 149.1 175.3 70.9 257.4 132.5 5.3 79.6 1944 330.7 321.3 287.7 225.7 105.0 213.2 279.2 133.5 31.7 0.0 1945 369.2 225.5 178.9 201.4 111.1 140.4 126.4 175.7 103.9 43.9 1946 355.5 92.3 133.1 176.8 108.6 170.3 195.3 285.1 99.9 104.0 1947 341.7 193.6 181.9 166.7 171.1 225.8 246.9 143.3 95.1 64.0 1948 358.5 196.8 224.1 261.3 51.0 96.9 64.0 253.4 121.1 24.9 1949 34'.3 268.0 146.0 124.5 46.6 165.6 354.5 295.3 198.8 126.4 1950 364.9 317.0 145.6 0.0 78.8 113.6 190.2 213.5 165.2 118.8 1951 315.1 93.2 247.8 112.4 39.9 112.0 181.6 272.4 172.0 53.8 1952 319.7 146.1 176.3 41.1 159.2 98.7 218.6 235.7 161.3 137.2 1953 339.5 186.1 193.9 61.9 206.2 196.6 204.9 301.2 67.8 90.0 1954 366.8 300.1 273.6 73.7 187.5 76.7 107.6 243.6 152.0 59.3 1955 338.7 331.5 289.2 157.0 179.2 108.8 159.2 158.6 163.0 98.7 1956 364.4 90.1 117.7 6.3 78.1 67.9 209.5 248.1 118.8 8.2 1957 353.0 269.5 251.1 63.9 53.3 73.8 176.5 240.1 95.4 67.9 1958 309.3 209.8 204.8 280.9 129.5 131.5 143.0 218.3 5.3 0.0 AUG SEP TOTAL i 81.4 203.7 2076.9 : 131.4 219.3 1884.0 ! 127.3 127.2 I 2037.6 i 62.7 152.7 1950.2 i 129.1 185.4 1757.5 59.4 258.0 1868.8 I 27.1 245.9 1785.4 I 39.2 233.6 1966.1 I 64.2 300.3 2489.3 : 59.7 152.3 1852.1 57.9 104.8 2240.8 47.6 201.8 1884.5 59.4 189.1 18203 I 145.3 84.2 1653.4 15.8 157.3 1873.4 70.4 192.0 2511.4 84.6 302.1 2331.2 134.3 186.3 2217.5 40.3 173.2 2372.2 113.8 144.7 2007.9 135.1 291.8 2388.9 164.8 161.2 2176.5 13.6 150.3 1728.0 13.7 137.6 1991.0 76.0 210.8 1857.1 60.9 220.9 2209.8 22.9 157.4 1856.7 99.7 204.7 2025.5 47.4 247.0 2124.5 42.2 303.3 1997.5 124.6 231.3 2426.8 97.6 253.0 2058.3 48.5 125.9 1774.6 102.6 248.6 2045.1 40.4 294.9 2183.4 27.2 169.9 2037.9 158.0 216.0 2358.0 123.4 168.4 1600.9 32.6 144.3 1821.3 154.0 188.6 19749 i TABLE 8 (cont'd) POWER GENERATION LAKE 1013 THE EFFECTIVE CAPACITY OF THE UNITS IS 532 KILOWATTS SIMULATED PRODUCTION IN MEGAWATT-HOURS YEAR OCT NOV DEC IAN FEB MAR APR MAY JUN JUL 1959 357.3 220.2 271.4 134.1 130.4 249.7 230.6 186.7 161.3 142.5 1960 336.1 253.6 314.5 89.8 148.3 208.9 337.0 210.2 126.7 135.7 1961 359.7 214.3 268.8 236.8 205.5 164.5 302.8 111.4 82.2 6.3 1962 360.0 241.2 157.9 208.7 101.8 79.6 302.4 109.2 127.0 33.9 1963 351.2 305.6 284.9 152.0 245.2 128.5 110.5 77.0 71.0 21.4 1964 363.9 150.8 225.8 185.3 271.3 125.2 259.8 120.4 215.7 116.7 1965 363.0 221.4 170.2 159.8 134.1 121.7 153.7 73.1 49.8 0.0 1966 357.9 109.9 194.7 82.9 111.5 174.5 237.1 284.0 112.1 41.1 1967 350.3 149.7 200.8 150.0 200.3 105.3 24.1 286.1 126.0 132.1 1968 359.7 188.1 161.3 174.4 147.2 249.0 223.9 162.4 86.5 36.6 1969 351.2 279.2 133.0 2.1 0.0 57.8 284.2 164.6 65.6 82.7 1970 308.1 349.9 266.9 126.2 264.8 185.3 203.2 252.8 128.4 58.0 1971 348.5 125.5 107.9 119.0 163.6 106.9 234.9 209.2 200.4 72.2 1972 327.1 198.8 153.0 54.5 61.4 202.7 96.3 255.2 192.4 180.0 1973 328.4 201.8 132.8 154.0 153.7 143.3 276.3 208.8 135.6 138.8 1974 360.2 12.7 167.1 13.7 164.5 79.7 272.3 248.0 190.2 130.4 1975 368.3 219.8 281.6 137.6 57.1 97.5 138.1 195.7 154.7 127.5 1976 331.4 144.3 243.5 201.4 157.6 135.2 169.1 178.4 135.3 237.7 1977 336.1 197.8 277.7 115.3 275.2 156.4 255.5 51.4 112.7 60.8 1978 342.0 182.4 146.0 49.0 149.1. 153.6 176.8 95.9 10.6 1.1 1979 368.3 226.8 210.0 29.9 n,3 223.3 160.7 250.1 96.2 12.4 1980 336.7 150.0 277.5 60.4 175.6 194.4 274.4 161.2 8.4 41.9 1981 344.8 343.9 244.3 311.5 172.0 201.5 239.6 27.4 41.4 33.9 1982 321.9 271.7 173.1 76.7 41.5 83.0 118.1 263.1 108.0 11.3 1983 332.2 97.9 152.3 238.3 201.1 116.3 209.9 159.3 6.3 16.9 1984 338.6 154.0 102.5 245.4 282.0 258.9 200.8 98.3 96.4 88.3 1985 328.9 92.6 175.7 245.2 150.2 178.5 244.3 169.0 81.4 29.5 1986 338.0 79.0 160.6 260.8 110.2 305.4 216.3 115.8 60.4 3.2 1987 360.2 174.5 259.0 258.1 247.4 107.1 300.9 215.7 145.6 4.2 1988 346.3 ~.3 243.3 132.9 173.9 243.4 262.7 249.2 126.6 96.3 1989 342.4 217.1 224.2 156.6 65.3 71.8 230.6 171.7 21.6 0.0 AVG 345.7 217.4 209.9 146.2 142.4 148.5 205.9 184.9 99.1 63.1 NOTE: PRODUCTION IS COMPUTED FROM SYNTHESIZED DAILY FLOW RECORDS ~ OF THE TIME PLANT IS SHUT DOWN FOR LOW FLOWS: 12.7 THE PLANT FACTOR IS .47 - AUG SEP TOTAL 85.3 222.7 2392.3 I' 76.4 217.4 2454.5 55.7 229.2 2237.1 I 73.4 227.6 2022.6 7.4 280.7 2035.5 102.4 198.3 2335.7 1.1 75.8 1523.7 112.2 245.2 2063.1 139.2 328.4 2192.3 40.9 307.1 2137.2 164.6 171.5 1756.5 117.5 241.8 2503.0 135.8 219.9 2043.7 191.8 261.2 2174.6 75.6 228.1 2177.3 66.6 148.7 1853.9 .. ' 80.4 181.9 2040.3 123.7 248.7 2306.2 14.5 172.3 2025.7 62.5 195.5 1564.4 17.5 231.8 1899.2 78.6 183.8 1943.l 84.8 247.8 2292.7 13.7 174.3 1656.5 ",. 181.8 207.8 1920.3 91.6 215.6 2172.5 56.4 158.0 1909.7 40.3 137.3 1827.3 ; "," 8.5 259.5 2340.8 96.6 229.2 2507.6 32.7 187.6 1791.6 ; 78.4 205.3 2046.7 .. .IIft Table 8 shows the power generation output and complete energy production assumptions and tabulated energy production for the entire years of simulated hydrological period of record, without considering reservoir drawdown. 4.2 loads A brief study of electrical demand at the City of Hydaburg was performed. From data supplied by AEA, annual load is about 1,300,000 kWh, for an average load of about 150 kW. Peak demand is about 370 kW currently. A refrigeration facility in town with a load of about 140 hp might operate sometime in the future, and could be more likely to operate if a secure source of electricity were available. A visitor's center with a load of up to 10 kW is also proposed for Hydaburg, but is unlikely to be operational before 1995 according to US Forest Service sources. AllOwing for S percent load growth per year and assuming all known possible loads are on line, the projected peak 1994 load is 545 kW. 5.0 COST ESTIMATE The cost estimate for the proposed project was prepared using past project experience, the Northwest Pipe & Casing Company Pipe Manual, average U.S. Bureau of Reclamation Cost Indexes, and cost quotations from major suppliers including Canyon Industries, Northwest Pipe & Casing, and Perelli Jacobson Contractors. At this level, the costs are estimated to be acauate to within plus or minus 30 percent Costs of various project features were developed by determination of unit quantities required for each major structure and application of unit costs appropriate for the area. Vendor quo&atiODS were obtained for some equipment such as the turbine generator, switchgear, pipe, submarine crossing, intake screen assemblies, etc. Results were tabulated in the FERC format in a Lotus 123 spreadsheet that could be used directly in exhibits for a FERC License Application should that project proceed to that point. Total project costs including design, licensing, construction, and start-up are $4,540,000 in January 1992 dollars. Escalation to July 1993 prices at S percent per year results in a -22- total project cost in 1993 of $4,880,000. See Table 9. Annual operations and maintenance costs for the first year of operation are estimated to be $159,000. Table 10 gives a breakdown of this estimate. 6.0 DEVEWPMENT ISSUES & SCHEDULE A general development schedule for this project suggests about 4 months will be required to perform detailed preliminary design of the project including some initial site surveying and geotechnical review. The product of this exercise would be performance plans and specifications and a project description adequate for both use in obtaining permits and licenses for the project and for refining cost estimates for the project to plus or minus 15 percent A go/no go decision should be made at this point to decide whether to proceed with project development. The licensing and permitting process would begin at this point and it should be possible to obtain all required approvals to proceed with construction within 12 months of application. We believe that some of the issues which could be raised during licensing include: 1) Instream flow requirements (We have assumed 1.0 cfs) 2) Verification of impassable barrier on Lake 1013 Creek 3) Loss of habitat or wetlands due to the raising of Lake 1013 4) Protection of wildlife from project impacts (eagles, bear, deer, elk) S) P.NIioa and sedimentation control during construction 6) SUeS" diversion and construction timing 7) Social and economic impacts 8) Water quality during and after construction Permits and licenses: HDR has reviewed the project and believes that the project as proposed should be exempt from FERC licensing requirements since there is no federally-owned land, an isolated electrical grid network, and the subject stream is not a -23- . ... ... .,..> ... - III- • ., w, ... • TABLE 9 DETAILED COST ESTIMATE -LAKE lOI3 ALASKA ENERGY AUTHORITY HYDABC"RG HYDROELECTRIC PROJECT LAKE 1013 DETAILED COST ESTIMATE (January 1992 Dollars) FERC i AIC No. , Description 330 Land and Land Rights 330.5 Mobilization and Logistics 331 Structures and Improvements 332 Reservoirs, Dams, and Waterways 333 Turbines, and Generators 334 Accessory Electrical Equipment 335 Misc. Mechanical Equipment 336 Roads, Railroads, and Bridges 350 Land and Land Rights (Transmission) 352 Transmission Structure and Improvements 353 Substation Equipment 355 Poles and Fixtures 356 Overhead Conductors and Devices 359 Line Clearing, Mob., and Demob. ESTIMATED COSTS SUBTOTAL Contingency Allowance (30 % ) TOT AL ESTIMATED DIRECT COST (rounded) Engineering and Administration (** 18.0%) TOTAL PROJECT COST JAN 1992 (rounded) TOT AL PROJECT COST JUL 1993 (rounded) Escalation @ 5 % to July 1993 .. Covering environmental studies and licensing (5 %), design and specification (8 %), and construction management (5 %). Amount ($) 50,000 262,400 143,400 832,400 170,000 15,000 20,000 171,500 0 39,640 290,000 380,550 541,450 45,000 $2,961,300 $888,400 $3,850,000 $693,000 $4,540,000 $4,880,000 FERC Acc No 330 .01 330 .5 .51 .52 .53 .54 .55 .56 .57 .58 .59 .60 331 331 .1 . 11 . 12 .13 . 14 .15 .16 .17 .18 .19 331 . 2 .21 .22 .23 . 24 .25 .26 TABLE 9 (cont'd) DETAILED COST ESTIMATE -LAKE 1013 ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT LAKE 1013 DET AILED COST ESTIMATE (January 1992 Dollars) Description LAND AND LAND RIGHTS Land Rights -Legal and Administrative Costs Subtotal -Acc No. 330 -Land and Land Rights MOBll..IZA TION AND LOGISTICS Storage and Helipads Construction Buildings Construction Power Temporary Water System Construction Surveys Rock Crusher Heavy Lift Helicopter Regular Helicopter Subsistence Crew Camp Costs Subtotal -Ace No. 330.5 -Mobilization and. Logistics STRUCTURES AND IMPROVEMENTS Powerhouse (20'X 26') Clearing (PowerhouseiSwitchyard) Excavation (assume no blasting) Concrete (including reinforcing) Structural Steel Metal Fabricat:iau Fumiahinp ad Fixtures Pre "'~4 MeIaI Building HV AC .... Plumbing arcp ",Grid: Subtotal -Powerhouse Powerhouse Site/Switchyard Fill Crushed Rock SurfAcing Drainage/Containment Chain Link Fencing Gate Foundations Quantity 1 1 1 1 1 1 1 3 20 200 1 2 100 SO 4,000 500 1 520 1 1 100 60 1 80 1 10 Unit I Amount Unit Price ($) 1-. ~ L.S. $50,000 50,000 .. 50,000 ~. .. f"" L.S. $5,000 5,000 -L.S. $30,000 30,000 L.S. $30,000 30,000 ... L.S. SS,OOO 5,000 ... L.S. SSO,OOO 50,000 L.S. $10,000 10,000 ~\ HOUR $1,800 5,400 iii HOUR $650 13,000 DAYS $70 14,000 .. L.S. $100,000 100,000 •• 262,400 ... ACRE $5,000 10,000 l1li' C.Y . $25 2,500 " C.Y. $1,000 50,000 ... LB . $4.00 16,000 LB. SS.OO 2,500 .<. L.S. $3,000 3,000 S.F. $45 23,400 1-<, L.S. $10,000 10,000 , L.S. $8,000 8,000 ., 125,400 1» • ... C.Y. $10 1,000 "",. C.Y. $20 1,200 L.S . $3,000 3,000 .. L.F. $30 2,400 f-" EACH $400 400 C.Y. $1,000 10,000 ~' ~ FERC .. Acc No .iI 332 332 .31 .311 .312 .313 .314 .315 .316 .317 .318 .319 .3110 .3111 .3112 332 .34 .341 .342 . 343 .344 • 345 . 346 332 .35 .351 . 352 TABLE 9 (cont'd) DETAILED COST ESTIMATE -LAKE 1013 ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT LAKE 1013 DETAILED COST ESTIMATE (January 1992 Dollars) Description Subtotal -Powerhouse Site/Switchyard Subtotal -Acc No. 331 -Stuctures and Improvements RESERVOIRS, DAMS, AND WATERWAYS Grouted Rock Dam Clearing Rock Placement and Grouting Drum Screens Intake Manifold IS-inch Diameter Steel Pipe 18-inch diameter Butterfly Valve Vacuum Valve 36-inch Low-Level Outlet 36-inch Sluice Gate Concrete Headwall Revegetation and Erosion Control Diversion and Care of Water Subtotal -Grouted Rock Dam Buried Penstock (5,500' Long) Clearing (30' wide) Trench Excavation (no rock assumed) Bee ... Ccwmcm 8 .... ll-iach Diameter Steel Penstock Coacrete iD Thruat.Blocks Revegetation and Erosion Control Subtotal -Penstock Tailrace Excavation (no rock assumed) Riprap Subtotal -Tailrace Quantity 0.5 200 2 4,000 3,000 1 1 50 1 1 0.5 1 2 13,000 9,200 3,070 214,500 80 2 100 30 I Unit Amount Unit Price ($) 18,000 143,400 ACRE $5,000 2,500 C.Y. $100 20,000 EACH $10,000 20,000 LB. $4.50 18,000 LB SO.68 2,040 EACH $5,000 5,000 L.S. $2,000 2,000 LF $50.00 2,500 L.S. $3,000 3,000 L.S. $10,000 10,000 ACRE $10,000 5,000 LS S20,OOO 20,000 90,040 ACRE $5,000 10,000 CY $25 325,000 C.Y. $10 92,000 C.Y. $2S 76,750 LB . $0.68 145,860 C.Y . SI,OOO 80,000 ACRE S5,OOO 10,000 739,610 C.Y • $20 2,000 C.Y. $25 750 2,750 FERC Acc No 333 334 .01 TABLE 9 (cont'd) DETAILED COST ESTIMATE -LAKE 1013 ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT LAKE 1013 DETAILED COST ESTIMATE (January 1992 Dollars) Description Subtotal -Acc No. 332 -Reservoir, Dams, & Waterways TURBINES AND GENERATORS Subtotal -Ace No. 333 -Turbines and Generators ACCESSORY ELECTRICAL EQUIPMENT Battery Pack and Recharger Quantity 1 1 Subtotal -Acc No. 334 -Accessory Electrical Equipment 335 MISCELLANEOUS MECHANICAL EQUIPMENT .01 Miscellaneous Equipment 1 Subtotal -Acc No. 335 -Miscellaneous Mechanical Equipm Int 336 ROADS .01 Clearing 30' 7.3 .02 Mountain Road 2.0 .03 Grade and surface exist. Hydaburg road 3.0 Subtotal -Acc No. 336 -Roads 350 LAND AND LAND RIGHTS .01 Land Ri&hD -TfUISIIIiaioD Line 1 Subtotal-Acc No. 350 -Land and Land Rights 352 STl.Ucrt1RES AND IMPROVEMENTS (TRANSMISSION FACILITY) 352 .1 Hydabyq Sublatioa .11 Site Prepuation ad Gradiq 1 .12 Concrete in Equipment Pads 10 .13 Crushed Rock Sur&ciDg 100 .14 Chain Link Fence 80 .15 Gate 1 Subtotal -Hydaburg Substation Subtotal -Ace No. 352 -Struct. and Imp. (Transmission Facility) .' Unit Amount Unit Price ($) ... 832,400 .., L.S. $170,000 ... ~, 170,000 Ii-"') L.S. $15,000 15,000 . 15,000 .' ~I" L.S. $20,000 20,000 Po 20,000 ~:; lIP 36,500 ~ .. ACRE $5,000 MILE $60,000 120,000 r- MILE $5,000 15,000 171,500 l L.S. $0 I O~ 01 1~~'I- I ,- L.S. $25,000 25,000, C.Y. $1,000 10,000 1 C.Y. $20 2,000. L.F. $28 2':'1 EACH $400 ,. 39,640.m 39,640:J 'J " FERC Ace No 353 353 . 1 .11 .12 353 .2 355 355 . 1 .11 .12 .13 356 356 .1 .11 .12 . 13 .14 359 .01 .02 TABLE 9 (cont'd) DETAILED COST ESTIMATE -LAKE 1013 ALASKA ENERGY AUTHORITY HYDABURG HYDROELECTRIC PROJECT LAKE 1013 DET AILED COST ESTIMATE (January 1992 Dollars) Description SUBST A nON EQUIPMENT AND STRUCTURES Lake 1013 Switchyard Transformer, 4,500 kVA (4. 16/35kV) Switches and Misc. Equip Subtotal -Reynolds Creek Switchyard Hydaburg Switchyard Transformer (34.5 kV 12.4kV) Switches, Breakers, and Misc. Equip Subtotal -Hydaburg Switchyard Subtotal -Ace No. 353 -Substation Equipment POLES AND FIXTURES Lake 1013 Powerhouse to Hydaburg 34.5 kV 3.7 miles Poles Guys, Anchors, and other Material Installation Subtotal -Acc No. 355 -Poles and Fixtures OVERHEAD CONDUCTORS AND DEVICES Lab 1013 Powert.ou.e to Hydaburg 34.5 kV 3.7 miles C.,.,.,..,.. Insulatan ~.·tIIId:·.MiscellaneoWl Installation Subtotal -Acc No. 356 -Overhead Conductors and Devices LINE CLEARING, MOBnlZE, AND DEMOBll.IZE Mobilize and Demobilize Light Clearing Subtotal -Ace No. 359 -Line Clearing, Mob., and Demob. Quantity I 1 1 1 1 1 1 3.7 1 1 1 3.7 1 3 I Unit I Amount Unit Price ($) L.S. $70,000 70,000 L.S. $50,000 50,000 120,000 L.S. $70,000 70,000 L.S. $100,000 100,000 170,000 290,000 L.S. $100,000 100,000 L.S. $90,000 90,000 MILE $51,500 $190,550 380,550 L.S. $150,000 150,000 L.S. $100,000 100,000 L.S . $75,000 75,000 MILE $58,500 216,450 541,450 L.S. $30,000 30,000 ACRE $5,000 15,000 45,000 TABLE 10 HYDABURG HYDRO INVESTIGA nON LAKE 1013 PROJECT FIRST YEAR O&M COSTS ITEM Hydro Maintenance (2 % of equipment costs) Road Maintenance Insurance Labor (One full time operator) FERC and Other Permit Fees Subsistence Fuels/Oils/Consumables Administrative Costs Total First Year Costs COST S37,000 $5,000 $40,000 $50,000 $2,000 S12,000 $5,000 $8,000 =========== $159,000 _i! IOIIi' - .. '" .. navigable waterway. Occasionally, the presence of anadromous fish in the streams, as is the case here, can trigger objections by federal and state fisheries agencies that could bring FERC into the picture. We believe this could be avoided in this case. Major permits that would be required include: 1) Water Rights -Alaska DNR 2) Alaska Coastal Management Program Compliance 3) 401 Clean Water Certification (DEC) 4) Authority to construct or modify a dam -Alaska DNR 5) FERC confirmation of no jurisdiction 6) Army Corps of Engineers -404 Permit to place fill in rivers Once all project permits are received, final design and construction can proceed. Construction should be planned to begin in late March or early April to take full advantage of the summer construction period. Every attempt should be made to have access installed to the dam site so dam construction could proceed in July and August, the low flow months. Final design should take about 3 to 4 months to get plans and specifications to the point the work could be put out for construction bids. Actual site construction could be performed in one construction season if it were closely planned and well organized. Several issues would need to be addressed early in the development of this project in order to keep the whole development moving smoothly. These issues include: 1) Ownership rX the Project. Possible Owners include: a) Private Developer; b) City of Hydaburg; c) Haida Corporation; d) Alaska Energy Authority; e) Alaska Power and Telephone; or f) Sealaska Corporation; or g) some combination of the above. Ownership will affect financing methods, operations, permitting, and bidding requirements to name a few. ·24- 2) Land Rights: Hydaburg City staff indicated that all project lands are believed to be currently owned by the Sealaska Corporation, but that Sealaska was in favor of the project and was open to negotiations. Oearly, decisions about land ownership, easements, or rights-of-way need to be made, but full investigation of land rights issues was outside the scope of this study. Costs for land owner negotiations are included in the project cost estimate. 3) Presently, Alaska Power and Telephone is authorized by the APUC to sell electricity in Hydaburg. 4) Financing and Sources of Funding: The sources of funding for the project, whether they be bond sales, outside financing, grants, subsidies or some combination of these, will affect the economic evaluation of the project and to some extent project schedules and overall costs. Basic agreement on the approach to financing will clarify other issues and focus the development effort. v. COMPARISON OF REYNOLDS CREEK AND LAKE 1013 PROJEerS The following table presents a comparison of the various aspects of the Reynolds Creek and Lake 1013 Projects. -25- ". .... .. .. •• - .. "'. HYDABURG HYDRO INVESTIGATION COMPARISON OF REYNOLDS CREEK AND LAKE 1013 PROJECTS ITEM REYNOLDS CREEK LAKE 1013 Full Load Output 750 kW (1) 600 kW Peak Annual Energy 6,00),00) kWh 2,046,00) kWh Length Penstock 2,600 feet 5,500 feet Length Transmission 11.4 miles 3.7 miles Total Cost $8,260,00) $4,880,00) Cost Per Kilowatt $11,00) $8,084 Cost of Transmission $4,795,00) $2,120,00) Percent of Total for Transmission 58.1% 43.7% Line Can Expand In Future yes no Require FERC License yes no Meets All Hydaburg Needs When yes no On-line & Available Gross Head 681' 650' Design Flow 18 cfs (2) 14 cfs Basin Average Annual Flow in cfs 70.9 cfs 9 cfs Type of Turbine 2 jet pelton 2 jet pelton Assumed FISh Bypass Flow 5cfs 1 cfs Reservoir Storage 640 ac-ft 280 ac-ft. Estimated Total Development Time 57 months 31 months Notes: 1. Plant size is 750 kW for first phase of development, second phase is 1,500 kW capacity. 2. Design flow at full 1,500 kW capacity is 36 cfs The attached Figure 17 is a comparison of the total estimated development time for the Reynolds Creek and Lake 1013 Projects. The requirement for a FERC license on the Reynolds Creek Project is estimated to add from 18 months to 3 years to its overall development schedule compared to the Lake 1013 Project. ·26- November. 1991 YlU 1 PROJIICT J , .. " .. oJ oJ " s Planning LAKE 1013 PROJEcr Planning REYNOLDS CREEK , , , , , FIGURE 17 HYDABURG HYDRO INVESTIGATION-PROJECT DEVELOPMENT TIME LINE REYNOLDS CREEK AND LAKE 1013 PROJECTS Y\UUI l Y\UUI ] YEAH .. 0 • D J F M A M J J A S 0 N D J F M A M J J A S 0 N 0 J f M A M J J A S 0 N IJ J Per.l [[ lng Oes1gn I I _'I f I Constluctlon Total· 11 Montha Std[-[ up Pennitt1ng (14 To 48 Months) Des1gn F M A TO'..! t~ t ~91..,~t~. L.~.n~l~g ~n IPel-IUngl COBS t I U('( lun ., . , I , , .. • YlAR ~ M J J A S 0 N .':i I dl t "P -III VI. CONCLUSIONS AND RECOMMENDATIONS 1. Both projects appear to be technically feasible. The high cost of transmission lines from Reynolds Creek is an apparent obstacle to development. 2. A land survey to determine the correct elevation of Lake 1013 should be performed early in the development process. 3. Powerhouse locations and elevations at both sites need to be confirmed through land surveymg. 4. If the decision is made to go ahead with a more detailed analysis of these projects, recording stream gages should be installed at each diversion site. A significant amount of local flow data must be collected before a more detailed hydrologic analysis could be completed. The data collection process should be started as soon as the decision is made to continue the project investigation. 5. The Reynolds Creek Project will likely require a FERC l1cense or Exemption. The Lake 1013 Project should be able to avoid this requirement. 6. Agencies with jurisdiction should be contacted early in the development process to obtain their input on all the known issues and to uncover any other potential issues. Instream flow requirements, particularly on the Lake 1013 Project, will have a great impact on annnal power generation predictions. 7. 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'.'tll ,.- ~.+ ~) / val" .. , "'!UJ.ID.t~~flliiiifill .3'O.OOO.'lO •. ~s;l\~. Conlilureit.lotaot .k.t.Ob. W __ too· ov... • woad ....... , .,', 'I' I 100II ., ...... :\fi:.,.., ~'1I .. 1.)I' .. . .,,, .. t.M1-.a t-a.i.· ~JJiI\ ~~"'Jr.~ .... ". r j' ; " . . ~ . " . t": ., ' , , .,( " ~ "'...-'''-'' --"--_.- (.0.1 NORTHWEST PIPE & CASING CD. QUOTATIO~ TO Mandera Shrestha H.D.R. gnglneers Bellevue, WA C DATI ) .... ___ o_c_t_o_b_e_r _1_7_, _1_99_1 ______ ~.'" OUIII IIIEIltIilDiCI Prince or Whales Island Pipeline ~II"CES SElOW ...... E QliQTEO 'SHIPMENT CAN BE MAOtI 'PAYMENT T'liIilMS FOB Dockside in Seatth WE TAKE PLEASURE IN aUOTlNG AS FOUOWS. The following are estlmatinc prices tor the above noted project as you requested. The pipe wtll conform to AnA C-200 and w111 be in 40' lenathl with O-Rlnlluket Joints. 1 ", The coatine w111 be a 60 mil tape system per AnA C-214. The lln1nl wll1 be a tank _ 8olution (TAO). one coat to 4 to emU •. 1300' 1300' 24ft 00 x 10 1& wall thickness (pipe wellht 37./tt) 24" OD x 3tH!" •• U thickness (plpe "eL,ht 50*lft> Please call me or Gre, Smith It you have any questions. Dave Bla!r Chief !:stimator III cc: Gre. SIllth '29.60tfoot '38.00/foot ,"II QUCTA"~ I' .U .... fTTID IUaJlCT TO TINt AND CattDmONS ON "IVIRIL II' 1liii' ... ' .. ... ... - ,'4,j r Ire .l. \ ,,,\ • ..,) I , .. ~ . "tt..I ",.,... • '(I • .. r ... QJ NCRTHWEST PIPE & CASINCI CC. QUOTATIOf\ TO Mr. Don Thompson H.D ,R. Eni1neers Sent via fax 206-463-7101 rA~ l_ October 16.1991 C'l'OU~ "IEI'EAE,,"CE Black Creek Hydro ~jiiI'Cc5 BE_GW AFIE OuO-:'ED SHIPMEN'" CAN BE MAoe PA'I'MENT ~~M8 fOB Jobs1te '" WE TAKE ~L;;ASURE IN aUOTING AS FOL.L.OWS. The prices llsted be!ow are estimating prices for tr.e steel ptpe for the above noted project. All pipe wtlt conform to AWVlA C-200 and will have welded bell joints. The coal tar epoxy lintng w1ll conform to AWWA C-210 except the paint wlll be applied in ~ coat. The tape coating wtll conform to AWWA C-214 and will be an 80 m1l system. 30" 00 x 1.'4" wall pipe x 40' long, bare steel 30" 00 x 112" wall ptpe x 40' long, bare steel 36" 00 x 1/4" wall ptpe x 40' long, bare steel 30" coal tar epoxy lininl 36" coal tar epoxy lining 30" tape coat1nl I 10 ,..,i !H5" tape coatinl I to ".,,;/ 1" thick cement mortar overcoat over the tape 137. gOlf! S81.35ift S44.gS/tt S 14.201rt S 16.90/ft S 9.15/ft SlO.gS/ft $13.50/ft rr you have any questions, Dlease call me at 800-824-9824 or 503-286-1400. ?;.~ Dave Blair Chlef E.timator Isr ~.b7/+¥- 3.0Q/Pf THI' QUOTAT10N 's 8UIM!T'T'IO SUILIECT TO UIII"'8 ANO CCNomON9 ON PEVI!PSI. ) l,v I NORTHWEST PIPE & CASINCJ CO, , " QUOTATION TO Mandera Shrestha H.D.R. Ene1neers Bellevue, WA re"fi l October 21. 1991 Prtnce of Whales [sland Pipeline "'1'II:C£9 6E~O"'" AA!: OUO'!'£O ""'P~eNr C,\N 8. MAOE ?AVMI!NT TERMS FOB Dockside 1n Seattle WE TAKE PLEASURE IN OUOTING AS FOLLOWS. ,..he following are estimatini prtces tor the above noted project as you requuted. The plp@ will conform to AWWA C-200 and w111 be in 40' len&ths with O-Ring gasket joints The Coatin& wlll bE! A 60 mil tape system per AWWA C-214. The 11n1n& w111 be a tank 5011.1.:ion (TelO), one coat to 4 to 6 mill. 1300' 24" 00 x lOla wall thickness (pipe weight 37#ltt) 1300' 24" 00 x 3/1 e" wall thickness (pipe weight 50"ltt) 1~00' 24" 00 1 1/4" wall thic:kness (pipe weleht 674'/ft) 2750' is'' 00 x 10 ia wall thickness (p1pe weicht 29./tt) 2760' 18" 00 x 3/l6" wall thickness (pipe we1eht 3941/tt) 2150' 18" OD x 1/4" .. a.U thtcknelS (pipe •• 1aht 81#/tt) Please call me or Gr., Smith If you ha.ve any questions. Dave Blair Chiet Estlmator fsr e~: GrjIJl Smith S29.50/ft S38.001ft $44.95/ft S21.60/tt S26.25/tt &31.g0/ft ....... -...... ~ --..... -."..... __ ..... -~_~. _____ __ __ _. __ A ._a..'- ) .... PIRELLI JACOBSON, INC. Fax No. (206) 789-2851 DATE: 10/21/91 TO: HDR E;;;~N~~~.3I.l,;;L.;-:....!B~ELLEVUE A1J:N:- "------ FROM: PIETRO MONDINI TO Fax Ref. #: PJI-3906-PM cc; " NO. PAGES (INCLUDING THIS COVER): 2 , . ~ , IF YOU HAVE ANY PROBLEM WITH THIS TRANSMISSION, PLEASE CALL US AT (206) 782-1618. ------.-._---------_ ..... ---... ---------_.-----------............. _-----.--.. -... --._----------------.--... Re: 35kV Submarine Cable 30 Miles Off Ketchikan· Alaska With regard to your request dated October 18, 1991, we would respond as follows: 1. Cable Sypoly For the application you are requiring, we would propose a submarine cable of the following main characteristics: Voltage Conductor Semiconducting Layer Insulation Semiconducting Layer Metallic Shielding Laying Up Core Binder Bedding Armor Serving Reference Standard 35kV -3/i 4/0 Tinned copper compact sealed strand Thermosetting extruded compound EPR Compound (Ethylen/Polypropylene/Rubber). 345 mils thickness Thermosetting extruded compound Tmed copper tapes Three cores as above are cabled together with Polypropylene filler. A 6 F.O. cable could be ptaced in one of the interstice. Woven tape Polypropylene yam Galvanized steel wires Polypropylene yam AEIC-CS-6-82 and ICEA S.68.516 as far as applicable TO 2. Installation ServiceS To install the above cable, we will be using specialized laying equipment as well as qualified personnel out of our premises in the Seattle area. At this time, with the information we have available so far, we would propose the following services: 2.1 Mobilize the equipment and personnel 2.2 Survey the cable route 2.3 Receive the cable 2.4 Transit to site 2.5 Lay the cable 2.6 Terminate or splice the cable at each end (termination structures or vaults to be provided by others) 2.7 Test the cable 2.8 Demobilize equipment and personnel We have estimated the costs of the above services to be: Please call uS for any questions you may have. Regards, PIREW JACOBSON, INC. JLv J --.. Pietro Mondini Vice Presider4l~ineering & Strategic PImW ag $450,000 - ..... ... ... .. ... ... .. -_ .. -. , 1 ~COKDUCTOR BINDER TAPE AIDIOI BEDDING AIDIOR BPa XII8Ur..aIfOBD .£~ DEBIGII 80BHaJlIHB POtrBIl CABLB I • SPECnLLY FORMULATED HV EPR INSULATION • tJRJACRrzo, tJHSBBA~D CABLES • • • • loot , ll3' LEVEL OF INSULATION PRESH , SEA WAIf'ER IHS'l'AL'A'l'IONS ~TY (20) YEARS OP OPERATING EXPERIENCE APPROX. 350 MILES OF MV (5-35 kV) CABLE IHS~ALI,ED 'l'O DA'rE , : . , ________ • &:_1 LAKE MELLEN AND REYNOLDS CREEK SEPTEMBER, 1991 OUTLET OF LAKE MELLEN Dam would be constructed in cut near center of photo SEPTEMBER 1991 IP~ Tide till REYNOLDS CREEK PROJECT HYDABURG, ALASKA ~ 1--SITe PHOTOGRAPHS I p~ NIII'ftber io.u I~M __ I . 1 I J ·r " " LAKE 1013 DRAINAGE BASIN SEPTEMBER, 1991 i, ~~~'i19 . ;,;-" ~.... ... ...... , . .~' -1,.(' ~,.:}:~~ 1 . ' ' . .:~ .. ~'~?i:f .' . ,.' •. ' :'P" ~ .. ~~ ~ itf .' . , ' .1'; '1 ~ ''''i-~. 'j ?,P ~.~~:}61 •. ";~~~~ • ...... M.._. 4n~' ~ _ l ...... :-..." .. " LAKE 1013 OUTLET NEAR PROPOSED SEPTEMBER,1991 Project Title lil~ LAKE 1013 PROJECT HYDABURG. ALASKA ... 1--SITE PHOTOGRAPHS Ipro;.ct N ....... I D ... I ProtKt M-e- ____ ...i-..... LAKE 1013 SEPTEMBER, 1991 IprojKt T .... L'R I LAKE 1013 PROJECT HYDABURG, ALASKA ru 1--rA SITE PHOTOGRAPHS I Protect N .......