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Final Report Bethel-NYAC Transmission Line Feasibility Report 1992
FINAL REPORT BETHEL - NYAC TRANSMISSION LINE FEASIBILITY REPORT Prepared for: Calista Corporation 601 W. Sth Avenue Anchorage, AK 99501 Prepared by: BETTINE & ASSOCIATES 400 D. St., Suite 320 Anchorage, AK 99501 May, 1992 Funded By: Alaska Energy Authority Contract #2800459 FINAL REPORT BETHEL - NYAC TRANSMISSION LINE FEASIBILITY REPORT Prepared for: Calista Corporation 601 W. Sth Avenue Anchorage, AK 99501 Prepared by: BETTINE & ASSOCIATES 400 D. St., Suite 320 Anchorage, AK 99501 May, 1992 Funded By: Alaska Energy Authority Contract #2800459 PREFACE The results of the economic analysis contained in this report conclusively favors the Single Wire Ground Return (SWGR) transmission systemalternative over the more conventional three phase transmission system alternatives. While the use of a single energized wire and earth return circuit is unconventional in the sense that the application is not common, it is an accepted system of proven use in many areas of the world including Alaska. In 1981an experimental 8.5 mile SWGR transmission line was constructed between the communities of Bethel and Napakiak. This line has been in operation for over 10 years, safely, economically and reliably delivering low cost electrical energy from Bethel to Napakiak. Construction of SWGR system within the State should not, however, be allowed to proceed in an uncontrolled manner. The fifth edition of the National Electrical Safety Code (NESC) allowed the use of the earthasareturnconductor for a power circuit in rural areas, however the most recent edition does not. In orderto construct the experimental SWGR transmission line between Bethel and Napakiak it was necessary to obtaina waiver tothe NESC from the State of Alaska, Department of Labor. It is anticipated that a similar waiver would be required to construct and operate any new SWGR line within the State. Because of possible problems associated with safety, ground return currents such as corrosion or communication interference, each project should require licensing by the State after careful, but timely review. The SWGR system proposed in this report is similar in design to the existing system presently interconnecting Bethel and Napakiak and would in no way createan operating system with a lesser safety than the "conventional" systems now in use throughout Alaska. However, to prevent personal injury it is imperative that the State require all earthing systems meet or exceed the standards as set forthin IEEE guide for substation grounding. Bethel-Kwethluk Jct. K-Jet. -Kvethluk K-Jet. ~Akiachuk Akiachuk-Akiak Axiak-Tuluksak Jct. T-Jet.-Tuluksak 10.0 TeJet. -MYAC 2a TOTAL «86-45 tincludee 0.2 mi. submarine cable VICINITY MAP TABLE OF CONTENTS 1.0 INTRODUCTION AND SUMMARY 2.0 EXISTING SYSTEMS AND FUTURE ELECTRIC POWER REQUIREMENTS 2.1 Existing Facilities 2.2 Historical Information 2.3 Future Electric Energy and Demand Projections 3.0 ECONOMIC FEASIBILITY ANALYSIS 3.1 Introduction 3.2 The Choice of Methods and Alternatives 3.3 Alternative Development Plans 3.4 Conclusions 3.5 Recommendations APPENDICES A TECHNICAL DATA A.1 Conceptual Design Summary A.2 Design Parameters A.3 Single Wire Ground Return Minimum Cost Transmission System A.4 Three Phase Construction A.5 Pile Foundations A.6 Conductor A.7 Single Phase to Three Phase Conversion in SWGR Power Tranmsission B COST ESTIMATES C ECONOMIC EVALUATION C.1 Description of Alternatives C.2 Parameters Used For Economic Evaluation C.3 Explanation of Computer Printouts PAGE NO. © 0c CO 19 19 21 22 33 34 Al A2 A2 A3 A4 AS A7 A9 Bl Cl C2 3) C6 GRAPHS 1 BUSBAR COST OF ENERGY $/KWH FOR YEARS 1993, 2003 & 2014 5% & 7.6 % Financing BUSBAR COST OF ENERGY $/KWH 5% & 7.6% Financing AVERAGE BUSBAR ENERGY COST $/KWH, 5% & 7.6% Financing TABLES 1 5 FI 1 COMPARISON OF BUSBAR COST OF ENERGY FOR MAIN ALTERNATIVES INVESTIGATED TABULATION OF ESTIMATED 1993 PEAK LOAD REQUIREMENTS FOR THE 7 VILLAGES, NYAC AND BETHEL ELECTRIC ENERGY AND POWER REQUIREMENTS FOR INTERCONNECTED VILLAGES AVERAGE BUSBAR COST OF ENERGY $/kWH (1993 DOLLARS) STRUCTURE DESIGN SUMMARY E FIGURE 1, PROJECT VICINITY MAP FA TIE ii 6,7 29, 30 oi) 32 18 28 A6 36 1.0. INTRODUCTION AND SUMMARY 1.1. INTRODUCTION Calista Corporation, utilizing grant funds received from the Alaska Energy Authority (AEA), has authorized a study for the purpose of evaluating the technical and economic feasibility of constructing an electrical transmission line to interconnect one or more of the villages of Kwethluk, Akiachak, Akiak, Tuluksak and the mining camp at Nyac, with the regions largest central electric generating facility located at Bethel, Alaska.* Additionally the study is to evaluate the economic feasibility of developing and utilizing a small 1.4 MW hydroelectric plant located at Nyac, Alaska to supply electric power and energy to the transmission line. The technical feasibility and cost associated with the development of the Nyac hydro project is contained in the report entitled, Accepted Draft Report, Nyac Hydroelectric Investigation, prepared for the Alaska Energy Authority, November 1991. 1.2 SUMMARY Except for the villages of Napakiak and Oscarville which are connected to Bethel by electric power lines, the remaining villages surrounding Bethel rely exclusively on small diesel power plants to satisfy their electrical power _Tequirements. These small village power plants are inherently inefficient “producing approximately 7 kWHs/gallon of diesel fuel as compared to 12-14 kWHs/gallon for larger power plants such as found in Bethel. These low generation efficiencies when combined with the high cost of diesel fuel in the villages has resulted in excessive electrical energy costs for village consumers.” Typically the cost of electrical energy in the villages exceeds electrical energy costs in Bethel by a factor of two. The construction of transmission lines to interconnect villages to a central generation facility in Bethel and the development of the Nyac hydroelectric project would appear to hold immense potential for lowering the cost of electricity in the villages. a. In addition to these four villages and Nyac, the villages of Napaskiak, Oscarville and Napakiak were included in alternatives which examined the economics of a regional transmission intertie. b. Current residential rates per kWh: Akiachak - $0.49; Akiak - $0.47; Bethel - $0.2156; Kwethluk - $0.44; Tuluksak - $0.45 The following paragraphs summarize the main findings contained in the report. A. Existing Systems and Future Power Requirements Power requirements have been estimated for eight communities in the Bethel area. The communities are those which are located to the east and south of Bethel and which can cost effectively be interconnected to Bethel and/or the Nyac hydroelectric project by a transmission line. Future power requirements for these communities have been established using historical growth rates. It is anticipated that historical growth rates will continue and industrial development will be encouraged if a cost-stable source of energy becomes available. Sensitivity to load growth projections has been determined by assuming a no load growth and a high-load growth scenario, for selected alternatives. High-load growth has been calculated assuming a yearly load growth of 2.4% which is a 20% increase over the average historical village load growth of 2%. B. Electric Energy Resources Central generation with transmission interties promises cheaper energy cost to villages, as a result of enhanced generating efficiency and lower fuel costs in Bethel, if transmission ties are economically feasible. The Single Wire Ground Return (SWGR) transmission line concept is anticipated to offer substantial savings compared to conventional three phase transmission lines. A demonstration SWGR transmission line interconnecting Napakiak to Bethel was constructed in 1980 and has been operating successfully and reliably for the past 11 years, effectively demonstrating the economic and technical feasibility of the SWGR concept. The Nyac hydroelectric project located near Nyac has the potential to generate an estimated 5000 MWH per year with a peak output of 1400 kW. This hydro site represents perhaps the only renewable resource in the Bethel area that can at present be economically developed to provide lower priced electric energy and power to the communities examined in the study. CE ic Feasibili lysi The construction of a regional transmission intertie (See Figure 1, pg. 3) which would interconnect the villages of Akiachak, Akiak, Kwethluk, Tuluksak, Napaskiak, Oscarville, Napakiak and the mining camp of Nyac to a centralized more efficient generation source in Bethel and development of the Nyac hydroelectric project to provide energy to these 7 villages and Nyac, appears to be the most promising alternative. NYAC TIE LINE SEGMENTS: BETHEL- Kwethluk Jct. K-Jct .-Kwethluk K-Jct.-Akiachuk Akiachuk-Akiak Tuluksak Jct. --Tuluksak Bethel- Akiak- T-Jet T-Jct .-NYAC submarine cable 0.2 mi. “Includes Kwethluk Napskiak FIGURE 1 PROJ MAP VICINITY ECT Construction of transmission interties to connect the villages of Akiachak, Akiak, Kwethluk, Tuluksak and Nyac to a central generation facility in Bethel has been found feasible independent of the Nyac Hydro project. This is mostly due to the higher generation efficiencies and lower fuel costs found in Bethel as compared to those found in the villages. Table 1 compares the busbar cost of energy for six selected alternatives. This information is also portrayed graphically on Graph 1 and 1A (pgs. 6&7). Energy cost are listed for financing rates of 5% and 7.6%. Note: Busbar costs are not the costs charged to the consumer. Busbar costs are the minimum costs which must be charged to recover fixed and production costs. It is estimated the cost to the consumer would at a minimum, average 5-10% greater than busbar costs. TABLE 1 usb: t of E i Ww Financing rate of 5%/7.6% lternati lan 1995 2004 2014 Continued Self Generation at $0.42 $0.44 $0.48 Akiachak, Akiak, Kwethluk and Tuluksak (1-A)‘° Akiachak, Akiak, Kwethluk, $0.39/0.47 $0.34/0.41 $0.07/0.07 Tuluksak, Nyac, + Nyac Hydro intertied to Bethel with Single Pole SWGR Transmission Line (3-A) Akiachak, Akiak, Kwethluk, $0.49/0.59 $0.43/0.51 $0.06/0.06 Tuluksak, Nyac, + Nyac Hydro intertied to Bethel with Single Pole 3 wire, 3 phase Transmission Line (5S-A) Akiachak, Akiak, Kwethluk, $0.34/0.37 $0.31/0.34 $0.21/0.21 and Tuluksak, intertied to Bethel with Single Pole SWGR Transmission Line (8-A) Akiachak, Akiak, Kwethluk, $0.34/0.40 $0.30/0.35 $0.10/0.10 Tuluksak, Nyac, Napaskiak, Oscarville, Napakiak + Nyac Hydro intertied to Bethel with Single Pole SWGR Transmission Line (11-A) Akiachak, Akiak, Nyac, +Nyac Hydro $0.40/0.47 $0.35/0.41 $0.10/0.10 intertied to Bethel with Single Pole 3 wire, 3 phase Transmission Line. Kwethluk, Tuluksak, Napaskiak, Oscarville, & Napakiak, intertie to transmission grid by Single Pole SWGR Transmission Line (12-A). c. A financing rate of 0% is assumed for alternative 1-A. 1.3. CONCLUSIONS AND RECOMMENDATIONS A. Conclusion The economics clearly favor the construction of a transmission system interconnecting the villages with the centralized more efficient generation facilities found in Bethel, with or without the development of the Nyac hydroelectric project. In addition, the results of the economic analysis strongly encourages the development of the Nyac hydroelectric project. B. Recommendations Careful study of these alternatives suggest the following development plan should be implemented. 1. Construct a transmission line in 1993 utilizing Single Pole SWGR construction® to intertie the four villages of Akiachak, Akiak, Kwethluk and Tuluksak with Bethel. 2. Construct the Nyac hydroelectric project as quickly as permitting and financing allows. Extend the transmission line from Tuluksak to interconnect with the Nyac Hydro plant when it becomes operational, which is assumed as 1994 in this study. 3. A regional transmission intertie system, which extends the Bethel - Nyac transmission line to the villages of Napaskiak, Oscarville and Napakiak should be constructed.* Such an regional intertie would serve to further reduce the cost of energy in the villages. d. SWGR construction using A-Frame or Single Pole construction are approximately equal in costs. However, because Single Pole SWGR is designed such that it can be readily converted to a standard 3-phase transmission line, Single Pole SWGR construction is recommended over the slightly less expensive SWGR A-Frame construction. e. The villages of Napakiak and Oscarville are presently connected to Bethel by power lines. However, extending the transmission line to these two villages would eliminate any necessity for Bethel Utilities to wheel energy from the Nyac hydro over its distribution lines to these two villages. No federal or state regulations presently exist that requires a utility to wheel energy over its distribution lines. % FINANCING FOR YEARS 1995, 2004 & 2014 5 BUSBAR COST OF ENERGY $/KWH SP 2 ZZ - =— f| N i i 1 zig | 8 O flu 18 i i 2 ZL, «< | cook ’ a WLLLLMdddddldddddldddddl, i < w aaa < CLL dddddddddddddddddbbdddle,,” < e828 8 8 82 288 9 9 9S So Oo Oo So o So oO oS A PB FA A A A @F PA ea A ea HM>/$ ADYANA AO LSOO YVasSnd OV ALTERNATIVES BUSBAR COST OF ENERGY $/KWH $0.60 $0.50- $0.40- $0.30-7/ $0.20- $0.10+}"~ BUSBAR COST OF ENERGY $/KWH FOR YEARS 1995, 2004 & 2014 7.6% FINANCING $0.00 GRAPH 1A _| YEARS 1995, 2004, 2014 Welle 5-A 8-A ALTERNATIVES 11-A 12-A 2.0 EXISTING SYSTEMS AND FUTURE ELECTRIC POWER REQUIREMENTS 2.1 EXISTING FACILITIES Electrical energy is supplied, to Bethel and the surrounding villages examined in this study, by diesel generators, and possibly a few gasoline powered units serving individual homes. The largest single source of power is Bethel Utilities, with the electrical load in Bethel being some 5 times greater than the combined total of all the villages included in this study. The following is a tabulation of the estimated 1993 peak load requirements for the 7 villages, Nyac and Bethel. Table 2 Location 1993 Peak L kW Akiachak 197 Akiak 68 Bethel 5500 Kwethluk 167 Napakiak 165 Napaskiak 92 Nyac 228 Oscarville 16 Tuluksak 76 As previously stated, there are no transmission or distribution interties between these communities with the exception that Napakiak is intertied to Bethel by a SWGR transmission line and Oscarville is connected to Bethel by a conventional single phase distribution line. 2.2 HISTORICAL INFORMATION The historical data relied on in performing this study was obtained from three primary sources. The first source consists of, Reconnaissance Study of he Kisaralik River Hydroelectric P r Potential and Alternative Ener Resources in the Bethel Area, Alaska Power Authority, 1980, which was used as the source for 1979 base data. The second source consisted of, First Annual Statistical Report of the Power Cost Equalization Program, Alaska Power Authority, 1989. The third source consisted of, Second Annual Statistical Report of the Power Cost Equalization Program, Alaska Energy Authority, 1990. The two Statistical Reports of the Power Cost Equalization Program were used as the primary sources to obtain the vast majority of data needed to complete this study. The information obtained from these sources indicates a compounded annual population growth rate of between 1.9 and 4 percent for the villages included in this study and generally a moderate increase in the electrical energy usage for each consumer class. 2.3 FUTURE ELECTRIC ENERGY AND DEMAND PROJECTIONS Population growth rates of between 1.9 and 4 percent were applied to individual villages based on historical growth rates. The 1989 ratio of residential consumers to population is maintained throughout the study period. A nominal relationship exists between the number of commercial and residential consumers. As the number of residential consumers increase, a greater number of commercial consumers can be supported. The 1989 ratio of small and large commercial consumers to residential consumers is maintained throughout the study period. Electric energy consumption for residential, small and large commercial classes of consumers, including schools is projected to increase at the rate of 1/2 percent per year in all villages. Energy consumption calculations are based on the assumption that village school load requirements, except for Tuluksak, are included as part of the energy consumption listed for each village as found in the two statistical reports of the Power Cost Equalization Program. Annual load factor is assumed to be .40 in 1979, increasing to .50 by 1989 and remaining at .50 throughout the study period. AKIACHAK Population growth between 1979 and 1989 has averaged approximately 1.9% per year. The growth rate is projected to remain at the same rate during the study period. BLECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 POPULATION 371 448 483 583 704 (1) # of Residential 50 107 115 139 168 Consumers (2) Average kWH/no/ 130 239 244 256 269 consumer (3) MWH/year residential 78.0 306.9 337.6 428.5 543.9 consumers (1)x(2)x12/1000 (4) # of small commercial 6 20 22 26 31 consumers (5) average kWH/no/ 400 373 381 388 396 consumer (6) MWH/year small 28.8 89.5 100.5 121.1 147.3 comm. consumer (4)x(5)x12/1000 (7) # of large consumers 1 2 2 3 3 plus public buildings (8) average kWH/mo/cons. 15,000 14,775 15,073 15,376 15,686 (9) Mwh/year LP's 180 354.6 = 361.7 553.6 = 564.7 (7)x(8)x12/1000 (10) System Muh/year (3)+(6)+(9)+8% Losses (11) System Load Factor (12) (System Demand kW 88.4 185.2 197.2 272.0 = 309.7 (10) /8.760/(11) 10 AKIAK Population growth between 1979 and 1989 has avera 2.7% per year. The growth rate is study period. f ged approximately projected to remain at this rate during the BLECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 POPULATION (1) # of Residential 25 60 67 87 113 Consumers (2) Average kWH/no/ 130 251 256 269 283 consumer (3) MWH/year residential 39.0 180.7 204.8 279.8 382.3 consumers (1)x(2)x12/1000 (4) # of small commercial 4 5 6 7 ng) consumers (5) average kWH/n0/ 175 378 386 393 401 consumer (6) MWH/year small 8.4 22.7 27.8 = 33.0 43.3 comm. consumer (4)x(5)x12/1000 (7).# of large consumers 1 2 2 3 4 plus public buildings (8) average kWH/no/cons. 8,000 1,700 1,734 1,823 1,916 (9) Mwh/year LP's 96 40.8 41.6 65.6 92.0 (7)x(8)x12/1000 : (10) System KWh/year (3)+(6)+(9)+8% Losses 154.9 263.7 296.1 = 408.8 = 559.1 (11) System Load 0.4 0.5 0.5 0.5 0.5 Factor (12) (System Demand kW 44.2 60.2 67.6 93.3 127.6 (10) /8.760/(11) 11 KWETHLUK Population growth between 1979 and 1989 has averaged approximately 1.3% per year. The growth rate is projected to remain at the same rate during the study period. ELECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 1979 1989 1993 2003 2013 POPULATION 457 518 545 617 700 (1) # of Residential 74 136 143 162 184 Consumers (2) Average kWH/no/ 130 204 208 219 230 consumer (3) MWH/year residential 115.4 332.9 357.1 425.5 506.9 consumers (1)x(2)x12/1000 (4) # of small commercial 8 8 8 10 Bb consumers (5) average kWH/n0/ 400 632 645 658 671 consumer (6) MWH/year small comm. consumer (4)x(5)x12/1000 (7) # of large consumers 1 2 2 2 3 plus public buildings (8) average kWH/mo/cons. 15,000 10,560 10,773 11,324 11,903 (9) Mwh/year LP‘s 180 = 253.4 258.5 = 271.8 = 428.5 (7)x(8)x12/1000 (10) System Muh/year (3)+(6)+(9)+8% Losses (11) System Load 0.4 0.5 0.5 Factor (12) (System Demand kW 102.9 159.5 167.1 9191.4 252.5 (10) /8.760/(11) 12 TULUKSAK Population growth between 1979 and 1989 is estimated at approximately 2.2% per year. The growth rate is projected to remain at the same rate during the study period. Data for Tuluksak has been estimated by comparison with Akiachak, Akiak and Napaskiak. As in the other villages, the school power requirements has been included as a large consumer load. ELECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 POPULATION 240 301 330 413 518 (1) # of Residential 32 067 8Os«d100—s«i126 Consumers (2) Average kKWH/n0/ 130 250 255 268 282 consuner (3) KWH/year residential 49.9 219.0 244.6 322.5 425.1 consumers (1)x(2)x12/1000 (4) # of small commercial 4 6 7 8 10 consumers (5) average kWH/n0/ 400 375 383 390 398 consumer (6) MWH/year small 19.2 27.0 32.1 37.5 47.8 comm. consumer (4)x(5)x12/1000 (7) # of large consumers 1 2 2 3 3) plus public buildings (8) average kWH/no/cons. 8,000 1,200 1,224 1,287 1,353 (9) Mwh/year LP’s 96 “28.8 29.4 46.3 48.7 (7)x(8)x12/1000 (10) System XWb/year (3)+(6)+(9)+8% Losses , 178.3 296.8 330.6 438.7 563.3 (11) System Load 0.4 0.5 0.5 0.5 0.5 Factor (12) (System Demand ki 50.9 67.8 75.5 100.2 128.6 (10) /8.760/(11) v3 NAPASKIAK Population growth between 1979 and 1989 has averaged approximately 4% per year. The growth rate is projected to remain at the same rate during the study period. ELECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 POPULATION 210 311 364 539 798 (1) # of Residential 43 n 83 123 182 Consumers (2) Average kWH/no/ 175 235 240 252 265 consumer (3) MWH/year residential 90.3 200.2 239.0 372.0 579.2 consumers (1)x(2)x12/1000 (4) # of small commercial 5 16 19 28 41 consumers (5) average kWH/no/ 400 251 256 261 266 consumer (6) MWH/year small 24 48.2 58.4 87.8 131.1 comm. consumer (4)x(5)x12/1000 (7) # of large consumers 1 5 6 9 3 plus public buildings (8) average kWH/mo/cons. 10,000 1,020 1,041 1,094 1,150 (9) Mwh/year LP's 120 61.2 74.9 118.1 = 179.4 (7)x(8)x12/1000 (10) System MWh/year (3)+(6)+(9)+8% Losses 253.0 334.4 = 402.1 624.2» -960.8 (includes losses) (11) System Load 04 05 05 0.5 0.5 (12) (System Demand kW 72.2 76.3 91.8 142.5 219.4 (10)/8.760/(11) 14 OSCARVILLE Population growth between 1979 and 1989 has averaged approximately 2% per year. The growth rate is projected at the same rate during the study period. ELECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 1979 1989 1993 2003 2013 (1) # of Residential 10 12 13 16 20 Consumers (2) Average kWH/n0/ 118 250 255 268 282 consumer (3) MWH/year residential 14.2 36.0 39.9 51.6 66.8 consumers (1)x(2)x12/1000 (4) # of small commercial 1 2 2 3 3 consumers (5) average kWH/no/ 165 375 383 390 398 consumer (6) MWH/year small 2.0 9.0 9.2 14.0 14.3 COmE. consumer 4)x(5)x12/1000 (7) # of large consumers 1 1 1 1 2 plus public buildings (8) average kWH/no/cons. 4,000 1,300 1,326 1,394 1,465 (9) Mwh/year LP's 48 15.6 15.9 16.7 35.2 (7)x(8)x12/1000 (10) System Mwh/year (3)+(6)+(9)+8% Losses 69.3 65.4 70.2 89.0 125.6 (11) System Load 0.4 0.5 0.5 0.5 0.5 Factor (12) (System Demand kW ; 19.8 14.9 16.0 20.3 28.7 (10)/8.760/(11) 15 NAPAKIAK Population growth between 1979 and 1989 has averaged approximately 1.9% per year. The growth rate is projected to remain at this rate during the study period. BLECTRIC POWER AND ENERGY REQUIREMENTS 1979-2013 1979 1989 1993 2003 2013 (1) # of Residential 48 89 96 116 139 Consumers (2) Average kWH/no/ 175 251 256 269 283 consumer (3) MWH/year residential 100.8 = 268.1 += -294.6 373.1 472.5 consumers (1)x(2)x12/1000 (4) # of small commercial 6 B 14 17 20 consumers (5) average kWH/no/ 400 356 363 370 378 consumer (6) MWH/year small 28.8 55.5 61.0 75.6 90.7 COMB. consumer (4)x(5)x12/1000 (7) # of large consumers 1 7 8 9 n plus public buildings (8) average kWH/mo/cons. 15,000 3,180 3,244 3,410 3,584 (9) Hwh/year LP’s 180 =. 267.1 311.4 = 368.3 473.1 (7)x(8)x12/1000 (10) System MWh/year (3)+(6)+(9)+8% Losses 334.4 638.0 «720.4 «= 882.3 1,119.3 (11) System Load 0.4 0.5 0.5 0.5 0.5 Factor (12) (System Demand kW . 145.7, 164.5 201.4 = 255.5 (10) /8.760/(11) 16 NYAC Nyac is basically a mining camp which is only occupied during a 5 month period from late spring through early fall. Energy usage is estimated at 750,000 KWH during this period with a peak demand of 228 kW. This information was estimated from data contained in the "Accepted Draft Report, Nyac Hydroelectric Investigation, Alaska Energy Authority, November 1991." A tabulation of past, and projected village loads and energy requirements can be found in Table 3, titled Electric Power and Energy Requirements for Interconnected Villages. uly) 8T TABLE 3 ELECTRIC POWER AMD ENERGY REQUIREMENTS POR INTER CONNECTED VILLAGES (1) 1979 1989 1993 2003 2013 VILLAGE Population kh KM Peak Population kWil kW Peak Population KWH kW Peak Population KWH KW Peak Population Ka KW Peak Akiachuk ‘ ey 309,700 88 448 811,100 ; 185 483 863,800 197 583 1,191,400 272 704 = 1,356,400 310 Akiak 19 154,900 “4 247 263,700 60 mm 296,100 68 357 408,800 93 464 559,100 128 Kwethluk 457 360,500 103 518 698,800 160 545 731,700 167 617 838,200 191 700° 1,105,900 252 Tuluksak 240 178,300 51 301 296,800 68 330 330,600 vA) 413 438,700 100 518 563,300 129 TOTAL Group A 1,258 1,003,400 286 1514 2,070,400. 473 1632 2,222,200 507 1970 2,877,100 657 2386 3,584,700 818 Hyac ee eee _ ---- 750,000 228 s--- 750,000 228 ---- 750,000 228 ——- 750,000 228 ‘TOTAL Group A + Hyac —- — 1514 2,820,400 701 1632 2,972,200 736 1970 3,627,100 885 2386 = 4,334,700 1047 Napaskiak 210 253,000 rR 3 334,400 6 364 402,100 92 539 624,200 143 798 960,800 219 Oscarville 52 69,300 20 64 65,400 15 70 70,200 16 86 89,000 2 105 125,600 29 Wapakiak 293 334,400 95 353 638 ,000 46 380 720,400 164 458 882,300 201 552 1,119,300 256 TOTAL Group A + Mapaskiak 1,813 1,660,100 474 2,242 3,858,200 938 2,446 4,164,900 1,008 3,053 5,222,600 1,249 3,841 6,540,400 1,550 (1) Summarized from Village Power and Energy Requirements 1979-2013 3.0. ECONOMIC FEASIBILITY ANALYSIS 3.1 INTRODUCTION This section contains an economic comparison summary of the various alternatives investigated for supplying future electrical energy needs for the villages of Akiachak, Akiak, Kwethluk, Tuluksak, and the mining camp of Nyac via a transmission line which interconnects Bethel and the proposed Nyac Hydroelectric plant to the villages. A regional intertie system is also examined which in addition to the above listed villages would supply the future electrical energy needs for the villages of Napaskiak, Oscarville and Napakiak. The study assumes electrical energy requirements for each village will be supplied by either continued diesel generation at each village; or via a transmission line constructed to intertie the villages with a potential hydroelectric development at Nyac and/or a centralized diesel generation facility at Bethel. Usable energy output from the Nyac hydro is estimated at 5000 MWH per year, with a 1400 kW peak output. It is assumed the hydro operates for only 7 months of the year, from mid-May through mid-November. Cost of developing the Nyac hydro project is estimated at $5,400,000' A detailed listing of parameters and assumptions used for this economic analysis is provided in Appendix C. The study does not include the costs associated with renovating or expanding fuel storage facilities in the villages. At present the approximate capacity of fuel storage facilities in the four primary villages examined in this study are: 1) Akiachak - 76,000 gallons; 2) Akiak - 47,000 gallons; 3) Kwethluk - 100,000 gallons; and 4) Tuluksak - 35,000 gallons. f. Data obtained from "Accepted Draft Report, Nyac Hydroelectric Investigation, Alaska Energy Authority, November 1991" 19 The list of main alternatives examined are: Alternative Description Continued Self-Generation 1-A Continued Self Generation at Akiachak, Akiak, Kwethluk and Tuluksak Nyac Hydro Developed and villages of Akiachak, Akiak, Kwethluk, Tuluksak, Nyac and Nyac Hydro intertied to Bethel with: 2-A A-Frame SWGR Transmission Line 3-A Single Pole SWGR Transmission Line 4-A Single Pole 2 wire, 3 phase Transmission Line 5-A Single Pole 3 wire, 3 phase Transmission Line 6-A H-Frame, 3 wire, 3 phase Transmission Line Nyac Hydro Project Not Developed But Akiachak, Akiak, Kwethluk, and Tuluksak, Intertied to Bethel with: T-A A-Frame SWGR Transmission Line 8-A Single Pole SWGR Transmission Line Nyac Hydro Project Not Developed But Akiachak, Akiak, Kwethluk, Tuluksak, and Nyac Intertied to Bethel with: 9-A Single Pole SWGR Transmission Line 10-A Single Pole 3 wire, 3 phase Transmission Line Nyac Hydro Project Developed: 11-A Villages of Akiachak, Akiak, Kwethluk, Tuluksak, Napaskiak, Napakiak, Oscarville, Nyac and Nyac Hydro intertied to Bethel with Single Pole SWGR Transmission Line 12-A Villages of Akiachak, Akiak, Nyac and Nyac Hydro intertied to Bethel with Single Pole 3-wire, 3 phase Transmission Line and villages of Kwethluk, Tuluksak, Napaskiak, Napakiak and Oscarville intertied to transmission grid with Single Pole SWGR Transmission Line. 20 3.2 THE CHOICE OF METHODS AND ALTERNATIVES The various analyses performed represent an attempt to find the most economically feasible development plan. Continued use of diesel generation (Alternative 1-A) in each village has been used as the base for comparison. The economic comparison is presented in the form of present worth values of energy cost for a 22 year period. It is realized that the choice of study period may penalize the Nyac Hydroelectric development as hydro plants generally have life spans of 50 years or more. However, with the uncertainties inherent in forecasting future oil prices and electrical load demands, it has been decided that a 22 year study period will allow a reasonable evaluation. The use of a 22 year period extends the study period a sufficient interval into the future to allow a comparison of energy costs between alternatives, after the investments in transmission interties and the Nyac hydro are completely amortized. Energy cost have been summarized: In tabular form showing average busbar cost® of energy in $/kWH for the study period. (Table 4, Pg. 28) In graphical form showing the busbar cost of energy in $/kWH for the year 1995, 2004, and 2114 for six selected alternatives (Graphs 1 & 1A, pgs. 6&7); the annual busbar cost of energy for six selected alternatives (Graphs 2 & 2A, Pgs. 29 & 30); and the average busbar cost of energy for all twelve alternatives (Graphs 3 & 3A, Pgs. 31 & 32). The graphical exhibits allow easy comparison of the results of various developments. Standard economic analysis parameters as recommended by the AEA have been used in evaluating the alternative development plans. These are summarized below. a) A general inflation rate of 0% per year is applied throughout the 22 year study period. b) The escalation rate for diesel fuel is assumed at 1.35%. c) Sensitivity to financing rates (i.e. the cost of borrowing money) has been investigated by establishing energy costs for interest rates of 5% and 7.6%. The 5% financing rate is representative of REA financing. The 7.6% rate is representative of tax-exempt financing g. Average busbar cost is calculated by dividing the accumulated present worth value of one kWh of energy by 22 years (i.e. the length of the study period). 2 and represents the rate recommended by the AEA. d) A base discount rate of 3.0% is utilized which is consistent with the use of 0% inflation and tax-exempt financing. Sensitivity to the discount rate is determined by varying the base rate by a + 1.0%. e) Sensitivity to the load forecast has been investigated by assuming zero load growth and a high load growth for selected alternatives. High load growth has been calculated assuming a yearly load growth of 2.4% which is a 20% increase over the average historical village load growth of 2%. 3.3 ALTERNATIVE DEVELOPMENT PLANS A summary of each of the alternatives is narrated below. Statistical and graphical comparisons are provided following the narratives on pages 27 through 31. Unless otherwise noted, the discount rate applied to determine the economic viability of the alternative is 3%. Average busbar costs which are listed for each alternative are calculated by dividing the present worth value of one kWH of energy by the length of the study period (i.e. 22 years). A. i -Gener Alternative 1-A This alternative assumes that the electrical energy requirements in the villages of Akiachak, Akiak, Kwethluk and Tuluksak will continue to be supplied by diesel driven generators throughout the study period. Electrical energy rates are almost entirely dependent on diesel fuel costs. Energy costs will continue to rise indefinitely under this alternative. The average busbar energy cost for this alternative is $0.33/kWH. ALTERNATIVE 1-B Same as 1-A, except a discount rate at 2%. Average busbar cost is $0.36/kWH. ALTERNATIVE 1-C Same as 1-A, except discount rate 4%. Average busbar cost is $0.30/kWH. 22 B. N v r vill nd Nys i hel These alternatives assume that the electrical energy requirements in the villages of Akiachak, Akiak, Kwethluk, Tuluksak and the mining camp of Nyac will be supplied from the 1400 kW Nyac Hydroelectric plant during 7 months of the year (mid-May through mid-Nov) and by purchases from Bethel Utilities during the remaining 5 months of the year. These alternatives also assume that Bethel Utilities will purchase all excess non-firm power generated by the Nyac hydro plant. The alternatives 2-A - 5-A represent the various transmission line options investigated for interconnecting the villages with the Nyac Hydroelectric plant and Bethel. Alternative 2-A: A-Frame SWGR Transmission Line This represents the lowest cost alternative for a transmission intertie from Bethel to Nyac and represents a substantial savings as compared to continued self-generation as outlined in Alternative 1-A. This alternative is economically feasible at financing rates of both 5% and 7.6%. Average busbar cost are $0.24/kWH (5%) and $0.29/kWH (7.6%) financing rate. Alternative 3-A: Single Pole SWGR Transmission Line This represents the third lowest cost alternative for a transmission intertie from Bethel to Nyac and also provides a substantial savings as compared to continued self-generation as outlined in Alternative 1-A. The primary advantage of this alternative is that the SWGR Single Pole transmission line is designed such that it can be readily converted to a standard 3-phase transmission line in the future should load and/or development of new generation sources warrant. Average busbar costs are $0.26/kWH (5%) and $0.31/kWH (7.6%) financing rates. This alternative is economically feasible at both financing rates. ALTERNATIVE 3-B Same as 3-A, except a discount rate of 2%. Economically feasible at both 5% ($0.28 kWH) and 7.6% ($0.34/kWH) financing rates. ALTERNATIVE 3-C Same as 3-A, except a discount rate of 4%. Economically feasible at both 5% ($0.24/kWH) and 7.6% ($0.29/kWH), financing rates. ALTERNATIVE 3-D Same as 3-A except annual load growth of approximately 2.4% which represents a 20% increase from the average historical load growth rate of 2%. Economically feasible at both 5% ($0.26/kWH) and 7.6% ($0.30/kWH) financing rates. 23 ALTERNATIVE 3-E Same as 3-A, except assumes no load growth over length of study period. Economically feasible at financing rates of 5% ($0.28/kWH) but at a financing rate of 7.6% the average busbar cost of this alternative is $0.34/kWH which exceeds the cost of self- generation by $0.01/kWH. Alternative 4-A: Single Pole, 2 Wire, 3-Phase Transmission Line This alternative represents the lowest cost 3-Phase transmission line intertie from Bethel to Nyac and would utilize the earth as the third conductor. This alternative represents a saving over self generation of Alternative 1-A only for a financing rate of 5% ($0.28/kWH). At a financing rate of 7.6% the average busbar cost is $0.33/kWH which is identical to self-generation costs. Alternative 5-A: Single Pole, 3-Phase Transmission Line This alternative represents the lowest cost conventional 3-Phase transmission line intertie from Bethel to Nyac. This alternative is economically feasible only at a 5% financing rate ($0.32/kWH). At a 7.6% financing rate the average busbar cost is $0.39/kWH which exceeds the cost of self-generation alternative by $0.06/kWH. Alternative 6-A: H-Frame, 3-Phase Transmission Line This alternative represents the most expensive alternative investigated for constructing a transmission line between Bethel and Nyac. Uneconomical at both financing rates of 5% and 7.6%. Cc. N r Devel vill Interti These alternatives assume that the electrical energy requirements in the villages of Akiachak, Akiak, Kwethluk, Tuluksak would be supplied by purchases from Bethel Utilities. The alternatives 7-A - 8-A represent the various transmission line options investigated for interconnecting the villages with Bethel. Alternative 7-A: A-Frame SWGR Transmission Line This represents the lowest cost alternative for a transmission intertie to interconnect the four villages to Bethel and represents a substantial savings as compared to continued self-generation as outlined in Alternative 1-A. Average 24 busbar energy cost for this alternative is $0.22/kWH (5%) and $0.24/kWH (7.6%) financing rates. This alternative is economically feasible at both financing rates. Alternative 8-A: Single Pole SWGR Transmission Line This alternative also represents a substantial savings as compared to continued self-generation as outlined in Alternative 1-A. The primary advantage of this alternative is that the SWGR Single Pole transmission line is designed such that it can readily be converted to standard 3-phase transmission in the future should load and/or development of new generation sources warrant. Average busbar energy costs for this alternative is $0.24/kWH (5%) and $0.26 (7.6%) financing rates. Average busbar costs for this alternative are approximately 10% greater than for Alternative 7-A. This alternative is economically feasible at both financing rates. D. NyacH Not Dev Four vi nd N These alternatives assume that the electrical energy requirements in the villages of Akiachak, Akiak, Kwethluk, Tuluksak and the mining community of Nyac are supplied by purchases from Bethel Utilities. The alternatives 9-A - 10-A represent the various transmission line options investigated for interconnecting the four villages and Nyac with Bethel. Alternative 9-A: Single Pole, SWGR Transmission Line This is the only SWGR alternative investigated for a transmission intertie to interconnect the four villages and Nyac to Bethel. The primary advantage of this alternative, as stated previously, is that the SWGR Single Pole design will allow conversion to standard 3-phase transmission in the future should load and/or development of new generation sources warrant. Average busbar costs for this alternative are $0.25/kWH (5%) and $0.28/kWH (7.6%) financing rate. This alternative is economically feasible at both financing rates. Alternative 10-A: Single Pole, 3-Phase Transmission Line This alternative represents the lowest cost conventional 3-Phase transmission line for interconnecting the four villages and Nyac to Bethel. This alternative is economically feasible at 5% financing rate ($0.32/kWH) but uneconomical at a 7.6% financing rate ($0.35/kWH) which is $0.02/kKWH greater than self-generation. 25 BE. Regi rti m with N lectri Vv Alternative 11-A: Regional Intertie - Single Pole SWGR The economic analysis discloses this alternative results in the second lowest cost of energy to the village consumer. This alternative assumes that the electrical energy requirements in the villages of Akiachak, Akiak, Kwethluk, Tuluksak and the mining camp of Nyac, Napaskiak, Oscarville and Napakiak will be supplied from the 1400 kW Nyac Hydroelectric plant during 7 months of the year (mid-May through mid-Nov) and by purchases from Bethel Utilities during the remaining 5 months of the year. This alternative was investigated to determine the effect of additional village load on energy costs. The alternative assume that Bethel Utilities will purchase all excess non-firm power generated by the Nyac hydro plant. The alternative also assumes the transmission intertie will be constructed using the Single Pole SWGR transmission line. Average busbar costs are $0.23/kWH (5%) and $0.27/kWH (7.6%) financing rates. This alternative is economically feasible at both financing rates. ALTERNATIVE 11-B Same as 11-A except 2% discount rate. Average busbar costs are $0.25/kWH (5%) and $0.29 (7.6%) financing rates. Economically feasible at both financing rates. . ALTERNATIVE 11-C Same as 11-A except 4% discount rate. Average busbar costs are $0.21/kKWH (5%) and $0.24/kWH (7.6%) financing rate. Economically feasible at both financing rates. ALTERNATIVE 11-D Same as 11-A except annual load growth of 2.4%. Economically feasible at both 5% ($0.23/kWH) and 7.6% ($0.26/kWH). ALTERNATIVE 11-E Same as 11-A but zero load growth assumed. Economically feasible at 5% ($0.25/kWH) and 7.6% ($0.29/kWH). Alternative 12-A: Regional Intertie - Single Pole, 3 Wire, 3 Phase Bethel, Akiachak, Akiak, and Nyac Hydro intertied via a single pole 3 wire, 3 phase transmission line, remaining villages interconnected to transmission grid by Single Pole SWGR. This alternative is economically feasible at 5% ($0.27/kWH) and 7.6% ($0.31/kWH) financing. While this alternative is economically feasible at both financing rates, it is less financially attractive than alternative 11-A. 26 The average busbar cost for all twelve alternatives investigated are listed in Table 4. Note: Busbar costs are not the costs charged to the consumer. Busbar costs are the minimum costs which must be charged to recover fixed and production costs. It is estimated the cost to the consumer would at a minimum, average 5-10% greater than busbar costs. 27 TABLE 4 AVERAGE BUSBAR COST OF ENERGY $/kWH* (1993 Dollars) Financing Alternative 5% 16% 1-A 0.33 - as 1-B 0.36 - . 1-C 0.30 - 2 2-A 0.24 0.29 3-A 0.26 0.31 3-B 0.28 0.34 3-C 0.24 0.29 3-D 0.26 0.30 3-E 0.28 0.34 4-A 0.28 0.33 5-A 0.32 0.39 6-A 0.33 0.39 7-A 0.22 0.24 8-A 0.24 0.26 9-A 0.25 0.28 10-A 0.31 0.35 11-A 0.23 0.27 11-B 0.25 0.29 11-C 0.21 0.24 11-D 0.23 0.26 11-E 0.25 0.29 12-A 0.27 0.31 h. Calculated by dividing accumulated present worth value of one kWH of energy by length of study period (i.e. 22 years). 28 62 BUSBAR COST $/KWH GRAPH 2 BUSBAR COST OF ENERGY $/KWH 5% FINANCING 1993 1995 2000 2005 2010 2014 YEARS =m 1A —-+ 3A -—« 5-A 4 8A —< 11-A -& 12-A | ALTERNATIVES 0€ BUSBAR COST $/KWH BUSBAR COST OF ENERGY $/KWH 7.6% FINANCING GRAPH 2 1993 1995 2000 2005 —= 1A —+ 3A —« 5A —=- 8A —< 11-A -& 12-A ALTERNATIVES TE AVERAGE BUSBAR COST $/KWH AVERAGE BUSBAR ENERGY COST $/KWH 5% FINANCING $0.36 993 DOLLARS GRAPH 3 $0.344 $0.32 $0.30- $0.28- $0.26- $0.24 $0.22 T T T T T T 1A 2A 3A 4A BA 6A ALTERNATIVES Average Busbar Cost Calculated By Dividing Present Worth Value of one KWH of Energy By 22 Years ce $0.40- $0.38- s $0.364 a t $0.34 O Oo cr $0.324 < a 2 $0.30+ a ® $0.28- c uu z $0.26, $0.24 $0.22 AVERAGE BUSBAR ENERGY COST $/KWH 7.6% FINANCING 1993 DOLLARS GRAPH 3A Tt Tt t Tt T T 5A 6A TA 8A oA 10A 11-A 112A ALTERNATIVES Average Busbar Cost Calculated By Dividing Present Worth Value of one KWH of Energy By 22 Years 3.4. CONCLUSIONS In light of the foregoing discussion the following conclusions and recommendations can be formulated. ile Conclusions Alternative 1-A utilizing strictly local village generation should be avoided. Results of the economic analysis demonstrates that for a 5% financing rate this alternative results in the highest energy cost for the villages. Year 2014 busbar cost of Alternative 1-A (5% financing rate) is calculated to exceed the busbar cost of the next most costly alternative by a factor of two. For a 7.6% financing rate, the self-generation is more expensive than all the alternatives except for 5-A and 6-A. The alternatives employing SWGR construction result in the lowest energy costs, and are feasible at all financing rates. The cost of SWGR alternatives utilizing either A-Frame or Single Pole construction are approximately equal.' However, the SWGR transmission line using the single pole long span construction is designed such that it can readily be converted to standard single pole 3-phase transmission in the future should load and/or development of new generation sources warrant. The Single Pole SWGR design combines the advantages of low initial cost and future flexibility. Alternative 5-A employing Single Pole, 3 wire, 3-Phase construction is economical at a financing rate of 5% but uneconomical at a financing rate of 7.6%. At the 5% financing rate the, three phase construction increases average busbar energy cost by approximately 25% as compared to SWGR Single Pole construction. Alternative 11-A investigates the economics of a regional intertie system. This alternative results in the second lowest average busbar energy cost for the village consumer. Only Alternative 7-A results in lower average busbar costs. However, the busbar cost of energy in 2014 for 7-A is approximately $0.20/kWH while the cost of energy for 11-A has decreased to approximately $0.10/kWH or 1/2 the cost of Alternative 7- A. Alternative 11-A would result in the lowest average busbar cost if the study period were extended to 30 years. Year 2014 busbar cost for Alternative 11-A is some 4.5 times less expensive than continued self generation in the villages. i Single Pole SWGR construction costs are approximately 10% greater than A-Frame SWGR construction. 33 A comparison of alternatives that do and do not develop the Nyac hydro project, clearly reveal that the Nyac hydro project should be constructed. Energy cost for the first 20 years of the study for alternatives which include development of the Nyac hydro, are approximately the same as alternatives which construct the same type of transmission line but do not develop the Nyac hydro. However, in the 21st year when the transmission line is fully amortized, the cost of energy for alternatives developing the Nyac hydro drop sharply and energy costs continue to decline in these alternatives during the 22nd year as the hydro is fully amortized. At the end of the 22 year study period (i.e. in 2014), typical cost per kWH for alternatives which include development of the Nyac hydro are in the range of $0.06 - $0.10/kWH. In alternatives that do not include the Nyac hydro the cost of energy in the year 2014 is approximately $0.20/kWH. Varying the historical load growth rate from zero load growth to +20% increase in load growth and the discount rate by + 1% has only a minimal affect on the average busbar cost of energy. 3.5 RECOMMENDATIONS Two alternate electrical energy sources that can replace diesel generation in the villages surrounding Bethel and which have been found to be technically and economically feasible are: (1) the construction of transmission interties; and (2) development of the Nyac hydroelectric project. Careful study of these alternatives suggest the following development plan should be implemented. 1. Construct a transmission line in 1993 utilizing Single Pole SWGR construction’ to intertie the four villages of Akiachak, Akiak, Kwethluk and Tuluksak with Bethel. Construct the Nyac hydroelectric project as quickly as permitting and financing allows. The transmission line should be extended from Tuluksak to interconnect with the Nyac Hydro plant when it becomes operational, which is assumed as 1994 in this study. j. SWGR construction costs using A-Frame or Single Pole construction are approximately equal. However, because Single Pole SWGR is designed such that it can be readily converted to a standard 3-phase transmission line, Single Pole SWGR construction is recommended over the slightly less expensive SWGR A-Frame construction. 34 3. A regional transmission intertie system, which extends the Bethel - Nyac transmission line to the villages of Napaskiak, Oscarville and Napakiak should be constructed.* Such an regional intertie would serve to further reduce the cost of energy in the villages. k. The villages of Napakiak and Oscarville are presently connected to Bethel by power lines. However, extending the transmission line to these two villages would eliminate any necessity for Bethel Utilities to wheel energy from the Nyac hydro over its distribution lines to these two villages. No federal or state regulations presently exist that requires a utility to wheel energy over its distribution lines. 35 10. TABLE OF AUTHORITIES Copper Valley Electric Association, M-31 Steel H-Pile Foundation Design Sheet, December, 1987. Environmental Atlas of Alaska, University of Alaska, 1984 First Annual Statistical Report of the Power Cost Equalization Program, Alaska Power Authority, by Robert E. LeResche, December 15, 1988. Foundation Analysis and Design, by Joseph E. Bowles, McGraw Hill Book Company, 1977. Accepted Draft Report - Nyac Hydroelectric Investigation, by HDR Engineering, Inc., Anchorage, AK, October, 1991. Single Wire Power in Alaska, by Robert W. Retherford, Frank J. Bettine, and Craig J. Thompson, February, 1982. Second Annual Statistical Report of the Power Cost Equalization Porgram, Alaska Energy Authority, by Robert E. LeResche, March, 1990. Solomon Gulch Transmission Line Inspection Report PS11 Substation to PS12 Substation, by Frank Bettine, March, 1988. Reconnaissance Study of the Kisaralik River Hydroelectric Power Potential and Alternate Electric Energy Resources in the Bethel Area, by Frank J. Bettine, Carl H. Steeby, and Dora L. Gropp, February, 1980. Alaska Energy Authority, Memorandum of September 3, 1991, from Richard Emerman, Senior Economist, addressing standard economic analysis parameters. 36 APPENDIX A TECHNICAL DATA APPENDIX A TECHNICAL DATA A.1 CONCEPTUAL DESIGN SUMMARY Conceptual designs have been prepared for both conventional three phase transmission lines, single wire ground return transmission lines and a two wire three phase transmission line utilizing the earth as the third conductor. Five different alternative transmission structures, utilizing 3 different conductor sizes were investigated. Calculations for each alternative were conducted for various combinations of structure heights, class of poles, span lengths and conductor sizes in an effort to develop minimum cost construction parameters for each of the five different structure alternatives. The combination ultimately selected for each structure alternative is shown on the attached Structure Design Summary Sheet. A description for each of the transmission structures alternatives as listed on the Design Summary sheet follows. The structures are categorized by transmission system alternatives such as single wire ground return, 2 wire-3 phase and 3 wire-3 phase. Conceptual drawings for each structure alternative are attached at the end of Appendix A. It should be noted that the conceptual structure designs were prepared for the sole purpose of obtaining cost to input into the economic study. Detailed structure design must still be accomplished once a transmission alternative is selected for construction. A.2_ DESIGN PARAMETERS The following design parameters were used in developing the conceptual designs for the various overhead transmission line structures investigated in this study: Extreme Wind Design Speed - 90 MPH Loading District - NESC Heavy NESC Construction Grade - Grade C Average Depth of Active Layer - 5 feet Transmission Line Maximum Load - 1200 kW Maximum ambient temperature - 90 degrees Fahrenheit Minimum ambient temperature - -40 degrees Fahrenheit . Transmission Line Voltage SIAR RWN A. 69 kV Line to Line for Conventional 3 Phase Transmission Lines A2 B. 40 kv Line to Ground for Single Wire Ground Return Transmission C. 69 kV Line to Ground for 2 wire, Three Phase utilizing the earth as the third conductor. A.3 SINGLE WIRE GROUND RETURN MINIMUM COST TRANSMISSION SYSTEM ingle Wir round Return Transmission of Electrici Single Wire Ground Return (SWGR) transmission can best be described as single phase - single wire transmission of electricity that uses the earth as the return conductor. The SWGR transmission concept suggested here is point-to- point with a carefully established grounding system at each point. The substation established at each grounding point would connect to the village multi-grounded neutral distribution through a step-down transformer. The SWGR system proposed herein would in no way create an operating system with a lesser safety than the "conventional" system now in use throughout Alaska. A SWGR transmission line demonstration project was constructed in 1981 to intertie the village of Napakiak with Bethel. The 8.5 miles of line interconnecting the two communities extends over tundra covered terrain which is underlain with permafrost and dotted by numerous small lakes. This demonstration project has operated reliably for 11 years and has proven that a SWGR transmission system is both economically and technically feasible. The SWGR transmission concept described in this proposal has evolved from a recognition of certain basic facts-of-life concerning electric energy in remote western and interior Alaska, which facts are: A Small electric loads and the geographic distribution of villages presently limit electric energy supply to small, inefficient fossil- fueled generating plants. 2: Conventional three-phase electric transmission/distribution systems to intertie the outlying communities to more efficient generating plants are mostly impractical because high initial costs penalize the transmitted energy rates. 3. A transmission system using a Single Wire Ground Return (SWGR) line promises good electrical performance and a substantially lower initial capital cost and therefore a lower transmitted energy cost than conventional transmission. A3 4. The incentive to develop new, alternative energy sources (such as appropriate scale hydroelectric power in the area) is dependent on an economically viable electric transmission scheme that can feasibly deliver such energy to the villages. The SWGR transmission concept is one which proposes to deal with these realities. While the use of a single energized wire and earth return circuit is unconventional in the sense that applications are not common, it is an accepted system of proven use in several areas of the world. Three phase equipment can also be successfully operated from this system by using phase converters. Lack of road systems, permafrost, and limited accommodations for construction crews throughout most of the region being studied has established certain limitations as to construction techniques which may be utilized. Two alternative transmission structures have been investigated for use in constructing a SWGR transmission line. Both designs have been developed with the intended purpose of minimizing construction costs. The two alternatives investigated are discussed in more detail in the subsequent paragraphs. A-FRAME TRANSMISSION STRUCTURES - The A-Frame transmission structure utilizes the same basic design developed for the Bethel to Napakiak SWGR transmission line and would consist of two 30’ Class 5 poles connected by an angle iron hair pin, a 69 kV post insulator and a full width 30’ Class 5S bog-shoe. The bog-shoe is necessary to prevent overturn in high wind conditions. The conductor selected for use with the A-Frame is 1/0-3/4 AWAC. Maximum span length is 650 feet and is limited by structure overturn resistance in high wind conditions. INGLE POLE TRANSMISSION STR RE, LON A CONSTRUCTION - A single 55’ Class 3 pole would be utilized for this structure. A 69 kv post insulator would be mounted vertically to the top of the pole. The structure would be bolted to a 10x42 HP driven pile foundation. Maximum span length utilizing 1/0-2/5 AWAC conductor is 1300 feet and is limited by the strength of the H-pile. A.4. THREE PHASE CONSTRUCTION Three structure alternatives were investigated for use in constructing Three-phase electric transmission systems to intertie the villages with the Nyac Hydro and Bethel. Three phase construction as expected, is significantly more costly than SWGR construction. The three alternative structure types investigated are discussed below: A4 SINGLE POLE TWO WIRE, THREE PHASE CONSTRUCTION - This type of construction would utilize the earth as the third conductor. As with SWGR construction, this alterative would in no way create an operating system with a lesser safety than the "conventional" system now in use throughout Alaska. A single 50’ Class 2 pole with two horizontal post insulators would be used. The pole would be mounted to a 10x42 HP driven pile foundation. Maximum span length utilizing 1/0-3/4 AWAC is 950 feet and is limited by the strength of the H-pile. SINGLE POLE THREE PHASE - This alternative utilizes a 45’ Class 2 single wood pole with one post insulator mounted vertical at the top of the pole and two horizontal post insulators mounted a distance of 9 feet and 13 feet respectively, below the top conductor. The pole would be attached to a 10x42 HP driven pile foundation. Maximum span length utilizing 1/0-3/4 AWAC would be 700 feet and is limited by conductor separation required to avoid conductor to conductor contact should galloping develop. H-FRAME CONSTRUCTION - This alternative utilizes 60’ Class 2 poles, standard unbraced H-Frame construction with double crossarms, suspension insulators and 12.5 feet conductor separation. Each pole would be attached to 10x57 HP driven pile foundation. Maximum span length with 1/0-2/5 AWAC is 1300 feet and is limited by the strength of the H-pile. A5 STRUCTURE DESIGN SUMMARY Structure Designator Cost$/Mile A-Frame SWGR Single Pole SWGR Single Pole 2 wire, 3 phase Single Pole 3 wire, 3 phase II-Frame 3 wire, 3 phase Foundation Max Span Type Feet Self 650° Supporting W/Bog-Shoe 10X421IP —-1300° 10X421IP 750° 10X421IP 700° 10XS7HIP 1300” Pole Length/ Class? 30°CLS* 55°CL3 50°CL2 4S5'°CL2 60°CL2 1. A detailed breakdown of cost is contained in Appendix B. is) . Douglas Fir unless otherwise noted 3. Limited by strength of 10X421IP 4. Western Red Cedar 5. Limited by strength of 10X42IIP 6. Limited by conductor gallop 7. Limited by strength of 10XS7IIP A6 Structure Weight/Ibs Including HP or Bog-shoe 1470 2650 3200 3000 6400 Conductor Type 1/0-3/4 AWAC 1/0-2/5 AWAC 1/0-3/4 AWAC 1/0-3/4 AWAC 1/0-2/5 AWAC Estimated’ $49,000 $59,000 $82,000 $110,000 $115,000 A.5 H-PILE FOUNDATIONS H-pile foundations were selected for all structure foundations except the self supporting A-Frame. H-pile foundations will be necessary to prevent frost- jacking of structures embedded in the frost susceptible soils found in the Bethel region. The H-pile foundation was selected primarily because similar H-pile foundations have proven to be relatively successful in resisting frost jacking forces in the Copper River Basin region of Alaska. A comparison of soil conditions and meteorological data between the Bethel region and the Copper River Basin region has revealed a notable similarity between the two regions. These similarities are as follows: 1) highly frost susceptible fine grain sands and silts are found through both regions; 2) depth of the seasonal active layer is approximately 5 feet in each region; 3) the freezing index and degree days below zero are similar which should account for the similarity in the depth of the seasonal active layer; 4) both regions lie within the discontinuous permafrost zone; and 5) the permafrost found in both regions is relatively warm permafrost in the range of 30-32 degrees fahrenheit. Because of these similarities it is anticipated that H-pile foundations which have proven relatively successful in the Copper River Basin should prove equally successful in the Bethel region. H-pile foundations will consist of a 25 foot section of either 10x42HP or 10x57HP, driven 21 feet into the earth. Experience in the Copper River Basin has shown H-piling can be driven readily into the warm permafrost encountered in the region. Poles will not be embedded into the earth but will instead be bolted to the 4 feet of H-pile left protruding above the ground-line. Installation of the H-pile in this manner will leave approximately 16 feet of H-pile embedded in soils below the active layer. In general a pile must be embedded at least twice the thickness of the active layer into permafrost or unfrozen consolidated soils in order to prevent frost jacking. A.6 CONDUCTOR Three conductors were evaluated to determine their suitability. These three conductors were 7#8 Alumoweld, 1/0-3/4 AWAC and 1/0-2/5 AWAC. These three conductors were chosen for evaluation because of their high tensile strength and small diameter. A high tensile strength is essential for long span construction, a small diameter is necessary to minimize wind forces on the conductor. The 7#8 Alumoweld conductor was evaluated and discarded because of unacceptable voltage drop and power losses associated with the conductor. Calculations disclosed that both the 1/0-3/4 AWAC and 1/0-2/5 AWAC are acceptable from a line loss, voltage drop and conductor strength basis. Sag and tension calculations determined 1/0-3/4 AWAC, with a breaking strength of approximately 13,800 pounds was satisfactory for span lengths up to A7 1000 feet. For span lengths in excess of 1000 feet 1/0-2/5 AWAC, with an ultimate breaking strength of 19,500 lbs was selected. Because the conductors will be tensioned to a value of approaching 25 percent of ultimate strength at 60 degrees Fahrenheit, vibration dampers will be installed on the conductor to alleviate any potential conductor vibration problems. Electrical Characteristics of each of the three conductors evaluated are listed in the following tables. A voltage of 40 kV line to ground was selected for SWGR transmission and a voltage of 69 kV phase to phase was selected for three phase transmission. Calculations determined these two voltages to be the best suited for the loads and distances involved. 60 HZ Impedances and Shunt Reactance SWGR® -PHASE’ zg Xe Zg Xe Conductor Size (ohms/mi) megohms/mi) (ohms/mi) (megohms/mi) 7#8 Alumoweld 2.5 + j1.6 .24 2.5+ 5.85 2 1/0-3/4 AWAC 85+ j1.5 24 85+ 5.85 2 1/0-2/5 AWAC 80+ j1.5 24 8045.85 “2 Line L ing Limits in Megaw For 5% Voltage Drop at .9 PF. —— SWGR @ 40kV 3-Phase @ 69kV"° 7#8 Alumoweld 25 75 1/0-3/4 AWAC 55 165 1/0-2/5 AWAC 60 180 8. Calculations assume average soil resistivity of 100 ohm meters, 30 feet conductor height. 9. Impedances and shunt reactance values for 2 wire, 3 phase transmission line assumed to be the same as for a conventional 3 phase transmission line. 10. The use of 69kV, three phase construction will require the addition of approximately 1 MVAR of shunt reactors to the line at a cost of $100,000. The cost of the reactor is not included in the Cost Estimates in Appendix B or the economic analysis. Failure to include this cost has an insignificant effect on the validity of the economic analysis. A8 A.7 SINGLE PHASE TO THREE PHASE CONVERSION IN SWGR POWER TRANSMISSION Single Wire Ground Return transmission scheme is an attempt to develop an economical method of electrically interconnecting small communities with low energy demands to a lower cost generation source(s), such as the Nyac Hydroelectric project or Bethel Utilities, where conventional 3-phase lines would be too expensive to construct (see Appendix B). However, small three phase distributions systems such as found in Bethel cannot supply or absorb large blocks of single phase power without excessive overheating occurring in the generator(s) supplying the distribution system. This overheating is caused by unbalance electrical current flowing within the winding of the three phase generators. To eliminate this problem it is necessary to install either rotary or static single phase to three phase conversion equipment. Interconnection between three phase and single phase systems have been made for many years via rotating machinery. The size of these converters ranging from a few kW up to 45 MVA. Static frequency/phase conversion equipment is also available but is presently not an "off the shelf" item for small 1-2 MW applications. A converter set in the 1 megawatt range as required for this intertie project utilizing a combination of rotating equipment and static conversion equipment is estimated to cost approximately $300/kW installed. Conversion losses is estimated at about 4 percent. In the various alternative’s that intertie the Nyac Hydroelectric plant to Bethel and the villages via a SWGR line, the phase converter equipment would be designed to transmit power in two directions. That is, the converter would convert single phase power to three phase power when excess energy from the Nyac hydro plant is being sold to Bethel. Conversely the converter would convert 3 phase power to single phase power when electrical power is purchased from Bethel Utilities by the villages. It is anticipated that existing village distribution systems can readily be re-phased such that the majority of the village load can be supplied from single phase power. This was accomplished at Napakiak in 1981, as part of the SWGR demonstration project, when the village distribution system was easily reconfigured to operate on either single phase or three phase power. The single phase configuration is used when the village is supplied from the SWGR transmission line. The three phase configuration is used when the village is supplied power from its three phase generators during periods the transmission line is out of service. This was accomplished by installation of a transfer switch at the power plant which allows the power plant operator to either supply the AQ village from the SWGR transmission line or the three phase village generators. Where 3-phase is required it can be provide by small rotary phase converter equipment, such as installed at the Napakiak school in 1981 as part of the SWGR demonstration project. A 52.5 kVA rotary phase converter was installed at the Napakiak school to demonstrate the feasibility of utilizing such equipment. This unit operated unattended and reliably for a number of years on a continuous basis converting single phase power to three phase power to supply the needs of the school. It was only recently that the rotary phase converter was "shut down." This occurred when the school district for economic reasons, decided to generate its own electrical power and ceased purchasing power from the Napakiak Corporation. If a SWGR transmission line is constructed to the Nyac hydro, it will be necessary to generate single phase power from the hydro generator to eliminate the necessity and cost of installing additional single phase to three phase conversion equipment. However, to retain maximum future flexibility it is recommended that a three phase generator be purchased and reconnected to operate as a single phase generator. A10 APPENDIX B COST ESTIMATES Bl CONSTRUCTION COST ESTIMATE ALTERNATIVES 2-A -- A-FRAME SWGR TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC A. 87 miles at $49,000/mi = $4,263,000 B. Interface to Kwethluk, Akiachak, = $225 ,000 Akiak, Tuluksak & Nyac @ $45,000 ea. C. Interface to Bethel including = $400 ,000 750 kVA transformer & 1 phase to 3 phase 750 kVA rotary phase converter with building D. 1.5 MVA step-up transforemer at = $60,000 Nyac Hydro E. Remote control Nyac Hydro from Bethel = $100,000 F. R.0.W. Clearing 25 mi. @ $1000/mi. = $25,000 TOTAL COST = $5,073,000 3-A -- SINGLE POLE SWGR TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC A. 87 miles at $59,000/mi = $5,133,000 B. Interface to Kwethluk, Akiachak, = $225,000 Akiak, Tuluksak & Nyac @ $45,000 ea. C. Interface to Bethel including = $400,000 750 kVA transformer & 1 phase to 3 phase 750 kVA rotary phase converter with building D. 1.5 MVA step-up transforemer at = $60,000 Nyac Hydro E. Remote control Nyac Hydro from Bethel = $100,000 FP. R.O.W. Clearing 25 mi. @ $1000/ni. = $25,000 TOTAL COST = $5,943,000 B2 4-A -- SINGLE POLE, 2 WIRE, 3PHASE TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC A. 68 miles at $82,000/mi = $5,576,000 19 miles of Single Pole SWGR = $1,121,000 $59,000/mi to serve Kwethluk and Tuluksak B. Interface to Kwethluk, Tuluksak = $135,000 & Nyac @ $45,000 ea. Interface to Akiachak & Akiak = $70,000 at $35,000 ea. C. Interface to Bethel including = $150,000 750 KVA transformer D. 1.5 HVA step-up transforemer at = $60,000 Nyac Hydro E. Remote control Nyac Hydro from Bethel = $100,000 F. R.O.W. Clearing 25 mi. @ $1000/ni. = $25,000 TOTAL COST = $7,237,000 5-A -- SINGLE POLE, 3 WIRE, 3 PHASE TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC A. 68 miles at $110,000/mi = $7,480,000 19 miles of Single Pole, 2 wire, = $1,558,000 3 phase @ $82,000/mi to serve Kvethluk and Tuluksak B. Interface to Kwethluk, Tuluksak = $90,000 & Nyac @ $30,000 ea. Interface to Akiachak & Akiak = $70,000 at $35,000 ea. C. Interface to Bethel including = $150,000 750 kVA transformer D. 1.5 MVA step-up transformer at = $60,000 Nyac Hydro E. Remote control Nyac Hydro from Bethel = $100,000 F. R.O.W. Clearing 25 mi. @ $1000/mi. = $25,000 TOTAL COST = $9,533,000 B3 6-A -- H-FRAME, 3 WIRE, 3 PHASE TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC A. 68 miles at $115,000/ni = $7,820,000 19 miles of Single Pole, 2 wire, = $1,558 ,000 3 phase @ $82,000/mi to serve Kwethluk and Tuluksak B. Interface to Kwethluk, Tuluksak = $90,000 & Nyac @ $30,000 ea. Interface to Akiachak & Akiak = $70,000 at $35,000 ea. C. Interface to Bethel including = $150,000 750 kVA transformer D. 1.5 MVA step-up transforemer at = $60,000 Nyac Hydro E. Remote control Nyac Hydro from Bethel = $100,000 PF. R.O.W. Clearing 25 mi. @ $1000/mi. = $25,000 TOTAL COST = $9,873,000 7-A ~~ A-FRAME SWGR TRANSMISSION LINE, BETHEL TO TULUKSAK NO HYDRO A. 52 miles at $49,000/mi = $2,548,000 B. Interface to Kwethluk, Akiachak, = $180,000 Akiak, Tuluksak @ $45,000 ea. C. Interface to Bethel including = $325,000 750 kVA transformer & 3 phase to 1 phase 750 kVA rotary phase converter with building D. R.O.W. Clearing 12.5 mi. @ $1000/mi. = $12,500 TOTAL COST = $3,065,500 8-A -- SINGLE POLE SWGR TRANSMISSION LINE, BETHEL TO TULUKSAK NO HYDRO A. 52 miles at $59,000/ni = $3,068 ,000 B. Interface to Kwethluk, Akiachak, = $180,000 Akiak, Tuluksak @ $45,000 ea. C. Interface to Bethel including = $325,000 750 kVA transformer & 3 phase to 1 phase 750 kVA rotary phase converter with building D. R.O.W. Clearing 12.5 mi. @ $1000/mi. = $12,500 TOTAL COST : $3,585,500 B4 9-A -- SINGLE POLE SWGR TRANSMISSION LINE, BETHEL TO NYAC A. 87 miles at $59,000/mi = $5,133,000 B. Interface to Kwethluk, Akiachak, = $225,000 Akiak, Tuluksak & Nyac @ $45,000 ea. C. Interface to Bethel including = $400,000 750 kVA transformer & 1 phase to 3 phase 750 kVA rotary phase converter with building D. R.0.W. Clearing 25 mi. @ $1000/mi. = $25,000 TOTAL COST = $5,783,000 10-A -- SINGLE POLE, 3 WIRE, 3 PHASE TRANSMISSION LINE, BETHEL TO NYAC A. 68 miles at $110,000/mi = $7,480,000 19 miles of Single Pole, 2 wire, = $1,558,000 3 phase @ $82,000/mi to serve Kwethluk and Tuluksak B. Interface to Kwethluk, Tuluksak = $90,000 & Nyac @ $30,000 ea. Interface to Akiachak & Akiak = $70,000 at $35,000 ea. C. Interface to Bethel including = $150,000 750 kVA transformer D. R.O.W. Clearing 25 mi. @ $1000/mi. = $25,000 TOTAL COST = $9,373,000 11-A -- SINGLE POLE SWGR TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC + INTERTIE WITH NAPASKIAK, OSCARVILLE & NAPAKIAK A. 100 miles at $59,000/mi = $5,900,000 B. Interface to Kwethluk, Akiachak, = $360,000 Akiak, Tuluksak, Nyac, Napaskiak, Oscarville, Napakiak @ $45,000 ea. C. Interface to Bethel including = $500,000 1000 kVA transformer & 1 phase to 3 phase 1000 kVA rotary phase converter with building D. 1.5 MVA step-up transformer at = $60,000 Nyac Hydro E. Remote control Nyac Hydro from Bethel = $100,000 F. R.O.W. Clearing 25 mi. @ $1000/mi. = $25,000 TOTAL COST = $6,945,000 B5 12-A -- SINGLE POLE, 3 WIRE, 3-PHASE TRANSMISSION LINE, BETHEL TO NYAC WITH HYDRO DEVELOPED AT NYAC + INTERTIE WITH > NAPASKIAK, OSCARVILLE & NAPAKIAK . 68 miles at $110,000/ni . 32 miles of Single Pole, SWGR at $59,000/mi to service Kwethluk, Tuluksak, Nyac, Napaskiak, Oscarville & Napakiak . Interface to Akiachak & Akiak @ $35,000 . Interface to Kwethluk, Tuluksak, Nyac, Napaskiak, Oscarville, Napakiak @ $45,000 ea. . Interface to Bethel including 1000 kVA transformer . 1,5 MVA step-up transformer at Nyac Hydro . Remote control Nyac Hydro from Bethel . R.0.W. Clearing 25 mi. @ $1000/ni. TOTAL COST nou " " " $7,480,000 $1,888,000 $70,000 $270,000 $180,000 $60,000 $100,000 $25,000 $10,073,000 B6é TRANSMISSION LINE COST ESTIMATES A-FRAME SWGR AFRAME AVG/SPAN = 650 STRU/MI = 8.1 #COND = 1 QTY /STRU MATL ~— LABOR M&L TOTAL/STRU TOT MATL/MI TOT LABOR/MI TOT/MILE POLES 3 $280 $300 $580 $1,740 $6,823 $7,311 $14,134 INSULATORS 1 $100 $25 $125 $125 $812 $203 $1,015 HPILES 0 $600 $500 $1,100 $0 $0 $0 $0 HARDWARE 1 $200 $100 $300 $300 $1,625 $812 $2,437 CONDUCTOR 650 $0.25 $1.00 $1.25 $813 $1,320 $5,280 $6,600 KISC 1 $100 $100 $200 $200 $812 $812 $1,625 TOTAL $2,978 $11,393 $14,418 $25,811 MOB&DEMOB+SUBSISTENCE $15,000 ENGR/SURVEY $1,500 SUBTOTAL $42,311 CONTENGENCIES $6,347 AT 15% TOTAL $/HI $48 ,658 SINGLE POLE SWGR SPSW AVG/SPAN = 1300 STRU/HI = 4.1 # COND = 1 QTY /STRU MATL —LABOR M&L TOTAL/STRU TOT MATL/MI TOT LABOR/MI TOT/MILE POLES 1 $900 $1,600 $2,500 $2,500 $3,655 $6,498 $10,154 INSULATORS 1 $250 $100 $350 $350 $1,015 $406 $1,422 HPILES 1 $600 $500 $1,100 $1,100 $2,437 $2,031 $4,468 HARDWARE 1 $100 $100 $200 $200 $406 $406 $812 CONDUCTOR 1300 = $0.25 $1.00 = $1.25 $1,625 $1,320 $5,280 $6,600 MISC 1 $150 $100 $250 $250 $609 $406 $1,015 TOTAL $5,775 $9,443 $15,028 $24,471 MOB&DEMOB+SUBSISTENCE $25,000 ENGR/SURVEY $1,500 SUBTOTAL $50,971 CONTENGENCIES $7,646 AT 153 TOTAL $/HI $58 ,616 B7 SINLGE POLE, 2 WIRE, 3 PHASE SP2W AVG/SPAN = 950 STRU/HI = 5.6 # COND = 2 QTY /STRU MATL = LABOR M&L TOTAL/STRU TOT MATL/MI TOT LABOR/MI TOT/MILE POLES 1 $900 $1,600 $2,500 $2,500 $5,002 $8,893 $13,895 INSULATORS 2 $250 = $100» «$350 $700 $2,779 $1,112 $3,891 HPILES 1 $600 $500 $1,100 $1,100 $3,335 $2,779 $6,114 HARDWARE 1 $200 = $100-~=—-$300 $300 $1,112 $556 $1,667 CONDUCTOR 1900 $0.25 1.00 1.25 $2,375 $2,640 $10,560 $13,200 HISC 1 $150 = $100-~—«$250 $250 $834 $556 $1,389 TOTAL $6,975 $15,701 $24,455 $40,156 MOB&DEXOB+SUBSISTENCE $30,000 ENGR/SURVEY $1,500 SUBTOTAL $71,656 CONTENGENCIES $10,748 AT 15% TOTAL $/HI $82,404 SINLGE POLE, 3 WIRE, 3 PHASE SP3P AVG/SPAN= 700 STRU/MI = 7.5 # COND. = 3 QTY /STRU MATL —_ LABOR M&L TOTAL/STRU TOT MATL/MI TOT LABOR/MI TOT/MILE POLES 1 $900 $1,600 $2,500 $2,500 $6,789 $12,069 $18,857 INSULATORS 3 $250 $100 $350 $1,050 $5,657 $2,263 $7,920 HPILES 1 $600 $500 $1,100 $1,100 $4,526 $3,771 $8,297 HARDWARE 1 $200 $100 $300 $300 $1,509 $754 $2,263 CONDUCTOR 2100 = $0.25 = $1.00» $1.25 $2,625 $3,960 $15,840 $19,800 MISC 1 $150 $100 $250 $250 $1,131 $754 $1,886 TOTAL $7,575 $23,571 $35,451 $59,023 MOB&DEMOB+SUBSISTENCE $35,000 ENGR/SURVEY $1,500 SUBTOTAL $95,523 CONTENGENCIES $14,328 AT 15% TOTAL $/HI $109,851 H-FRAME, 3 PHASE HFRAME AVG/SPAN = 1300 STRU/HI = 4.1 # COND. = 3 QTY/STRU MATL = LABOR) = s&L_~=—STOTAL/STRU TOT MATL/MI TOT LABOR/HI TOT/MILE POLES 2 $900 $1,600 $2,500 $5,000 $7,311 $12,997 $20,308 INSULATORS 3. $100 = $50—Ss«$150 $450 $1,218 $609 $1,828 HPILES 2 $800 = $700--$1,500 $3,000 $6,498 $5,686 $12,185 HARDWARE 1 $400 © §300-~—-$700 $700 $1,625 $1,218 $2,843 CONDUCTOR 3900 $0.25 1.00 $1.25 $4,875 $3 ,960 $15,840 $19,800 HISC 1 $150 += §100-S «$250 $250 $609 $406 $1,015 TOTAL $14,025 $21,222 $36,757 $57,978 MOB&DEKOB+ SUBSISTENCE $40,000 ENGR/SURVEY $1,500 SUBTOTAL $99,478 CONTENGENCIES $14,922 AT 153 TOTAL $/HI $114,400 B9 APPENDIX C ECONOMIC EVALUATION Ci APPENDIX C ECONOMIC EVALUATION C.1 DESCRIPTION OF ALTERNATIVES Alternative Description Continued Self-Generation 1-A Continued Self Generation at Akiachak, Akiak, Kwethluk and Tuluksak Nyac Hydro Developed and villages of Akiachak, Akiak, Kwethluk, Tuluksak, Nyac and Nyac Hydro intertied to Bethel with: 2-A A-Frame SWGR Transmission Line 3-A Single Pole SWGR Transmission Line 4-A Single Pole 2 wire, 3 phase Transmission Line 5-A Single Pole 3 wire, 3 phase Transmission Line 6-A H-Frame, 3 wire, 3 phase Transmission Line Nyac Hydro Project Not Developed But Akiachak, Akiak, Kwethluk, and Tuluksak, Intertied to Bethel with: T-A A-Frame SWGR Transmission Line 8-A Single Pole SWGR Transmission Line Nyac Hydro Project Not Developed But Akiachak, Akiak, Kwethluk, Tuluksak, and Nyac Intertied to Bethel with: 9-A Single Pole SWGR Transmission Line 10-A Single Pole 3 wire, 3 phase Transmission Line Nyac Hydro Project Developed: 11-A Villages of Akiachak, Akiak, Kwethluk, Tuluksak, Napaskiak, Napakiak, Oscarville, Nyac and Nyac Hydro intertied to Bethel with Single Pole SWGR Transmission Line 12-A Villages of Akiachak, Akiak, Nyac and Nyac Hydro intertied to Bethel with Single Pole, 3 wire, 3 phase Transmission Line. Kwethluk, Tuluksak, Napaskiak, Oscarville, Napakiak intertied to transmission grid by Single Pole SWGR Transmission Line. C2 C.2 PARAMETERS USED FOR ECONOMIC EVALUATION A. POWE EMAND A ENERGY RE IREMENT The load data developed in Section 2 has been utilized. Distribution losses within each village is assumed at 8 percent, therefore, energy sold in each village is assumed at 92 percent of purchased or generated energy. The listed demands have been used as coincidental demands. Sensitivity to load growth projections has been determined by assuming zero load growth and a high load growth for selected alternatives. High load growth has been calculated by assuming a 2.4% load growth which is a 20% increase over the average historical village load growth of approximately 2%. B. GENERATION SOURCES AND SUPPLIES The study assumes electrical energy requirements for each will be supplied through either: 1. Continued diesel generation at each village; or 2. For alternatives investigating an intertied system by purchasing power from Bethel Utilities and/or from the Nyac Hydroelectric plant. Usable energy output from the Nyac hydro is estimated at 5000 MWH per year, with a 1400 kW peak output. It is assumed the hydro operates for only 7 months of the year, from mid-May through mid-November. Cost of developing the Nyac hydro is estimated at $5,400,000. (Information obtained from Draft Report, Nyac Hydro Electric Project Potential Study, October, 1991) It is assumed sufficient diesel generation capacity will be maintained in each village to meet generation requirements in the event of a transmission line outages. CS R D POWER AND ENERGY db Villages can purchase power and energy from Bethel Utilities at a cost of $22.18 per kW demand plus $0.1103 per kWH for energy charge. (Cost obtained from Bethel Utilities three phase customer rate schedule and Cost of Power Adjustment schedule.) Demand costs are escalated at the general inflation rate. 80% of energy charge is escalated at the fuel escalation rate, the remaining 20% at the general inflation rate. eS) D. NON-FIRM POWER SA Assumed Bethel Utilities will purchase all excess Nyac hydro energy at a rate of $0.1015 per KWH. (Cost obtained from Bethel Utilities non-firm tariff rate.) Escalated a fuel inflation rate. E. SW LINE L E Line losses incurred on the SWGR Intertied System are estimated at 10% which includes losses in the 3 phase to one phase rotary/static phase converter. F. THREE PHASE LINE LOSSES Line losses for three phase and 2 wire three phase using the earth as the third conductor are estimated at 4 percent. G. BASE YEAR A base year of 1993 is used for the study. It is assumed a transmission line interconnecting the villages would be constructed in 1992-93 winter/spring season and would be operational by late spring 1993. The Nyac hydroelectric plant is estimated to become operational in the summer of 1994 and would supply 2500 MWH of energy during 1994 and full energy output of 5000 MWH beginning in 1995. H. ESCALATION RATES 1. Fuel Costs An escalation rate of 1.35%, is applied to the study period. This fuel escalation factor was recommended by the Alaska Engergy Authority. 2. All Other Costs A general inflation rate of 0% is applied to all other cost over the study period. The AEA typically recommends a 0% inflation rate for long term economic studies. I. FUEL COSTS The average 1993 cost per gallon for diesel fuel in the villages is assumed at $1.25 per gallon, which is the approximate price Bethel Utilities was paying for diesel fuel in January 1992. Cost of diesel fuel is escalated at the fuel inflation rate. c4 J. GENERATION FUEL EFFICIENCIES A diesel generation efficiency of 7 kWH/gal is used for the villages. This was calculated from data obtained from the First and Second Annual Statistical Report of the Power Cost Equalization Program, 1989, 1990. K. DIESEL OPERATIONS, MAINTENANCE AND PLANT COST A value of 1993 cost of $0.20/kWH is used to cover the cost of diesel maintenance and replacement costs. This value was calculated from data contained in the First and Second Annual Statistical Report of the Power Cost Equalization Program, 1989, 1990. Escalated at the general inflation rate. L. NYAC HYDRO OPERATION AND MAINTENANCE COST Estimated at $80,000 in 1993, escalated at the general inflation rate, which covers the cost of a part-time operator and maintenance. M. DEBT SERVICE Debt service on investments has been calculated using a 7.6% cost of debt, which reflects the nominal tax exempt rate for low risk bonds and 5% which is representative of REA financing. The 7.6 % financing rate was recommended by the AEA. An amortization period of 22 years is used in all alternatives. N. DISCOUNT RATE For tax-exempt financing the AEA recommends a base discount rate of 3.0%. Rates for sensitivity tests are 2.0% and 4.0%. Discount rates are used in the various alternatives to determine present worth values. These are real discount rates consistent with the use of 0% inflation rate. cS C.3 EXPLANATION OF COMPUTER PRINTOUTS The following is a line by line explanation of the enclosed computer printouts. a G. H. C. 3% D P N Load Demand . Demand - kW . Energy . Transmission Line Loss in MWH . Total Energy Requirements MWH Available from Nyac Hydro . Village Hydro Use Surplus Hydro Purchase from Bethel Utilities . Investment Costs ($1000) . Transmission Line . Nyac Hydro Total Investment ($1000) Fixed Costs ($1000) EXPLANATION Projected Peak Load in kW Projected Energy Requirements in MWH Estimated Line Losses in MWH. Calculated as percentage of energy. Estimated at 10% SWGR lines & 4% for three phase lines. Sum of Project Energy Requirements and Line Losses. Estimated at 5000 MWH per year Calculated as 60% X (Total Energy Requirements - Nyac Energy Requirements) +Nyac Energy Requirements. (Assume all Nyac Energy Requirements will be supplied from hydro in those alternatives where hydro is developed. Surplus Nyac Hydro Energy Available for Sale to Bethel Utilities. (MWH available from Nyac Hydro - Village Hydro use) Total Energy Requirements - Village hydro use. Cost of Transmission Line in 1993 dollars. Assumes transmission line constructed in 1993. Cost of Nyac Hydro plant in 1993 dollars. Assumes Nyac hydro constructed in 1993 & 1994. Sum of Transmission & hydro investment for each year. Ccé A. Debt Service Including Construction Interest at 7.6% B. Insurance C. Total Fixed Cost 4. Production Costs ($1000) A. Operations and Maintenance 1. Transmission 2. Hydro 3. Administrative B. Self-Generation C. Purchases from Bethel Utilities ($1000) D. Total Production Costs ($1000) 5. Annual Costs ($1000) A. Credit for Sales to Bethel Utilities ($1000) Debt Service on Investment. Debt service includes 7.6% Interest during construction. Debt Service is calculated using 5% & 7.6% Cost of Money. Calculated at $8/$1000 of Nyac Hydro Investment Cost. No Insurance on Transmission Line. The Sum of Debt Service at 5% & 7.6% Plus Cost of Insurance. Estimated at $500/mile for the transmission line + $20,000/year for Maintenance of Rotary Phase Converter if Applicable. Yearly Maintenance + Cost of a Part-time Operator. Estimated at $80,000 for full year of operation. Administrative Costs Associated with Operating Nyac Hydro and Transmission Line. Covers Cost of Self-Generation at villages for 1/2 year while transmission line is under construction. Cost of Purchasing Power and Energy from Bethel Utilities. (MWH purchased from Bethel Utilities x Purchased power and energy costs) Sum of Operation & Maintenance Costs and Purchases from Bethel Utilities. Sum of Total Fixed Costs, plus Total Production Costs, for 5% and 7.6% Debt Service. Dollar Value of Nyac Hydro, Non- firm power sales to Bethel Utilities. (Surplus MWH Hydro Sales to Bethel x non-firm tariff rate.) C7 B. Total Annual Costs ($1000) C. Present Worth ($1000) Total Annual Costs D. Accumulated Present ($1000) Worth Total Annual 6. Energy Costs $/kWh A. Energy Sold MWHs B. Cost of Energy $/kWH C. Present Worth Energy $/kWh D. Accumulated Present Worth of Energy $/kWH Annual Costs less Dollar Value of Sales to Bethel Utilities, for 5% and 7.6% Debt Service. Present Worth of Total Annucal Costs for 5% and 7.6% Debt Service. Present Worth calculations use a 3.0% discount rate unless noted otherwise. Accumulated Present Worth of Total Annual Costs, 5% and 7.6% Debt Service. Number of MWH’s sold to Consumers. Calculated at 92% of Energy - MWH (i.e. line 1B). Total Annual Costs divided by MWH’s sold, for 5% and 7.6% Debt Service. Present Worth Cost of Energy $/KWh, at 5% - 7.6% Debt Service. Present Worth calculations use a 3% discount rate unless otherwise noted. Accumulated Cost of Energy in $/kWH, 5%-7.6% debt service. cs 60 1, LOAD DEMAND A DEMAND - KWH. 8 ENERGY - MWH 2 PRODUGTION COSTS ($1000) O&M $/KWH O&M GOST ($1000) B. DIESEL FUEL $/GAL FUEL COST ($1000, G. ANNUAL GOSTS ($1009, 0. PRESENT WORTH ($1000) ANNUAL COSTS E ACCUMULATED PREGENT ($1000, WORTH ANNUAL COST 3. ENERGY GOST $/KWH A. ENERGY SOLD MWH B. COST ENERGY S/KWH C. PRESENT WORTH ENERGY $/KWH 8. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 1903 607.0 e222 $0 200 $4444 $).260 $200.6 $041.3 $e413 $241.3 2044.4 0.411 $0411 $0411 1004 822.0 2287.7 $0,200 $487.5 $1,207 $414.0 $871.0 $040.2 $1.087.4 2104.7 $0414 $0.402 $o.e14 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK & TULUKSAK - SELF GENERATION (ALTERNATIVE 1-8) 1905 937.0 2363.2 $0.200 $470.6 $1204 $431.6 $002 3 $260.5 $2.937.0 2104.0 $0.417 $0,303, $1,208 1996 8620 2187 $0.200 $463.7 $1,301 $440.0 $033.4 $e04.2 $3,302.1 2206.2 90.410 $0.304 $1.500 1907 607.0 2484.2 ‘$0.200 $496.8 $1310 $408.0 $004.0 $657.3 2286.4 $0.422 $0.375 1998 582.0 2840.7 $0.200 $508.9 $1,337 $496.9 $006.8 $5,.100.2 2346.7 $0.425 $0.307 $2332 1909 697.0 26161 $0,200 $623.0 $1,366 $600.1 $1,020.1 $001.0 $5,071.14 2406.9 $0.428 $0.368 2000 e120 2080.6 $0.200 $936.1 $1.373 $926.8 $1,061.9 $902.4 2406.2 $0.431 $0.350 $3.040 2001 627.0 2746.1 $0.200 $540.2 $302 $645.0 $1,096.1 $045 $7.608.0 2620.4 $0.433 $0342 2002 042.0 2811.6 $0.200 $502 3 $1.410 $906.5 $1,1268 $806.1 $3,504.2 2686.7 $0.436 $0.334 $3.717 2003 067.0 2077.1 $0200 $676.4 $420 $587.5 $1,1020 $005.3 $0,420.65 2646.0 $0.430 $0.327 $4044 673.1 2047.0 $0.200 $86.8 $1.449 $010.1 $1,100.68 $208.8 $10,206.1 e720 $0.442 $0.320 $4383 e892 s018.6 $0 200 $603.7 $1408 $033.1 $1,230.09 $007.5 $11,163.7 2777.1 90.446 $0312 $4.676 705.3 3080.4 $0.200 $017.0 $1.498 $068.7 $1,274.68 ‘$208.0 $12,031.6 2042.2 $0.448 $0.305 2007 721.4 3160.1 $0,200 $632.0 $1508 $e808 Hs120 $12,200.68 2007.3, 737.5 3230.9 $0.200 $046.2 $1,620 $708.5 $1,351.7 2070.4 $0.455 $0.202 $o.s72 753.6 3301.7 $0.200 $660.3 $1540 $730.7 $1,301.0 se08.8 $14,634.0 3037.6 $0468 $0,206 2010 7007 33724 $0.200 $074.5 $1.570 $766.4 $1,430.90 $06.7 $15,400.7 3102.6 $0.451 $0.270 $8.136 785.8 3443.2 $0. 200 seen. $1501 $782.7 $1.471.3 $204.3 $16,264.0 3107.7 $0.404 $0.273 2012 e019 3613.0 $0.200 $702.8 $1,613 $800.6 $1.91204 $e02.5 $17,226.4 3232.8 $0.408 $0.267 $0.070 2013 818.0 3684.7 $0,200 $716.0 $1.036 $637.0 $1,654.0 $260.4 $18,080.6 3207.0 $0471 $0,201 2014 833.5 3082.8 $0.200 $7306 $1.057 $804.4 $1,506.0 $e57 4 $13,044.2 3300.6 $0.475 $0.255 $7.192 ULW 1, LOAD DEMAND A DEMAND - KWH. B ENERGY - MWH 2 PRODUGTION COSTS ($1009, ‘A ORM S/KWH ‘O&M GOST ($1000) B. DIESEL FUEL $/GAL_ FUEL COST ($1000) G. ANNUAL COSTS ($1000) O. PRESENT WORTH ($1009, ANNUAL COSTS ACCUMULATED PRESENT ($1000) WORTH ANNUAL COST 3. ENERGY COST $/KWH A. ENERGY GOLD MWH. B. COST ENERGY S/KWH G. PRESENT WORTH ENERGY $/KWH 6. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 607.0 22222 $0,200 $444.4 $1,260 $390.8 $041.3 $041.3 $841.3 2044.4 $0.41 $0411 $0411 19004 6220 2287.7 $0.200 $487.5, $1.207 $414.0 $971.5 $964.5 $1,005.7 2104.7 $0.414 $0.408 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK & TULUKSAK - SELF GENERATION (ALTERNATIVE 1:8, 2% DISCOUNT RATE) 1995 637.0 2363.2 $0.200 $4708 $1,294 $431.6 ‘$002 3 2104.9 $0.417 $0401 $1218 1990 662.0 24187 $0.200 $463.7 $1.301 $4400 $033.4 $8705 $3,442.5 2206.2 $0410 $0,305 $1,013 1007 667.0 24042 $0.200 $406.6 $1310 $408.0 $064.0 $e014 2006.4 $0.422 $0 300 1998 682.0 2540.7 $0.200 $600.0 $1.337 $488.0 $006.8 $002.8 $5.236.7 23457 $0.426 $0.335 $2338 1900 697.0 2616.1 $0.200 $623.0 $1.365 $506.1 $1,020.1 gorse $0.150.6 2405.0 $0.428 ‘$0,380 2000 e120 2080.6 $0.200 $636.1 $1.373 $926.8 $1,061.9 $025.5 $7,076.0 2406.2 $0.431 $0.375 $3.143 627.0 2746.1 ‘$0,200 $540.2 $1302 $546.9 $1,096.1 $024.7 2826.4 $0.433 $0.370 $3513 2002 e420 2811.8 $0.200 $902.3 $1.410 $606.5 $1,126.8 $045.5 $3,064.3 2686.7 $0.436 $0,305 $3676 657.0 2877.1 $0 200 $876.4 $7,420 $875 $1,1620 $054.0 2640.9 $0,430 ‘$0 300 2004 073.1 2047.0 $0.200 $680.6 $1.440 $0101 $1,190.6 $004.8 $10,873.1 2712.0 $0.442 $0.358 $4594 680.2 30186 $0,200 $603.7 $1.408 $633.1 $1,230.09 $0753 $11,648.4 2777.4 $0.445 $0351 705.3 3080.4 $0.200 $017.0 $1,488 $066.7 $1,274.68 $006 3 $12,633.7 2640.2 $0.448 $0.347 $6.202 2007 721.4 3100.1 ‘$0,200 $632.0 $1508 $080.8 $1.5120 $095.0 $13.628.7 2007.3 $0.462 $0.342 737.5 3230.9 $0.200 $046.2 $1,520 $706.5 $1,361.7 $1,004.3 $14,833. 20724 $0.455 $0.338 $8.072 753.6 3301.7 ‘$0,200 $660.3 $1,540 $730.7 $1,301.0 $1,013.3 $16,640.3 3037.6 90.468 $0,334 2010 700.7 33724 $0.200 $074.5 $1,670 $750.4 $1,430.90 $1,021.09 $19,608.1 3102.8 $0.401 $0.320 $0.635 2011 788.8 3443.2 $0.200 $eee.6 $1.501 $7827 $1.471.3 $1.030.2 $17,808.3 3167.7 $0404 $0.326 2012 801.0 3613.9 $0.200 $702.8 $1,613 $800.6 $5124 $1,038.1 $13,036.5 3232.8 $0408 $0.321 $7,231 2013 8180 36847 $0,200 $7180 $1.636 $637.0 $1,664.0 $1,0465.8 sio.ce22 3207.0 $0.471 $0.317 2014 833.5 3052.8 $0.200 $7306 $1.657 $004.4 $1,506.0 $1,052.3 $21,034.68 3360.6 $0.475 $0.313 $7.912 LE 1. LOAD DEMAND A. DEMAND - KWH B. ENERGY - MWH 2 PRODUCTION COSTS ($1000) A O&M $/KWH O&M GOST ($1000) B. DIESEL FUEL $/GAL FUEL GOST ($1000) G ANNUAL COSTS ($1009) D. PRESENT WORTH ($1000) ANNUAL COSTS & ACCUMULATED PRESENT ($100, WORTH ANNUAL GOST 3. ENERGY COST $/KWH A ENERGY SOLD MWH 8. COST ENERGY $/KWH G. PRESENT WORTH ENERGY $/KWH 6. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 1903 607.0 2022.2 ‘$0,200 $444.4 $1250 $306.8 $e41.3 $ea13 $241.3 2044.4 $0411 $0411 $0.411 1004 522.0 2287.7 $0,200 $487.5 $1,207 $414.0 $938.0 $1,670.3 2104.7 $0.414 $0.810 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK & TULUKSAK - SELF GENERATION 1995 637.0 2363.2 $0.200 $4706 $1,204 4310 $0023 $934.2 $2.513.5 2104.0 $0.417 $0.335 $1,195 (ALTERNATIVE 1-C, 4% DISCOUNT RATE) 19961907 1998 1990 8620 $67.0 582.0 697.0 26187 24862 © 2840.7 2811 $0.200 $0200 $0200 $0,200 $463.7 $4008 © $500.9 $623.0 $1301 $1,310 $1337 $1.386 $4090 $4080 © $486.0 $6001 $0034 $0040 = $008.8 = $1,0201 sero $6248 8 ©— $8103 $813.3 $3,343.3 $4,168.0 $4.087.3 $6,800.7 2206.2 22864 = 2345.7 2405.0 $os19 $0422 6 $0425 $0428 $0373 $0301 $0340 © $0.38 $1508 $1020 «$2278 $2,616 e120 2080.6 $0.200 $636.1 $1.373 $626.6 $1,067.9 $807.0 2466.2 $0.431 $0.327 $2,043 627.0 2746.1 $0 200 $640.2 $1,302 $945.9 $1,096.1 $800.2 $7.407.0 2600.4 90.433 90.317 042.0 2811.6 $0.200 $502.3 $1410 $906.5 $1,128.83 $703.1 $3,200.9 2606.7 $0.438 $0.307 $3.607 657.0 2877.1 ‘$0200 $876.4 $1.420 $6975 si629 $7e56 2646.0 $0.439 $0,207 073.1 2047.0 $0.200 $680.6 $1.449 $0101 $1,190.6 $770.3 $9,766.8 ani20 $0.442 $0.237 $4.151 680.2 3018.6 $0,200 $803.7 $1408 $633.1 $1,236. $7725 $10,638.4 2777.1 $0445 $0.278 $4420 706.3 3080.4 $0.200 $017.0 $1,488 $066.7 $1.2746 $706.5 $11,303.9 pean2 $0.448 $0.200 $4.098 721.4 3160.1 $0,200 $632.0 $1508 $e80.8 $1.5120 $758.2 $12,0620 2007.3 $0. 462 737.6 3230.0 $0.200 $046.2 $1620 $706.5 $1,361.7 $760.5 $2826 20724 $0.455 $0.252 $6.212 763.6 3301.7 $0,200 $660.3 $1,540 $730.7 $1,301.0 $7427 $13,666.2 3037.5 $0.488 $0244 2010 760.7 3372.4 $0.200 $674.5 $1.570 $766.4 $1,430.98 $734.68 $14,260.86 s1026 $0.461 $0.237 $5.693 2011 795.8 3443.2 $0,200 $088.6 $1.501 $7827 $1,471.3 $7203 $16,010.1 31677 $0404 $0229 2012 801.0 3613.9 $0.200 $702.8 $1.013 $800.6 $5124 $778 $15,734.90 3232.8 $0.458 $0.222 818.0 3584.7 ‘$0.200 $716.0 $1.036 $237.0 $1.554.0 $700.2 $16,443.2 3297.9 $0471 $0215 2014 833.5 3062.8 $0.200 $7306 $1.057 $204.4 $1,605.0 $e00.0 $17,143.1 3300.6 $0.475 $0.208 $0.608 clu 1. LOAD DEMAND A. DEMAND - KWH B. ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 10% 0. TOTAL ENERGY REQUIREMENTS - MWH & MWHAVAILABLE FROM NYAG HYDRO F. VILLAGE HYDRO USAGE - MWH. @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000, A. TRANSMISSION LINE B.NYAC HYDRO. G. TOTAL INVEST. GOST ($1000, 3. FKED COSTS ($1000, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 8% 7.0% B. INSURANCE G. TOTAL FIKED COST ($1000) 5% 7.0% 4, PRODUCTION COSTS ($1000) ‘A. OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE 8. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000, 1903 738.0 20722 207.2 3260.4 oo oo 1634.7 $6,073 $2,700 $7,773 $671.1 $820.7 $671.1 $820.7 $04.5 $0.0 $85.0 326.9 $191.3 $067.7 1994 750.9 3037.7 303.8 3341.5 2304.0 196.1 1036.6 $2,700 $2,700 $904.2 $1.1138 $43.2 $047.4 $1,197.0 $04.5 $40.0 $85.0 $120.1 $3156 POWER COST STUDY AKIACHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG - INTERTIED TO BETHEL + NYAG HYDRO WITH A-FRAME, SWGR TRANSMISSION LINE 1995 705.8 3103.2 3103 3413.5 2348.1 2051.0 1086.4 eee $004.2 $1,113.88 $43.2 $047.4 $1.167.0 $045 $80.0 $85.0 $1300 $360.4 1996 780.7 3168.7 316.0 3485.5 2301.3 2008.7 1004.2 ess $004.2 $1113.68 $43.2 $047.4 $1,187.0 $04.5 $80.0 $85.0 $135.8 $305.3 (ALTERNATIVE 2-4) 1907 1998 706.6 810.5 32342 © 32007 323.4 330.0 36576 © 3620.6 5000 6000 24345 24778 25065 © 2622.2 11230 00(1161.8 $0. $0 $0 $0 $0 $0 $0042 $004.2 $1.1138 $1,1138 $43.2 $43.2 $047.4 $047.4 $1,157.0 $1,167.0 $04.5 $04.5 $80.0 $80.0 $95.0 $05.0 ° ° si408 $146.9 $3703 © $376.4 1999 825.4 3306.1 338.5 3701.7 2621.0 2470.0 1180.7 ees $004.2 H138 $43.2 $047.4 $1,157.0 $04.5 $80.0 $25.0 $151.1 $380.6 8403 3430.6 343.1 3773.7 2504.2 2435.8 1200.5 eee $004.2 $1,.1138 $43.2 $047.4 $1,167.0 $04.5 $80.0 $85.0 $156.4 $386.0 2001 865.2 3496.1 349.6 3845.7 2007.4 23026 1238.3 eee $904.2 $1,.113.8 $43.2 $047 4 $1,167.0 $64.5 $80.0 $85.0 $161.7 $301.2 8701 3561.6 3662 30178 2050.7 2340.3 12071 ess $004.2 $1.113.8 $43.2 $047.4 $1,157.00 $04.5 $80.0 $85.0 $1072 $306.7 885.0 3627.1 362.7 3080.8 2693.0 2306.1 1205.9 eee $004.2 1138 $43.2 $047.4 $1,157.0 $04.5 $80.0 $85.0 $1728 $402.3 901.2 3007.0 300.8 4067.6 2740.6 2250.4 13271 ess $004.2 $113.8 $432 $047.4 $1,187.0 $04.5 $80.0 $85.0 $178.8 $408.3 917.4 3708.6 376.9 4145.5 2787.3 20127 1368.2 ess $904.2 $1,113.86 $43.2 $047.4 $1,187.0 $04.5 $80.0 $26.0 $184.9 $414.4 933.6 3830.4 383.9 4223.3 2634.0 2106.0 1380.3 ese $004.2 $1.1138 $43.2 $047.4 $1.157.0 $04.5 $80.0 $85.0 $191.1 $420.6 2007 940.8 3010.1 391.0 4301.2 2680.7 21103 1420.5 ees $904.2 $1,113.8 $43.2 $047.4 $1,157.0 $04.5 $80.0 $85.0 $107.4 $426.9 906.0 3080.9 308.1 4370.0 2027.4 2072.6 1481.6 ees $004.2 91.1138 $43.2 $047.4 $1.187.0 $04.5 $80.0 $85.0 $203.9 $433.4 982.2 4051.7 405.2 4456.8 20741 1482.7 ees $004.2 $1,113.86 $43.2 $047.4 $1,157.0 $04.65 $80.0 $86.0 $2104 $430.9 2010 908.4 41224 22 4534.7 3020.8 1970.2 1813.0 ees $004.2 $1.113.8 $43.2 $047.4 $1,167.0 $04.5 $80.0 $85.0 $2174 $446.6 2011 1014.6 4193.2 4103 40125 3067.5 19325 1845.0 ees $004.2 1.1138 $43.2 $047.4 $1,157.0 $04.6 $80.0 $35.0 $223.0 $453.4 2012 1030.8 4203.0 426.4 4000.3 31142 1985.8 1676.1 ess $904.2 $1,113.86 $43.2 $047.4 $1,187.0 $04.5 $80.0 $26.0 $230.0 $400.4 Page 1 of 2 2013 1047.0 4334.7 433.5 4708.2 3160.9 1830.1 1607.3 ees $233.1 $287.1 $43.2 $2703 $330.3 $04.5 $20.0 $85.0 $2370 $407.4 2014 1063.8 44041 440.4 4944.5 3208.7 1703.3 1637.8 ees $0.0 $00 $43.2 $43.2 $43.2 $04.5 $80.0 $85.0 $246.1 $4746 & bi 5 ANNUAL GOST ($1000) s% 7.6% A. CREDIT FOR SALES: TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($100) o% 7.6% G. PRESENT WORTH ($1000) TOTAL ANNUAL COST 5% 7.0% D. AGCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST o% 7.0% 6. ENERGY COST #/KWH A. ENERGY SOLD MWH B. COST ENERGY $/KWH 6% 7.0% G. PRESENT WORTH ENERGY $VKWH 8% 7.0% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 5% 7.0% 1903 $1,338.8 $1,404.4 $0.0 $1,338.8 $1.404.4 $1,338.8 $1,494.4 $1,338.8 $1,404.4 2734.4 $0490 $0.547 $0.490 $0.547 $0.490 $0.547 1904 $1,263.0 $1,472.68 $20.3 $1,242.7 $1,462.35 $1,200.5 $1,410.00 $2,545.4 $2,904.4 2704.7 $0.445 $0,520 $0.432 $0,505 $0.021 $1.061 1905 $1,307.9 $1,617.4 $2602 $1,027.6 $1.297.2 $968.7 $1,106.2 $3.614.0 $4.070.5, 2864.9 $0,360 $0.433, $0.339 $0.408 $1.261 $1.460 1996 $1,3128 $1,522.3 $279.4 $1,033.4 $1,243.0 $045.7 $1,137.65, $4,469.7 $5,208.0 2015.2 $0.354 $0426 $0.24 $0.300 $1,585 $1,850 (ALTERNATIVE 2A) 1997 $1,.3178 $1,627.3 $278.5 $1,030. $1.248.9 $023.4 $1,109.6 $6,383.1 $0,317.68 2078.4 $0 349 $0420 $0310 $0.373 $1.805 $2.223 1908 $1,3228 $1,532.44 $277.5 $1,045.4 $1,266.0 $001.8 $1,082.5 $6,284.09 $7,400.2 3036.7 $0.344 $0413 $0.207 $0.357 $2102 $2.570 1999 $1,328.0 $1,637.6 $278.4 $1,051.6 $1,261.2 $880.7 $1,056.2 $7,165.86 $8,456.4 $0.340 $0.407 $0.284 $0.341 $2.477 $2,020 2000 $1.333.3 $1,542.09 $276.2 $1,058.1 $1,267.66 $860.3 $1,030.7 $8,026.9 $9,487.1 3196.2 $0335 $0.402 $0.273 $0.327 $2.750 $3.247 2001 $1,338.7 $1,548.2 $274.0 $1,064.7 $1,274.2 $840.5 $1,005.9 $8,066.4 $10,493.0 3216.4 $0.331 $0.306 $0.261 $0.13 $3.011 $3.560 2002 $1,344.2 $1,963.7 $272.7 $1,071.65 $1,261.0 $921.2 $081.8 $0,687.6 $11,474.09 32767 $0.327 $0.301 $0.251 $0.300 $3.261 $3859 2003 $1.340.7 $1,959.3 $271.3 $1,078.4 $1,288.0 $002.5 $958.4 $10,490.1 $12,433.3 3336.9 $0.323 $0.386 $0.240 $0.287 $3.902 $4.147 $1,365.7 $1,605 3 $260.4 $1,086.3 $1,205.90 $784.8 $936.2 $11,274.90 $13,300.5 3402.0 $0.310 $0.381 $0.231 $0.275 $3.733, $4,422 2005 $1,361.8 $1,971.4 $267.4 $1,094.5, $1,304.0 $767.6 $014.6 $12,042.56 $14,284.1 3467.1 $0316 $0.376 $0.221 $0,264 $3.954 $4.686 $1,368.0 $1,877.8 $205.3, $1,102.8 $1,312.3 $750.9 $893.6 $12,703.4 $19,177.7 3632.2 $0.12 $0.372 $0.213 $0.253 $4,187 $4.930 2007 $1.374.4 $1,683.90 $263.0 $1.191.3 $1,320.9 $734.7 $873.3 $13,628.2 $16,051.0 3697.3 $0.309 $0.367 $0.204 $0.243 $4.371 $6.181 $1,380.8 $1,800.4 $260.7 $1,120.1 $1,3207 $718.9 $853.5 $14,247.41 $16,904.4 3662.4 $0.308 $0.363 $0196 $0.233 $4,567 $6.414 $1,387.4 $1,606.9 $258.3 $1,.120.1 $1,338.7 $703.6 $834.2 $14,950.7 $17,738.68 3727.5 $0.303 $0.369 $0.189 $0.224 $4.766 $5.638 2010 $1,304.14 $1,603.68 $266.7 $1,138.3 $1,347.09 $eee.7 $816.5 $15,630.4 $18,664.1 3792.6 $0.300 $0.355 $0.182 $0.215 $4.937 $6.853 2011 $1.400.9 $1,610.4 $263.1 $1,147.89 $1,367.4 $074.2 $797.3 $16,313.7 $19,351.5 3887.7 $0.208 $0.362 $0.175 $0.207 $6.112 $6.060 $1,407.86 $1,617.4 $2603 $1,187.5 $1,367.1 $060.1 $770.6 $16,973.86 $20,131.41 3022.8 $0.206 90.348 $0.168 $0.190 $6.281 $6.250 Page 2 of 2 2013 $743.8 $797.8 $247.4 $406.4 $550.4 $274.8 $304.7 $17,248.06 $20,436.9 3987.9 $0.124 $0.138 $0.069 $0.076 $5349 $6.335 2014 $517.8 $517.8 $244.5 $273.3 $273.3 $146.9 $146.9 $17,306.56 $20,582.8 4051.7 $0,087 $0.087 $0.036 $0.036 $5.386 $0.371 TLV 1. LOAD DEMAND A DEMAND - KWH. 8. ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH_ & MWH AVAILABLE FROM NYAC HYDRO F. VILLAGE HYDRO. USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE. B.NYAG HYDRO G. TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1009, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 5% 7.0% B. INSURANCE G. TOTAL FED COST ($1000) 8% 7.8% 4, PRODUGTION COSTS ($1000) A OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION . PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 736.0 2072.2 297.2 3200.4 0.0 oo 1634.7 $6,943 $2,700 $8,643 $746.2 $o19.2 $746.2 $019.2 $04.5 $0.0 $85.0 326.9 $191.3 $007.7 1994 760.9 3037.7 303.8 3341.5 2600 2304.9 105.1 1036.8 $o $2,700 $2,700 $070.4 $1,206.3 $43.2 $1,022.68 $1,249.5 $64.5 $40.0 $85.0 $126.1 $315.6 POWER COST STUDY AKIACHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG - INTERTIED TO BETHEL + NYAG HYDRO WITH SINGLE POLE, SWGR TRANSMISSION LINE 1995 706.8 3103.2 3103 3413.5 2348.1 2051.0 1086.4 eee $070.4 $1,206.3 $43.2 $1,022.6 $1,240.5. $04.5 $80.0 $86.0 0 $130.0 $300.4 1996 780.7 3108.7 316.0 3485.5 2301.3 2008.7 1094.2 ees $970.4 $1,206 3 $43.2 $1,022.6 $1,240.65 $04.6 $80.0 $85.0 $135.8 $365.3 (ALTERNATIVE 3:8) 1907 1998 706.6 810.5 3234.2 © 3200.7 323.4 330.0 3657.0 © 3020.6 5000 5000 24345 (2477.8 25055 © 2522.2 11230 0 1151.8 $0 $0 $0 $0 $0 $0 $970.4 $070.4 $1,208.3 $1,206.3 $43.2 $43.2 $1,0226 $1,022.6 $1,2405 $1,240.65 $04.5 $04.5 $20.0 $80.0 $85.0 $26.0 ° 0 $408 $1450 $3703 © $376.4 1999 826.4 3306.1 3306.5 3701.7 2621.0 2470.0 1180.7 ess $970.4 $1,206.3 $43.2 $04.6 $80.0 $86.0 $161.1 $380.6 2000 e403 3430.6 343.1 3773.7 2664.2 2435.8 1200.5 ees $970.4 $1,206.3 $43.2 $1,022.6 $1,.249.5 $04.5 $80.0 $85.0 $156.4 $386.9 2001 855.2 3406.1 340.6 3846.7 2607.4 2302.6 1238.3 ees $970.4 $1,206.3 $43.2 $1,022.66 $1,240.5 $04.5 $20.0 $86.0 $161.7 $301.2 2002 8701 3661.6 356.2 3017.8 6000 2050.7 2340.3 12671 Bes $070.4 $1,208.3 $43.2 $1,022.6 $1.2405, $64.5 $80.0 $85.0 $107.2 $306.7 2003 885.0 3027.1 362.7 3980.8 2693.9 2308.1 1206.9 ese $079.4 $1,208.3, $43.2 $1,022.6 $1,249.5 304.5 $80.0 $85.0 $1728 $402.3 2004 901.2 3097.9 300.8 4087.6 27406 2260.4 1987.1 Bes $070.4 $1,206.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $178.8 $408.3 917.4 3768.0 376.0 4145.5 2787.3 22127 1368.2 eee $070.4 $1,200.3 $43.2 $1,022.68 $1.240.5 $04.5 $80.0 $85.0 $184.0 $4144 2006 933.6 3630.4 383.0 4223.3 2834.0 2108.0 1380.3 ees $070.4 $1,206.3 $43.2 $1,022.86 $1,240.58 $04.5 $80.0 $85.0 $1011 2007 940.8 3910.1 301.0 4301.2 2880.7 21103 1420.5, ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.56 $64.65 $80.0 $85.0 $197.4 $426.0 986.0 3080.9 308.1 4370.0 2027.4 2072.6 1451.6 ees $070.4 $1.208.3 $43.2 $1,022.6 $1,240.85 $04.5 $80.0 $85.0 $203,9 $433.4 2009 982.2 4051.7 405.2 4456.8 20741 2025.0 1482.7 ees $079.4 $1,206.3 $43.2 $1,022.6 $1,240.5 $64.6 $80.0 $85.0 $210.4 $439.9 2010 08.4 4122.4 422 4634.7 3020.8 1970.2 1813.9 eee $9704 $1,206.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $2171 $446.6 1014.6 4193.2 4193 40125 3067.5 1032.6 1846.0 eee so7a4 $1,208.3 $43.2 $1,0226 $1,240.5 $04.5 $80.0 $85.0 $223.9 $453.4 2012 1030.8 4203.0 426.4 4000.3 3114.2 1985.8 1976.1 ses $o7a.4 $1,208.3 $43.2 $1,0226 $1,240.5 $04.5 $80.0 $85.0 $220.0 $400.4 Page 1 of 2 2013 1047.0 4334.7 433.5 4708.2 3160.9 1830.1 1807.3 eee $233.1 $287.1 $43.2 $276.3 $330.3 $04.5 $80.0 $85.0 $237.0 $407.4 2014 1063.8 4404.1 440.4 4844.5 3208.7 1703.3 16378 ese $0.0 $0.0 $43.2 $43.2 $43.2 $04.5 $80.0 $85.0 $246.1 $474.6 STO 5. ANNUAL GOST ($1000, o% 7.0% A. CREDIT FOR SALES: TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) o% 7.0% C. PRESENT WORTH ($1000) TOTAL ANNUAL COST 5% 70% D. ACCUMULATED PRESENT ($1000, WORTH TOTAL ANNUAL COST ox 7.0% 8. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH o% 7.0% PRESENT WORTH ENERGY $/KWH o* 7.8% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1903 $1.4140 $1,586.90 $0.0 $1.4140 $1,586.0 $1.4140 $1,986.0 1.4140 $1,586.9 2734.4 $0517 $0.580 $0517 $0.580 $0.517 $0.580 1904 $1,338.2 $1.505.1 $203 $1.3178 $1.544.8 $1.2704 $1,409.8 $2.003.4 $3.086.7 27047 $0.472 $0.553 $0.468 $0.537 $0.975 $1117 19965 $1,383.0 $1,6100 $200.2 $1,102.68 $1.320.7 $1.030.5 $1,263.4 $3,732.0 $4,340.1 $0386 $0466 $0 364 $0.430 22 1996 $1,387.08 $1,014.0 $2704 $1.108.5 $1.335.5 $1,0144 $1,2222 $4,747.3 $5.562.3 2o152 $0.380 $0.458 $0348 $0410 $1.687 $1.975 (ALTERNATIVE 3:8) 1907 1998 $1,2020 $1.3080 $1,.0199 $1,624.09 $2785 © $2775 $1.1144 $1.1206 $1.341.4 | $1,347.65 $o002 $88.6 $i191.8 $1,1024 $5.737.5 $6.7040 $0.7541 $7,016.55 20754 © 3036.7 $0375 © $0.380 $0451 $0444 $0333 gosi8 $0.401 $0.383 $2020 $2338 $2376 © $2.750 1999 $1.403.1 $1.6301 $276.4 $1.1268 $1.363.7 $043.6 $1.133.7 $7.647.7 $0,050.2 $0364 $0.437 $0.305 $0366 $2043 $3.126 $1.408.4 $1.635.4 $275.2 $1.133.2 $1.300.2 $0214 $1,105.90 $9,500.1 $10,156.1 3186.2 $0.350 $0.431 s0.292 $0.350 $2935 $3.475 2001 1.4138 $1.6408 $274.0 $1,130.8 $1,306.8 $200.8 $1,078.98 $9.408.8 $11.236.1 32164 $0.354 $0.425 $0.280 $0 335 $3215 $3811 $1.410.3 $1,646.2 $2727 $1,146.86 $1.3736 se7ee $1,0527 $10,347.6 $12,2678 32767 $0.350 $0419 $0208 $0.321 $3.483 $4132 $1.4248 $1.651.8 $2713 $1,193.6 $1,380. $ese.4 $1,027.3 $11,206.0 $13,315.00 3336.9 $0.346 $0414 $0257 $0308 $3.740 $4440 $1.430.8 $1,057.88 $260.4 $1.161.5 $1.388.4 $830.1 $1,003.0 $12,046.0 $14,3181 3402.0 $0341 $0.408 $0.247 $0.205 $3.987 94.735 $1.436.0 $1,603.0 $267.4 $1,100.68 $1,300.5 $820.3 $970.5 $12,605.3 $16,207.68 $0.337 $0.403 $0.237 $0.283 $4.223 $6.017 $1.443.1 $1,670.11 $205.3 $1,177.90 $1,404.90 $802.1 $056.6 $13,007.4 $10,2542 $0.333 $0 308 $0.227 $0.271 $4.450 $5.268 2007 91.4405 $1,676.5 $1.180.4 $1.413.4 $784.4 $034.4 $14.451.8 $17.188.7 3697.3 $0.330 $0,303 so218 $0.260 $4008 $5.548 $1.456.0 $1,082.09 $2007 $1962 $1.4222 $767.2 soi2e $15,2190 $18,101.56 $0326 $0 388 $0.209 $0240 $4878 98.707 $1,4025 $1,689.5 $258.3 $1,204.2 $1.431.2 $750.4 $891.9 $15,000.4 $18,003.4 3727.5 $0 323 $0 384 $0.201 $0230 $6.070 $6.038 2010 $1.400.2 $1,006.2 $255.7 $1.2135 $1.4404 $734.2 $971.5 $16,703.5 $19,804.90 3702.6 $0 320 $0.380 $0.104 $0.230 $6.273 $6.260 2011 $1.476.0 $1.703.0 $253.1 $7183 $651.7 $17,421.9 $20.7165 3857.7 $0317 $0376 $0.186 $0221 $5.460 $6.487 2012 $1.4820 $1,708.9 $250.3 $1,232.7 $1,450.68 $703.0 $9324 $19,124.90 $21,548.09 $0314 $0372 $0179 so2i2 $5.038 $8.009 202 2013 $743.8 $7078 $247.4 $406.4 $550.4 $274.8 $304.7 $18,2007 $21,863.7 3087.9 $0124 $0.138 $0.000 $0,070 $5.707 $6.776 2014 $5178 $5178 $2445 $273.3 $2733 $146.9 $146.9 $18,646.68 $22,000.60 4051.7 $0.067 $0.007 $0.030 $0.0368 $5.743 sore Ylw 1, LOAD DEMAND ‘A. DEMAND - KWH B. ENERGY - MWH_ C. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH MWH AVAILABLE FROM NYAG HYDRO. F. VILLAGE HYDRO USAGE - MWH @. SURPLUS MWH HYDRO ‘SALES TO BETHEL UTILITIES 1. MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000, A. TRANSMISSION LINE B.NYAG HYDRO G. TOTAL INVEST. COST ($1000, 3. FIXED COSTS ($1000, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 5% 7.0% B. INSURANCE C. TOTAL FIKED COST ($1009) 6% 7.0% 4. PRODUGTION COSTS ($1000) A. OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2. HYDRO 3. ADMINISTRATIVE B. SELF GENERATION C, PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($100, 736.0 2972.2 207.2 3200.4 oo 0.0 1634.7 $5,043 $2,700 $8,643 $740.2 sor9.2 $740.2 so19.2 $64.5 $0.0 $85.0 320.0 $191.3 $067.7 1904 760.9 3037.7 303.8 3341.5 2304.0 106.1 1036.6 $2,700 ‘$2,700 $070.4 $1,200.3, $43.2 $1,022.6 $1,240.65 $04.5 $40.0 $85.0 $126.1 $315.6 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKGAK, NYAG - INTERTIED TO BETHEL + NYAC HYDRO WITH SINGLE POLE, SWGR TRANSMISSION LINE 1006 705.8 3103.2 103 3413.5, 2348.1 2061.0 1065.4 ees $0704 $1,208.3 $43.2 $1,022.6 $1,249.65 $64.6 $80.0 $85.0 $130.9 $360.4 1906 780.7 3108.7 316.9 3486.5 2301.3 2008.7 1094.2 ees $970.4 $1.206.3 $43.2 $1,022.6 $1,240.65 $04.5 ‘$80.0 ‘$86.0 $136.8 $306.3 (ALTERNATIVE 3-8, 2% DISCOUNT RATE) 1007 1908 1990 2000 705.6 810.5 825.4 840.3 32342 © 3200.7 33051-34306 323.4 330.0 330.6 343.1 3667.0 © 362068 = 3701.7 3773.7 6000 6000 6000 5000 24345 © 24778 = 2521.0 2884.2 2005.5 26222 «24700 2435.8 11230 0«1181.8 1180.7 12006 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0704 © $0704 «= $0704 «= $0704 $1,208.3 $1,2083 $1,208.3 $1,208.3 $43.2 $43.2 $43.2 $43.2 $1,0226 $1,0226 $1,0226 $1,0226 $1.2405 $1,245 $1,.240.5 $1,240.65 $04.5 $04.6 $64.5 $04.5 $80.0 $80.0 $80.0 $80.0 $285.0 $85.0 $85.0 $85.0 0 0° 0 0 $i40e $1450 $151.1 $1584 $3703 $3754 «= $380.0 $386.9 2001 865.2 3496.1 349.6 3845.7 2007.4 2302.8 1238.3 eee $070.4 $1,200.3, $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $86.0 $161.7 $301.2 2002 870.1 3661.6 366.2 30178 2060.7 2340.3 12671 ees $0704 $1,208.3 $43.2 $1,022.6 $1,240.56 $04.6 $20.0 $85.0 $1072 $300.7 2003 885.0 3627.1 362.7 3080.8 2093.9 2300.1 1205.9 ees $079.4 $1,208.3 $43.2 $1,022.6 $1,249.65 $64.5 $80.0 $85.0 $172.8 $402.3 e01.2 3697.0 300.8 4067.6 2740.6 2260.4 13271 ses $970.4 $1,208.3 $43.2 $1,022.6 $1,240.56 $04.5 $80.0 $85.0 $178.8 $408.3 2005 o17.4 3768.6 370.0 4148.6 2787.3 22127 1368.2 ees $070.4 $1,208.3 $43.2 $1,022.6 $1,240.65, $04.5 $80.0 $85.0 $194.9 $414.4 2008 933.6 3839.4 383.9 4223.3 2834.0 2108.0 1380.3 ees $970.4 $1,206.3 $43.2 $1,022.68 $1,240.85. $04.5 $80.0 $85.0 $101.4 $420.8 2007 949.8 3010.1 391.0 4301.2 28807 21103 1420.5 eee $070.4 $1,208.3 $43.2 $1,022.6 $1,240.5 $04.65 $80.0 $86.0 $197.4 $426.9 960.0 3080.9 308.1 4370.0 2027.4 20720 1461.6 ees $970.4 $1,208.3 $43.2 $1,022.6 $1,240.65 $04.6 $80.0 $85.0 $203.0 $433.4 982.2 4081.7 405.2 4458.8 2074.1 2025.0 1482.7 ees $079.4 $1,206.3 $43.2 $1,022.68 $1.240.5 $04.5 $80.0 $85.0 $210.4 $430.0 2010 908.4 4122.4 4122 4534.7 3020.8 1970.2 1513.0 ees $070.4 $1,200.3 $43.2 $1,022.6 $1,240.68 $04.65 $20.0 $85.0 $217.1 $440.6 2011 1014.6 4193.2 419.3 4125 3067.5 1932.5 1846.0 ees $070.4 $1,200.3 $43.2 $1,022.06 $1,240.65 $64.5 $80.0 $85.0 $223.0 $453.4 2012 1030.8 4203.9 420.4 4090.3 3114.2 1985.8 1676.1 ees $979.4 $1,206.3 $43.2 $1,022.6 $1,240.56 $64.5 $80.0 $25.0 $230.9 $400.4 Page 1 of 2 2013 1047.0 4334.7 433.5 4708.2 3160.9 1830.1 1907.3, ess $233.1 $287.1 $43.2 $276.3 $330.3 $04.5 $30.0 $85.0 $237.0 $407.4 2014 1063.8 44041 440.4 4844.5 3208.7 1703.3, 1037.8 2 8 $00 $0.0 $43.2 $43.2 $43.2 $04.5 $80.0 $85.0 $246.1 $474.0 LLvJ 5, ANNUAL COST ($1000) o% 7.0% A. GREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) 5% 7.0% C. PRESENT WORTH ($1000) TOTAL ANNUAL COST 5% 7.0% D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST 5% 7.0% 8. ENERGY COST $/KWH A ENERGY SOLD MWH 8. COST ENERGY $/KWH o% 7.0% C. PRESENT WORTH ENERGY $KWH 5% 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 5% 7.0% 1093 $1,414.0 $1,586.90 $00 $1.414.0 $1,986.0 $1,4140 $1,586.0 $1.4140 $1,586.9 2734.4 $0.617 $0.580 $0.517 $0,580 $0.617 $0.680 1994 $1,338.2 $1,906.1 $203 $1.317.8 $1,448 $1,2020 $1,614.65 $2,708.90 $3,101.4 2704.7 $0.472 $0.653 $0.402 $0.642 $0.970 $1122 1995 $1,363.0 $1,010.0 $2802 $1,102.8 $1,320.7 $1,059.09 $1,278.1 $3,705.90 $4.370.6 2854.9 $0. 386 $0.400 $0.371 $0.448 $1.361 $1.670 1996 $1,387.0 $1,014.09 $2704 $1,108.56, $1,335.5 $1,044.68 $1,268.6 $4,810.65 $6,638.0 2018.2 $0.380 $0.468 $0.368 $0.432 $1.700 $2,002 (ALTERNATIVE 3-8) 1907 $1,302.0 $1,010.90 $278.5 $1144 $1,341.4 $1,020.6 $1,230.3 $5,840.0 $6,877.2 2076.4 $0.375 $0.461 $0 346 $0416 $2.065 $2.418 1998 $1,308.0 $1,624.90 $2775 $1,1205 $1,347.55 $1,014.90 $1,220.56 $0,864.9 $8,007.7 3036.7 $0.369 $0.444 $0.334 $0.402 $2.380 $2.820 1990 $1,403.1 $1,630.1 $270.4 $1,126.8 $1.363.7 $1,000.5 $1,202.1 $7,865.4 $0,200.8 3005.0 $0,304 $0.437 $0.323 $0 368 $2713 $3.208 $1,408.4 $1,635.4 $276.2 $1,133.2 $1,360.2 $086.5 $1,1841 $8,841.90 $10,483.0 3166.2 $0.360 $0.431 $0.313 $0.376 $3.026, $3.684 2001 $1,413.8 $1,040.8 $274.0 $1,130.68 $1,300.8 $0728 $1,166.5 $9.814.8 $11,050.4 3210.4 $0.354 $0.425 $0.302 $0.363 $3.328 $3,946 2002 $1.410.3 $1,648.2 $2727 $1.1406 $1,373.68 $950.4 $1,140.3 $10,774.2 $12,7007 3276.7 $0.30 $0.410 $0.203 $0.361 $3.620 $4.207 2003 $1.424.8 $1,661.8 $271.3 $1,163.66 $1.380.5 $046.3 $1,132.56 $11,720.5 $13,032.3 3336.9 $0.346 90.414 $0. 284 $0.330 $3.904 $4.636, $1,430.8 $1,057.86 $260.4 $1,161.85 $1,388.4 $034.1 $1,116.7 $12,064.6 $16,048.0 3402.0 $0.341 $0.408 $0.275 $0.328 $4.178 $4,005 $1,438.06 $1,063.0 $207.4 $1,160.6 $1,306.5, $022.2 $1,101.2 $13,976.86 $16,160.1 3407.1 $0.337 $0.403 $0.200 $0.318 $4.444 $6,282 $1,443.1 $1,0701 $205.3 $1,177.90 $1,404.90 $o106 $1,086.0 $14,487.4 $17,230.1 3632.2 $0.333 $0,308 $0.258 $0.307 $4.702 $5.500 2007 $1,440.65. $1.076.5 $263.0 $1,.186.4 $1.413.4 $200.2 $1,071.2 $16,380.5 $18,307.3 3607.3 $0330 $0 303 $0.260 $0.208 $4.952 $6.688 $1,455.09 $1,082.09 $200.7 $1,106.2 $1,422.2 $888.1 $1,066.7 $10,274.60 $10,364.0 3662.4 $0320 $0368 $0.242 $0.280 $6.106 $0170 $1,402.65 $1,080.5 $258.3 $1,204.2 $1.431.2 $977.2 $1,042.5 $17,161.8 $20,400.6 3727.5 $0.323 $0.38 $0.235 $0.280 $6.430 $0.468 2010 $1,460.2 $1,006.2 $265.7 $1.2135 $1,440.4 $208.6 $1,028.7 $18,018.4 $21,435.3 3702.6 $0.320 $0.380 $0.228 $0.271 $6.050 $0.727 2011 $1,478.0 $1,703.0 $253.1 $1,222.90 $1.440.0 $250.2 $1,016.2 $18.674.7 $22,450.4 3867.7 $0.317 $0.376 $0.222 $0.263 $5.880 $0.990 2012 $1,4820 $1,700.9 $260.3 $1,232.7 $1,459.6 $840.1 $1,001.90 $19,720.8 $23,462.4 $0.314 $0372 $o.216 $0.265 $6.06 $7.240 Page 2 of 2 2013 $743.8 $797.8 $247.4 $406.4 $950.4 $3341 $3704 $20,054.8 $23,822.8 3087.0 $o.124 $0.138 $0.084 $0.003 $6.180 $7.38 2014 $6178 $517.8 $2445 $2733 $2733 $1803 $180.3 $20,238.1 $24,003.1 4061.7 $0.067 $0.067 $0.045 $0,045 $8.224 $7 383 BLU 1, LOAD DEMAND ‘A DEMAND - KWH B. ENERGY - MWH G. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH MWH AVAILABLE FROM NYAG HYDRO F. VILLAGE HYDRO USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000, A. TRANSMISSION LINE B.NYAG HYDRO C. TOTAL INVEST. GOST ($1000) 3. FKED COSTS ($1000, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% s* 7.0% B. INSURANCE G. TOTAL FKED GOST ($1000) 6% 7.0% 4, PRODUCTION GOSTS ($1000) A. OPERATIONS AND MAINT. 1, TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1903 736.0 2o72.2 207.2 3200.4 oo 00 1034.7 $5,043 $2,700 $9,043 $746.2 so10.2 $740.2 sn102 $04.5 $0.0 $86.0 320.0 $101.3 $087.7 1904 750.0 3037.7 303.8 3341.6 2304.0 105.1 1036.6, $2,700 $2,700 $0704 $1,200.3 $43.2 $1,022.6 $1,240.56 $04.6 $40.0 $85.0 $1201 $315.0 POWER GOST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG - INTERTIED TO BETHEL + NYAG HYDRO WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 3-G, 4% DISCOUNT RATE) 1906 708.8 3103.2 3103 34136 2348.1 2051.0 1065.4 ses $0704 $1,200.3 $43.2 $1,022.6 91,2406 $04.6 $800 $85.0 $130.0 $300.4 1906 780.7 3108.7 316.0 3485.5 2301.3 2008.7 1004.2 ees $0704 $1,200.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $135.8 $305.3 1907 7086 3234.2 323.4 3587.0 2434.5 1123.0 ees $0704 $1,200.3, $43.2 $1,022.06 $1,240.5 $04.5 $80.0 $85.0 $1408 $370.3 1998 8105 3200.7 330.0 24778 1181.8 ees $070.4 $1,200. $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $1450 $375.4 1990 825.4 3306.1 336.5 3701.7 2621.0 2470.0 1180.7 ees $070.4 $1,200.3 $43.2 $1,022.6 $1,240.85 $04.5 $80.0 $86.0 $151.1 2000 940.3 3430.0 343.1 3773.7 2604.2 2435.8 1200.6 ees $970.4 $1,200.3 $43.2 $1,022.6 $1,240.65 $64.5 $80.0 $85.0 $156.4 $385.0 856.2 3496.1 340.0 3845.7 2007.4 23026 1238.3 eee $070.4 $1,2063 $43.2 $1,022.6 $1,.2405, $04.5 $80.0 $85.0 $101.7 $301.2 8701 3661.6 3602 30178 2060.7 23403 12071 eee $0704 $1,200.3 $43.2 $1,022.60 $1,240.85 $04.6 $80.0 $85.0 $107.2 $306.7 885.0 3027.1 302.7 30808 2003.0 2306.1 1205.0 eee $0704 $1,200.3, $43.2 $1,022.6 $1,240.5 $04.5 $30.0 $86.0 $1728 $402.3 901.2 3097.0 3008 4067.6 27406 22604 1327.1 ees $070.4 $1,200.3 $43.2 $1,022.6 $1,240.65 $04.6 $80.0 $85.0 $1788 $408.3 o17.4 3708.0 376.0 4145.5 2787.3 22127 1358.2 ees $0704 $1,200.3 $432 $1,022.6 $1,240.5 $04.5 $80.0 $96.0 $184.0 $4144 933.6 3830.4 383.0 4223.3 2634.0 2168.0 1380.3 ees $0704 $1,200.3 $432 $1,022.6 $1,2406 $04.5 $80.0 $85.0 $1014 $420.6 2007 osoe 3010.1 301.0 4301.2 2880.7 21103 1420.5 ese $070.4 $1,200.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $107.4 $420.0 906.0 3980.9 308.1 43700 2007.4 20726 1461.6 eee $0704 $1,200.3 $43.2 $1,022.60 $1,240.65 $04.6 $00.0 $85.0 $203.0 $433.4 oe2.2 4051.7 408.2 4456.8 20741 1482.7 ese $0704 $1,200.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $2104 $430.0 2010 908.4 41224 422 4634.7 3020.8 1970.2 1813.0 ees $0704 $1,200.3 $43.2 $1,022.6 91,2405 $04.6 $80.0 $86.0 $217.4 $446.6 2011 1014.6 4193.2 103 40126 3007.5 1032.5 1846.0 ees $0704 $1,200.3 $43.2 $1,022.6 $1,240.5 $04.6 $80.0 $85.0 $223.0 $453.4 2012 1030.8 4203.0 420.4 4000.3 3114.2 1985.8 1876.1 ses so704 $1,200.3 $432 $1,022.6 $1,240.65 $046 $80.0 $85.0 $230.0 $400.4 Page 1 of 2 1047.0 4334.7 433.5 4708.2 3100.0 1830.1 1007.3, ees $233.1 $287.1 $43.2 $270.3 $330.3 $04.5 $80.0 $85.0 $237.0 $407.4 2014 1063.8 44041 440.4 48446 3200.7 1703.3 1037.8 ees $00 $00 $43.2 $43.2 $432 $04.5 $80.0 $85.0 $245.1 $474.6 610 5. ANNUAL COST ($1000) o% 70% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL GOST ($1000) o% 7.0% C. PRESENT WORTH ($1000, TOTAL ANNUAL GOST o% 7.0% D. ACCUMULATED PRESENT ($100, WORTH TOTAL ANNUAL GOST 6% 7.0% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $KWH ox 7.0% C. PRESENT WORTH ENERGY $/KWH * 70% . ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 70% 1903 $1.4140 $1,586.9 $00 $1,414.0 $1,580.9 $1.4140 $1,580.90 $1.4140 $1,598.9 27344 $0.17 $0.680 $0517 $0.680 $0.517 $0 580 1004 $1.338.2 $1,505.1 $20.3 91.3178 $1.5448 $1.207.1 $1,486.4 $2.081.1 $3.072.3 $0.472 $0.653 $0.463 $0532 $0.971 $1112 1906 $1,383.00 $1.610.0 $2002 $1,102.86 $1,320.7 $1.0106 $1.2204 $3.700.7 $4.301.7 $0380 $0.466 $0.357 $0431 $1,328 $1,542 1006 $1,387.9 $1,614.09 $270.4 $1,108.5 $1,335.6 $085.5 $1,187.2 $4,086.1 $5.480.0 2015.2 $0.380 $0.45 $0338 $0.407 $1,666 $1,060 (ALTERNATIVE 3G) 1907 $1,302.90 $1,0100 $1114.46 $1.341.4 $os26 $1,140.68 $5,038.7 $0,036.68 2978.4 $0375 $0.461 $0320 $0.85 $1086 $2335 1908 $1,308.00 $1,624 $2775 $1,120.56 $1.347.5 $021.0 $1,107.65 $0,560.7 97.7431 $0.444 $0.303 $0.365, $2280 $2,700 1990 $1.403.1 $1.630.1 $276.4 $1.1208 $1.363.7 $800.5 ‘$1,000.0 $7,450.2 $8.813.0 $0.30 $0.437 $0288 $0.346 $2677 $3.040 $1,408.4 $1,035.4 $275.2 $1,133.22 $1,300.2 $801.1 $1,033.66 $8,311.64 $0.640.6 3186.2 $0.360 $0.431 $0.273 $0327 $2.850 $3.373 $1,413.86 $1.040.8 $2740 $1.130.8 $1,306.8 $8328 $908.7 $0,144.2 $10,845.3 3216.4 $0.364 $0.425 $0260 $0310 $3100 $3,684 $1.4193 $1,048.2 $2727 $1,146.86 $1.3736 $205.6 $005.0 $0,0408 $11,8104 3270.7 $0.350 $0419 $0.246 $0.206 $3.364 $3978 $1.424.8 $1,051.8 $271.3 $1.153.6 $1,380.5 $7703 sos28 $10,720.1 $12,743.0 $0346 $0414 $0234 $0.270 $3.68 $4268 $1.4308 $1,057.68 $2004 91,1615 $1,388.4 $754.5 $001.0 $11,483.65 $13,044.06 3402.0 $0.341 $0.408 so.222 $0.206 $3,610 $4523 $1.436.0 $1,063.0 $207.4 $1,160.68 $1,300.5 $7305 $8723 $12.2141 $14.517.2 3487.1 $0.337 $0.403 soe $0252 $4.020 $4774 $1,443. $1,070.1 $205.3 $1.177.0 $1,404.90 $7074 $943.7 $12,021.56 $15,300.0 $0 333 $0 308 $0.200 $0 230 $4201 $5.013 $1.4405 $1,676.6 $203.0 $1,186.4 $1,413.4 $0851 $3102 $13,006.6 $16,177.41 3507.3 $0.330 $0.303 $0.190 $0.227 $4411 $5.240 $1,465.9 $1,082.90 $2007 $1,105.2 $1.4222 $003.7 $780.7 $14.2703 $16,000.68 3082.4 $0 326 $0. 388 $0.161 so216 $4,502 $5.466 $1.402.5 $1,080.56 $258.3 $1,206.2 $1.431.2 $042.0 $764.1 $14,0132 $17,730.9 3727.5 $0.323 $0.384 $0172 $0.205 $4765 ‘$5.061 $1,400.2 $1,000.2 $1,213.65 $1.4404 $023.0 $730.5 $15,636.2 $18.470.4 37026 $0 320 $0.380 90.104 90.106 $4.020 $5.856 2011 $1.476.0 $1,703.0 $253.1 $1,222.09 $1.440.0 ‘$003.7 $7187 $16,1308 $10,186.1 3887.7 $0317 $0376 $0.156 $0.186 $5.086 $0.041 $1.4820 $1,700.0 $2603 $1.2327 $1,450.06 $985.1 soo2e $16,724.90 $10,878.90 0.314 $0372 $0.149 $0.17 $5.235 soe Page 2of2 2013 $743.8 $797.8 sea74 $400.4 $950.4 $220.5 $251.2 $16,051.4 $20,130.1 3087.9 $0.124 90.138 $0,067 $0.063 $5.202 $0.281 2014 $517.8 $917.8 $2445 $273.3 $273.3 sii00 s1i99 $17,071.4 $20,250.1 4051.7 $0.067 $0.067 $0.030 $0.030 $6321 $6.310 0¢0 1, LOAD DEMAND A. DEMAND - KWH. 8. ENERGY - MWH_ G. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH_ E, MWH AVAILABLE FROM NYAC HYDRO. F. VILLAGE HYDRO. USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A TRANSMISSION LINE B.NYAG HYDRO G. TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1000) A DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 6% 7.0% B. INSURANCE G. TOTAL FIKED GOST ($1000) o% 7.0% 4, PRODUGTION COSTS ($1000) A. OPERATIONS AND MAINT. 1, TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION . PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1903 736.0 20722 207.2 3200.4 0.0 0.0 1634.7 $5,043 $2,700 $8,643 $748.2 $910.2 0 $746.2 $o19.2 $64.5 $0.0 $86.0 326.9 $191.3 $067.7 1904 756.9 3086.5 305.6 3362.1 2600 2317.3 1827 1044.9 $0 $2,700 $2,700 $0704 $1,200.3 $43.2 $1,022.6 $1,2405 $64.5 $40.0 $86.0 0 $1271 $316.68 POWER COST STUDY AKIACHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG - INTERTIED TO BETHEL + NYAG HYDRO WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 3-D, LOAD GROWTH +20%) 1995 777.8 3140.8 314.1 3454.8 2372.0 2027.1 1081.9 eee $0704 $1,208.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $85.0 $133.0 $362.5 1996 708.7 3225.0 322.6 3647.6 2428.6 2671.5 11100 ess $070.4 $1,208.3 $43.2 $1,022.6 $1,240.5 $64.5 $80.0 $85.0 0 $1300 $368.5 1997 8106 3300.3 330.9 3640.3 2484.2 25158 1186.1 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.5, $64.5 $80.0 $86.0 $145.1 $374.68 1998 840.5 3303.6 330.4 3733.0 2630.8 2400.2 1193.2 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.65 $04.6 $80.0 $85.0 $161.3 $380.8 1909 861.4 3477.0 347.8 3825.7 2506.4 2404.6 1230.3 eee $970.4 $1,206.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $85.0 $157.6 $387.1 2000 e823 3662.2 3668.2 3018.4 2051.0 2340.0 1267.4 ees $070.4 $1,208.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $85.0 $164.1 $303.6 2001 903.2 3646.4 364.6 4011.4 5000 2708.7 2203.3, 1304.4 ees $0704 $1,208.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $86.0 $170.6 $400.1 2002 924.1 3730.7 373.1 4103.8 6000 2762.3 2237.7 1341.6 $0 $0 $0 $070.4 $1,206.35 $43.2 $1,022.6 $1,240.5 $04.6 $80.0 $85.0 $177.3 $406.8 2003 945.0 3815.0 381.6 4196.5 2817.9 21821 1378.6 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.6 $64.5 $80.0 $85.0 $1844 $413.6 966.0 3809.3 389.0 4280.2 2873.5 2126.6 1416.7 ees $970.4 $1,206.3 $43.2 $1,022.68 $1,240.65 $04.65 $80.0 $85.0 $191.1 $420.6 997.0 3083.6 308.4 4382.0 2020.2 2070.8 1452.8 ees $970.4 $1,208.3 $43.2 $04.5 $80.0 $85.0 $198.1 $427.6 1008.0 4067.9 406.8 4474.7 2084.8 2016.2 1480.9 ees $o70.4 $1,206.3 $43.2 $1,022.86 $1,240.65 $04.5 $80.0 $85.0 $205.3 $434.8 2007 1028.0 4152.2 416.2 4567.4 3040.5 1950.5 1927.0 ees $070.4 $1.206.3, $43.2 $1,022.6 $1.240.5 $04.5 $80.0 $85.0 $2127 $442.2 1080.0 4236.5 423.7 4960.2 3006.1 1903.9 1964.1 ¢ 8 $070.4 $1,208.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $96.0 $220.1 $440.6 1071.0 4320.8 432.1 4762.0 3161.7 1848.3 1601.2 Bes $079.4 $1.200.3 $43.2 $1,022.86 $1,240.5, $04.5 $80.0 $86.0 $227.7 $457.2 2010 1092.0 4405.1 440.5 4845.6 3207.4 1702.6 1638.2 bes $9704 $1,206.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $85.0 $235.5 $466.0 2011 1113.0 4480.4 448.9 4938.3 3263.0 1737.0 1675.3 ees $0704 $1,200.3 $43.2 $1,022.68 $1,240.5, $045 $80.0 $85.0 $243.4 $4729 2012 1134.0 4873.7 457.4 5031.1 33186 1681.4 1124 ees $970.4 $1,206.3 $43.2 $1,022.6 $1.240.5, $04.5 $00.0 $85.0 $261.4 $480.0 Page 1 of 2 2013 1186.0 4658.0 405.8 6123.8 3374.3 1625.7 1749.5 ees $233.1 $287.1 $43.2 $276.3 $330.3 $04.5 $20.0 $86.0 $250.6 $490.1 2014 11735 4732.5 473.3 6205.8 3423.5 19765 1782.3 ees $0.0 $0.0 $43.2 $43.2 $43.2 $04.5 $80.0 $85.0 $207.3 $406.8 Teo 5. ANNUAL GOST ($1000) 6% 70% A CREDIT FOR SALES TO BETHEL UTILITIES 8, TOTAL ANNUAL GOST ($1000) 6% 7.0% . PRESENT WORTH ($1000) TOTAL ANNUAL COST ox 7.0% 0. AGCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST 6% 7.0% 8. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY §/KWH ox 7.0% G. PRESENT WORTH ENERGY $/KWH o% 7.0% G. ACGUMULATED PRESENT WORTH OF ENERGY $/KWH 6% 70% 1903 $1.4140 $1,696.09 $00 $1,414.00 $1,586.0 $4140 $1,586.9 $1,414.0 $1,586.0 2734.4 $0.517 $0.580 $0.517 $0,580 $0517 $0.680 19004 $1,330.2 $1,506.2 $101 $1,3202 $1,547.17 $1.261.7 $1,902.1 $2,005.7 $3,080.0 28120 $0 469 $0 560 $0456 $0.534 $0.073 91.115 1905 $1,386.1 $1,0121 $2770 $1,107.6. $1,3345 $1,043. $1,267. $3,730.6 $4,468 $0,383 $0 402, $0.301 $0.43 $1.334 $1.650 1996 $1,301.1 $1,018.0 $2754 $1,118.7 91,3426 $1,021.0 $1,2287 $4,760.6 $5.575.5 2007.0 $0.376 $0453 $0,344 $0414 $1,678 $1,064 (ALTERNATIVE 3-0) 1907 $1,307.2 $1,024.1 $273.1 $1241 $1,361.1 $008.7 $1,200.4 $5,750.3 $0,775.09 $0 360 $0444 $0.328 $0. 304 $2,006 $2.368 1998 $1,403.4 $1,630.3 $2706 $1,132.7 $1,360.7 $0771 $1.172.0 $6,736.4 $7,048.8 31221 $0.363 $0438 $0.313 $0.376 $2310 $2734 1990 $1.400.7 $1,636.7 $208.1 $1,141.6 $1,308.6 $056.1 $1,140.2 $7,0025 $9,005.0 3100.6 $0.367 $0.428 $0 200 $0,368 $2018 $3.002 $1,416.1 $1,043.1 $205.4 $1,160.7 $1,377 $035.6 $1,1202 $9,028.1 $10,215.2 3277.2 $0.351 $0.420 $0.285 $0.342 $2,004 $3434 2001 $1,4227 $1,040.7 $202.6 $1,100.1 $1,387.0 $0158 $1,004.9 $0,643.9 $11,310.1 3354.7 $0 340 $0.413 $0.273 $0 326 $3.17 $3 760 $1,420.4 $1,056.3 $2607 $1,100.7 $1,300.6 $806.4 $1,070.4 $10,440.3 $12,380.65 3432.3 $0.341 $0.407 $0.201 $0.312 $3.438 $4072 $1,438.2 $1,603.2 $250.7 $1,1705 $1,406.5 $877.7 $1,046.56 $11,318.00 $13,427.11 $0.336 $0401 $0.260 $0 208, $3.088 $4.370 $1,443.1 $1,6701 $263.5 $1,189.6 $1,4108 $850.4 $1,023.4 $12,174 $14,460.4 3687.4 $0.332 $0 306 $0.240 $0,285 $3,007 $4,050 $1,450.2 $1,677.2 $250.2 '$1,200.0 $1,426.09 $241.6 $1,000.8 $13,0190 $16,451.3 3064.9 $0.327 $0,389 $0.230 $0.273 $4.167 $4,929 $1,487.44 $1,084.4 $246.8 $1,210.68 $1,437.68 $9244 $078.0 $13,843.4 $16,430.2 37426 $0.323 $0.384 $0.220 $0.262 $4377 $5.190 $1,4047 $1,601.7 $243.2 $1,221.65 $1,448.56, $807.6 $957.6 $14,650.0 $17,387.8 $0.320 $0.370 $0211 $0.261 $4580 $5.441 $1,4722 $1,000.2 $230.5 $1,232.7 $1,460.7 $701.2 $036.0 $15,422 $18,324.7 3807.6 $0.316 $0.378 $0.203 $0.240 $4.702 $6.081 $1.4708 $1,706.8 $235.6 $1,044.2 $1,471.14 $776.3 $10.8 $10,217.58 $19,241.5 3076.1 $0.313 $0.370 $0.105 $0.231 $4.087 $6012 2010 $1,714.56 $231.6 $1,265.09 $1,482.90 $750.0 $807.2 $10,977.3 $20,138.7 $0.310 ‘$0 366 $0.187 $0.221 95.174 90.133 2011 $1,405.5 $1,7284 $227.5 $1,208.0 $1,406.00 $744.8 $878.1 $17,7222 $21,0108 4130.2 $0,307 $0.302 $0.180 $0213 $5. 355 $6.346 $1,503 5. $1,730.85 $223.2 $1,280.4 $1,607.3 $730.2 $860.6 $18,462.3 $21,876.4 4207.8 $0,304 $0 358, $0174 $0,204 $9.528 $0.550 Page 2 of 2 2013 $708.5 $H105 $2187 $6408 $000.8 $302.7 $3326 $18,756.1 $22,200.1 4205.4 $0.128 $0.140 $0.071 $0.078 $5.500 $6.628 2014 $540.0 $540.0 $2140 $3261 $326.1 $1748 $1748 $18,020.8 $22,383.68 4363.0 $0.076 $0.078 $0.040 $0040 $5.630 $6.008 eco 1, LOAD DEMAND A. DEMAND - KWH. B. ENERGY - MWH G. TRANSMISSION LINE LOSSES @ 10% 0. TOTAL ENERGY REQUIREMENTS - MWH &. MWH AVAILABLE FROM NYAC HYDRO. F. VILLAGE HYDRO USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000, A TRANSMISSION LINE B.NYAG HYDRO . TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1000) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 6% 7.6% B. INSURANCE G. TOTAL FKED COST ($1000) 5% 7.0% 4, PRODUCTION COSTS ($1000) A. OPERATIONS AND MAINT. 1, TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE b. SELF GENERATION B. PURCHASES FROM BETHEL UTILITIES G. TOTAL PROD. COSTS ($1000) 1993 736.0 20722 207.2 3260.4 00 00 1634.7 $6,043 $2,700 $8,043 $746.2 so192 $740.2 sora. $04.5 $0.0 $85.0 326.0 $191.3 $067.7 1904 738.0 2072.2 297.2 3200.4 2261.7 238.3 1007.8 $2,700 $2,700 $070.4 $1,200.3 $43.2 $1,022.68 $1.2405 $04.5 $40.0 $86.0 $122.6 $121 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG - INTERTIED TO BETHEL + NYAC HYDRO WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 3-€, NO-LOAD GROWTH, 1995 736.0 272.2 ere 3200.4 2201.7 2738.3 1007.8 ese $0704 $1,206.3 $43.2 $1,022.68 $1,240.65 $04.5 $80.0 $85.0 $123.8 $363.3 1906 736.0 e722 2072 3200.4 2201.7 2738.3 1007.8 ese $070.4 $1,200.3 $43.2 $1,022.6 $1,240.65 $04.6 $80.0 $85.0 $126.1 $364.6 1907 736.0 20722 207.2 3260.4 2201.7 2738.3 1007.8 ese $070.4 $1,200.3 $43.2 $1,022.6 $1,240.65 $04.5 $20.0 $85.0 $120.3 $356.8 1998 736.0 2972.2 207.2 3200.4 2201.7 2738.3 1007.8 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $26.0 $1276 $367.1 1909 738.0 20722 207.2 3200.4 2261.7 2738.3 1007.8 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $26.0 $128.0 $358.4 2000 738.0 2972.2 272 3200.4 2201.7 2738.3 1007.8 ees $070.4 $1,208.3 $43.2 $1,022.6 $1,2405 $04.5 $80.0 $85.0 $130.2 $360.7 2001 736.0 2072.2 207.2 3209.4 2261.7 2738.3 1007.8 ees $070.4 $1,200.3 $43.2 $1,022.6 $1,249.65 $04.5 $80.0 $85.0 $131.6 $301.1 2002 736.0 2072.2 207.2 3200.4 2201.7 2738.3 1007.8 ees $079.4 $1,208.3 $43.2 $1,022.6 $1,240.55 $04.6 $80.0 $85.0 $1329 $302.4 2003 736.0 2072.2 207.2 3200.4 5000 2261.7 2738.3 1007.8 ees $070.4 $1,206.3 $43.2 $1,022.6 $1.2405 $04.5 $80.0 $85.0 $134.3, $303.8 736.0 2e722 207.2 3200.4 2201.7 2738.3 1007.8 ees $070.4 $1,208.3 $43.2 $1,022.68 $1,240.56 $04.6 $80.0 $85.0 $136.7 $305.2 738.0 20722 207.2 3200.4 2201.7 2738.3 1007.8 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.5 $04.5 $80.0 $85.0 $137.1 $300.6 736.0 2072.2 207.2 3200.4 2201.7 2738.3 1007.8 ees so704 $1,206.3 $43.2 $1,022.6 $1,.249.5 $04.5 $80.0 $85.0 $1385 $388.0 2007 736.0 20722 2907.2 3280.4 2201.7 2738.3 1007.8 ees $070.4 $1,208.3, $43.2 $1,022.6 $1.2405 $04.5 $80.0 $85.0 $140.0 $300.5 736.0 2722 207.2 3200.4 2201.7 2738.3 1007.8 ees $070.4 $1,206.3 $43.2 $1,022.6 $1,240.65 $04.5 $80.0 $85.0 $141.5 $371.0 736.0 20722 207.2 3200.4 2201.7 2738.3 1007.8 ees $0704 $1,200.3 $43.2 $1,022.86 $1.2405 $04.6 $80.0 $86.0 $1420 $372.4 2010 736.0 2072.2 207.2 3200.4 2201.7 2738.3 1007.8 ees $070.4 $1,206.3 $43.2 $1,022.68 $1.240.5 $04.5 $80.0 $85.0 $1444 $373.9 2011 736.0 2072.2 207.2 2261.7 2738.3, 1007.8 ees $070.4 $1,200.3 $43.2 $1,022.68 $1,240.55 $04.5 $30.0 $85.0 $148.0 $375.5 2012 736.0 2072.2 2072 3200.4 2201.7 2738.3 1007.8 ees $o704 $1,206.3 $43.2 $1,022.6 $1,240.5, $04.5 $80.0 $85.0 $147.5 $377.0 Page 1 of 2 2013 736.0 2o722 2072 2260.4 2201.7 2738.3 1007.8 ees $233.1 $287.1 $43.2 $276.3 $330.3 $04.5 $80.0 $85.0 $1401 $3786 2014 736.0 2e722 207.2 3260.4 2201.7 2738.3 1007.8 ees $0.0 $00 $43.2 $43.2 $43.2 $04.5 $80.0 $26.0 $1607 $3802 €20 6. ANNUAL COST ($1000) 6% 7.0% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL GOST ($1000) o* 7.0% G. PRESENT WORTH ($1000) TOTAL ANNUAL COST 8% 70% D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL COST o% 7.0% 6. ENERGY GOST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH ox 7.0% PRESENT WORTH ENERGY $/KWH 6% 7.0% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1903 91.4140 $1,588.9 $0.0 $1.414.0 $1,586.90 1.4140 $1,588.0 $1,414.0 $1,686.9 27344 $0517 $0.580 $0.517 $0,580 $0.517 $0.580 1904 $1,334.7 $1,501.65 $248 $1,300.89 $1.936.8 $1.271.7 $1.4920 $2,085.6 $3,078.90 2734.4 $0.470 $0.562 $0.405 $0546 $0.082 $1126 1905 $1,376.09 $1,002.09 $200.4 $1,086.5 $1,313.85 $1,024.2 $1,238.1 $3,700.8 $4,317.0 2734.4 $0.307 $0.480 $0.375 $0.453 $1.367 $1.570 1990 $1,377.41 $1,004.1 $203.3 $1,083.09 $1,3100 $001.0 $1,100.60 $4,701.7 $5,510.7 2734.4 $0.306 $0470 $0.303 $0.430 $1710 $2.017 (ALTERNATIVE 3-6) 1907 $1.3784 $1,605.4 $207.2 $000.6 $1,1623 $6.002.3 $0,678.09 27344 $0305 90.478 $0.361 $0,425 $2071 $2443 1998 $1,3707 $1,006.7 $301.2 $1,078.56 $1,305.4 $930.3 $1,126.1 $0,502.6 $7,805.0 2734.4 $0.304 $0.477 $0.340 $0.412 s24n1 $2054 1909 $1,381.0 $1,008.0 $305.3 $1,078.7 $1,302.7 $900.9 $1,001.0 $7,403.5 $8,808.0 2734.4 $0 303, $0.476 $0320 $0.300 $2.740 $3.263 $1,382. $1,000.3 $300.4 $1,072.90 $1,200.09 $872.4 $1,056.9 $8,305.8 $9,062.0 2734.4 $0.302 90.475, $0319 $0.387 $3.050 $3.640 2001 $1,383.66 $1.6106 $313.60 $1,070.0 $1,207.0 $ea47 $1,023.09 $0,2106 $10,0708 2734.4 $0.301 $0.474 $0.309 $0.374 $3. 308 $4014 $1,386.0 $1,0120 $317.8 $1,007.2 $1,204.17 $817.0 $001.9 $10,028.4 $11,008.6 2734.4 $0 300 $0.473 $0 200 $0363, $3667 $4377 $1.380.4 $1,613.3 $3221 $1,064.3 $1,2012 $7a1.0 $060.8 $10,820.3 $12,020.4 27344 $0.389 $0.472 $0.200 $0.361 $3.967 $4.728 $1,387.68 $1,0147 $3205 $1,001.3 $1,288.3 $700.7 $9307 $11,587.0 $13,800.1 2734.4 $0.388 $0.471 $0.280 $0.340 $4.237 $6.000 $1,3802 $1,6101 $330.9 $1,058.3 $1,285.3 $7423 $001.5 $12,320.3 $14,761.68 2734.4 $0.387 $0.470 $0271 $0330 $4500 $6.308 $1,300.6 $1,017.68 $335.3 $1,055.3 $1,282.2 $7186 $873.1 $13,047.09 $15,634.7 27344 $0.386 $0,480 $0.263 $0.310 $4.72 sa.718 2007 $1,302.0 $1.619.0 $330.9 $1,062.2 $1,270.2 $e05.6 $845.7 $13,743.5 $16,480.4 2734.4 $0.386 $0.408 $0.264 $0.300 $6.026 $6.027 $1,303.55 $1,0205 $3445 $1,0401 $1,276.0 $0734 $8100 $14,416.8 $17,204 2734.4 $0.34 $0.407 $0240 $0 300 $5.272 $0,327 $1.305.0 $1,6220 $340.1 $1,045.09 $1,2729 $051.8 $7032 $16,008.6 $18,002.6 2734.4 $0382 $0.465 $0.238 ‘$0.200 $5.511 $0.017 2010 $1,306.5 $1,023.55 $363.8 $1,042.7 $1,200.7 $030.8 $768.2 $15,000.5 $18,800.8 2734.4 $0.381 90.464 $0.231 $0.261 $5.741 $e.808 2011 $1,308.0 $1,625.0 $368.6 $1,030.4 $1,200.4 so10.8 $743.0 $106,310.0 $10,604.7 2734.4 $0,380 $0 403 $0.223 $0.272 $5.005 $7.170 2012 $1,3006 $1,026.60 $303.4 $1,036.2 $1,203.1 $500.0 $720.3 $16,000.0 $20,325.0 2734.4 $0.370 $0.402 $0.216 $0.263 $0.181 $7.433 Page 2 of 2 2013 $054.0 $708.9 $308.3 $286.6 $340.6 $1587 $188.0 $17,050.6 $20,513.6 2734.4 $0.105 $0125 $0,068 $0,000 $6.230 $7.502 2014 $4234 $234 $373.3 $80.1 $601 $200 $260 $17,086.5 $20,640.65 27344 $0018 $o.018 $0.010 $0.010 $0.240 $7,612 1c0 1, LOAD DEMAND A. DEMAND - KWH 8. ENERGY - MWH G. TRANSMISSION LINE LOSSES @ 4% D. TOTAL ENERGY REQUIREMENTS - MWH MWH AVAILABLE FROM NYAC HYDRO. F VILLAGE HYDRO USAGE - MwH @_ SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES HH. MWH PURCHASES FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B.NYAG HYDRO G TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1000) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% ox 7.0% B. INSURANCE G. TOTAL FIKED COST ($1000) ox 7.0% 4, PRODUCTION COSTS ($1000) ‘A. OPERATIONS AND MAINT 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE 8. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000, 1903 738.0 20722 1189 3091.1 oo oo 1645.5 $7,273 $2,700 $0,973 $961.1 $1,000.6 $801.1 $1,060.6 $04.5 $00 $85.0 300.1 $1813 $630.0 1904 750.9 3037.7 121.5 31802 2105.5 304.5 963.7 $2,700 $2,700 $1,004.2 $1.347.8 $43.2 $1,137.4 $1,301.0 $04.5 $40.0 $85.0 $117.9 $307.4 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC - INTERTIED TO BETHEL + NYAC HYDRO WITH SINGLE POLE, 2 WIRE, 3-PHASE TRANSMISSION LINE 1995 706.8 3103.2 1241 3227.3 2236.4 2703.6 ese $1,0042 $1,478 $432 $1,137.4 $1,301.0 $04.5 $80.0 $85.0 $1224 $361.0 1996 780.7 31087 126.7 3205.4 22773 27227 1018.2 ees $1,004.2 $1,3478 $43.2 $1,137.4 $1,301.0 $045 $80.0 $86.0 $127.1 (ALTERNATIVE 4-8) 1997 1998 706.6 810.5 32342 © 32007 1204 1320 33035 34316 5000 5000 23181 23600 2081.0 © 2641.0 10454 © 10727 $0 $0 $0 $0 $0 $0 $1,0042 $1,004.2 $1.3478 — $1,3478 $43.2 $43.2 $1.1374 $1,197.4 $1,991.0 $1,301.0 $045 $04.5 $20.0 $800 $06.0 $95.0 ° o $131.6 $1366 $361.3 $3061 825.4 3306.1 1346 3400.7 1099.9 eee $1,004.2 $1,3478 $43.2 $1,137.4 $1,301.0 $04.5 $80.0 $85.0 $141.6 $371.0 840.3 3430.6 197.2 3507.9 24407 2550.3 19274 ees $1,004.2 $1,347.8 $43.2 $1.197.4 $1,3010 $04.5 $80.0 $85.0 $146.5 $3760 856.2 3496.1 1308 3630.0 2481.6 esi84 1154.4 ese $1,004.2 $1,347.86 $43.2 $1,137.4 $1.301.0 $045 $20.0 $95.0 $151.5 $381.0 870.1 3601.6 142.5 3704.1 26224 24776 1181.6 ess $1,004.2 $1.347.8 $43.2 $1.137.4 $1.3010 $045 $80.0 $85.0 $196.7 885.0 3627.1 146.1 37722 2683.3 2436.7 1208.9 eee $1,004.2 91.3478 $43.2 $1,137.4 $1,301.0 $04.5 $80.0 $85.0 $162.0 $301.6 901.2 3007.9 1470 3845.8 2007.5 23025 1238.3 ess $1.004.2 $1,3478 $432 $1,137.4 $1,301.0 $045 $80.0 $25.0 $107.6 $307.1 917.4 3708.6 150.7 30104 2051.6 248.4 1207.7 eee $1,004.2 $1,347.88 $43.2 $1,137.4 $1,301.0 $04.5 $90.0 $86.0 $173.4 $402.0 933.6 3830.4 153.6 3993.0 2005.8 2304.2 1207.2 ees $1,004.2 $1.347.8 $43.2 $1,137.4 $1,301.0 $04.5 $80.0 $85.0 $1702 $408.7 2007 049.8 3010.1 196.4 4086.5 2730.0 2260.1 1926.6 ess $1,004.2 $1,347.86 $43.2 $1,137.4 $1,361.0 $04.5 $20.0 $85.0 $186.2 $414.7 966.0 3080.9 1502 4140.1 27641 2215.0 1366.1 ees $1,004.2 $1,3478 $43.2 $1.137.4 $1,301.0 $045 $80.0 $85.0 $1013 $420.8 os22 4051.7 162.1 42137 21718 1986.5 eee $1,0042 $1,347.88 $43.2 $1.137.4 $1.301.0 $045 $90.0 $85.0 $197.5 $427.0 2010 08.4 41224 164.9 42873 28724 21276 14149 ese $1.004.2 $1.347.8 $43.2 $1,137.4 $1.391.0 $04.5 $20.0 $85.0 $203.8 $433.3 2011 10146 4193.2 107.7 4300.0 20165 2083.5 1444.4 ese $1,0042 91.3478 $43.2 $1,137.4 $1,301.0 $045 $80.0 $85.0 $2103 $430.8 2012 1030.8 4203.0 170.8 4434.5 2000.7 2030.3 1473.8 ess $1,004.2 $1,347.86 $43.2 $1,137.4 $1,301.0 $045 $800 $85.0 $2168 $446.3 Page 1 of 2 2013 1047.0 4334.7 173.4 4608.1 3004.9 1906.1 1603.2 ees $233.1 $2871 $43.2 $270.3 $330.3 $04.5 $20.0 $85.0 $223.5 2014 1003.8 4404.1 176.2 4680.2 3048.1 1051.0 1632.1 ees $00 $0.0 $43.2 $4.2 432 $045 $800 $85.0 $2302 $460.7 S20 5. ANNUAL GOST ($1000) o% 7.0% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) ox 7.0% . PREGENT WORTH ($1000, TOTAL ANNUAL COST 8% 7.8% D. AGGUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST % 7.0% 6. ENERGY GOST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH ox 7.0% G. PRESENT WORTH ENERGY $/KWH 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1903 $1,501.0 $1,700.6 $00 $1,601.0 $1,7006 $1,601.0 $1,700.68 $1,601.0 $1,7006 27344 $0.640 $0.022 $0540 $0.022 $0540 $0.022 1904 91.4448 $1,008.4 $31.7 $1.413.0 $1,000.68 $1,371.90 $1.018.1 $2.872.9 $3.318.7 2704.7 $0.506 $0.506 $0.401 $0.579 $1.040 $201 1995 $1,480.3 $1,742.06 $202.0 $1.107.3 $1,450.90 $1.128.6 $1,307.6 $4,001. $4,086.3 $0419 $0.508 $0.305 $0470 $1.435 ‘$1.080 1996 $1,404.0 $1,747.68 $2016 $1,202.4 $1,466.0 $1,100.3 $1,3324 $5,101.8 $0,018.7 2015.2 $o.412 $0.400 $0.377 $0467 $1813 $2137 (ALTERNATIVE 4-8) 1907 1998 $1,4087 — $1,503.5 $1,7523 $1,7671 $2011 $200.5 $1,207.6 $1.2130 $1,401.2 $1,406.56 $1.0720 $1,046.3 $1,208.2 $1,266.1 $0,1747 $7,221.1 $7,310.09 $8,582.0 20754 © 30357 $0.406 $0400 $0,401 $0.483 $0.361 $0345 $0496 $0417 $2173 $2518 $2673 $2,000 1990 $1,608.4 $1,7620 $280.0 91.2185 $1,020.5 $1,232.86 $0,241.65 $0,814.68 $0,304 $0.475 $0.330 $0. 308 $2.847 $3.388 $1,513.4 $1,706.0 $2802 $1,2242 $1.4778 $006.4 $1,201.6 $9,238.9 $11,016.4 3186.2 $0,388 $0,408 $0315 $0.381 $3.103 $3.700 2001 $1,518.4 $1,7720 $288.4 $1.2300 $1,483.6 $071.0 $171.2 $10,207.09 $12,187.56 3210.4 $0362 $0.401 $0.302 $0,304 $3.405 $4133 $1,623.60 $1,772 $287.6 $1.236.0 $1,480.68 $047.3 $1,141.7 $11,185.2 $13,202 32767 $0.377 90.455 $0.280 $0348 $3.754 $4482 $1,628.09 $1,762.4 $260.6 $1.242.2 $1,405.86 $024.3 $1,113.0 $12,0706 $14,4422 3336.0 $o372 90.448 $0277 $0.334 $4.03) $4815 $1,634.5 $1,788.1 $ees2 $1,240.3 $1,602. $002.5 $1,085.7 $12.0820 $15,627.0 3402.0 $0307 $0.442 $0205 $0.310 $4.200 $6.134 $1,840.35 $1,793.09 $283.8 $1.256.5 $1.810.1 $881.3 $1,050.2 $13,803.3 $16,987.1 3407.1 $0.02 $0.436 90.254 $0 305 $4.560 $5.440 $1,646.1 $1,700.7 $262.2 $1,2040 $1,017.56 $800.7 $1,033.4 $14,724.0 $17,020.5 $0358. $0.430 $0244 $0.203 $4704 $6.732 2007 $1,952.1 $1,806.7 $280.5 $1,271.6 $1,926.2 $8407 $1,008.3 $15,504.7 $18,628.8 3607.3 $0 353 0.424 $0234 $0.280 $5.028 $6.013 $1,958.2 $1,811.68 $278.7 $1.2705 $1,533.14 $821.2 $084.0 $10,385.0 s9.0128 90.340 0.419 $0.224 $0200 $5.252 $0.281 $1,504.4 $1,818.0 $2709 $1,287.66 $1,641.1 $802.3 $060.4 $17,168.3 $20,673.2 3727.5 90.345 90.413 $0215 $0268 $5.407 $6.530 $1,870.7 $1,824.3 $274.9 $1,205. $1.540.4 $784.0 $037.4 $17,0722 $21,5106 37026 90.342 $0.400 $0.207 $0.247 $5.074 $0,780 2011 $1,977.2 $1,830.7 $2728 $1.304.3 $1.657.9 $700.1 $015.1 $18,738.4 $22,426.7 3887.7 $0.338 $0.404 $0.100 $0237 $6.72 $7,023 $1,683.7 $1,837.3 $270.7 $1,313.0 $1,900.6 $748.8 $803.4 $19,487.2 $23,310.1 $0.335 $0.300 $0.191 $0.228 $0.063 $7.25) Page 202 2013 $720.3 $783.3 $208.4 $400.0 $615.0 $295.2 $285.1 $10,7424 $23,604.2 3087.0 90.116 $0.120 $0.004 $0.071 $0127 $7.322 2014 $602.9 $502.9 $206.1 $230.8 $2368 $127.3 $127.3 $19,800.7 $23.731.5 4051.7 $0.058 $0.058 $0.031 $0.031 $0.150 $7,354 9¢0 1, LOAD DEMAND A. DEMAND - KWH. B. ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 4% D. TOTAL ENERGY REQUIREMENTS - MWH E MWH AVAILABLE FROM NYAG HYDRO F. VILLAGE HYDRO USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES: 2 INVESTMENT COSTS ($1000, A. TRANSMISSION LINE B.NYAC HYDRO C. TOTAL INVEST. COST ($1000) 3. FKED COSTS ($100, A DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% o% 7.0% B. INSURANCE G. TOTAL FIKED COST ($1000) 5% 7.0% 4, PRODUCTION COSTS ($1000) A. OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATVE B. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. GOSTS ($1000) 1903 738.0 20722 118.9 3001.1 00 00 1845.5 $9,533 $2,700 $12,233 $1,056.2 $1,301.0 $1,058.2 $1,301.0 $64.5 $0.0 $26.0 300.1 $181.3 $639.9 1994 760.9 3037.7 121.5 3150.2 2600 2105.5 304.5 963.7 $0 $2,700 $2,700 $1,280.3 $1,988.1 $43.2 $1,3325 $1,631.3 $04.5 $40.0 $86.0 $117.9 $307.4 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC - INTERTIED TO BETHEL + NYAG HYDRO WITH SINGLE POLE, 3 WIRE, 3-PHASE TRANSMISSION LINE 1995 705.8 3103.2 1241 3227.3 2236.4 27636 990.9 ess $1,280.3 $1,988.1 $43.2 $1,332.5 $1,031.3 $04.5 $80.0 $05.0 $1224 $361.0 1906 780.7 3108.7 1267 3205.4 2277.3, 2722.7 1018.2 ees $1,280.3 $1,988.1 $43.2 $1,392.5 $1,631.3 $04.5 $80.0 $85.0 $127.1 $360.6 (ALTERNATIVE 5:A) 1997 1998 705.8 8105 32342 © 3200.7 1204 132.0 33035 3431.6 5000 6000 23181 2380.0 2081.9 2841.0 1045.4 1072.7 $0 $0 $0 $0 to $0 $1,2803 $1,280.3 $1,9881 $1,588.1 $43.2 $43.2 $1,3325 $1,332.56 $1,631.3 $1,631.3 $04.5 $04.5 $20.0 $80.0 $25.0 $25.0 ° ° $131.8 $136.6 $361.3 $366.1 1999 825.4 3306.1 134.6 3499.7 2309.8 2600.2 1099.9 ees $1,289.35 $1,988.1 $43.2 $1,332.56 $1,631.3 $04.5 $20.0 $86.0 $141.5 $371.0 840.3 3430.0 137.2 3687.0 24407 2550.3 1927.1 eee $1,280.3 $1,988.1 $43.2 $1,332.5 $1,031.3 $04.5 $80.0 $86.0 $146.5 $376.0 2001 855.2 3496.1 130.8 3636.0 2481.6 2518.4 1154.4 ees $1,280.3 $1,988.1 $43.2 $1,332.5 $1,6313 $04.5 $80.0 $85.0 $151.5 $381.0 2002 870.1 3601.6 1425 3704.1 2622.4 2477.6 11816 ees $1,280.3 $1,588.1 $43.2 $1,332.65 $1,631.3 $04.5 $80.0 $85.0 $156.7 $386.2 885.0 3627.1 148.1 37722 2563.3 2436.7 1208.9 ees $1,260.3 $1,688.1 $43.2 $1,332.65. $1,631.3 $04.5 $80.0 $85.0 $102.0 $301.5 2004 901.2 3607.0 147.9 3845.8 2607.5 2302.5 1238.3, ses $1,200.3 $1,588.1 $43.2 $1,332.5 $1,031.3 $048 $80.0 $85.0 $107.6 $307.1 017.4 3708.6 160.7 3019.4 2051.6 2348.4 1267.7 eee $1,280.3 $1,988.1 $43.2 $1,332.5 $1,631.3 $64.5 $80.0 $85.0 $173.4 $402.0 933.6 3830.4 183.6 3903.0 2605.8 2304.2 1207.2 ees $1,280.3 $1,988.1 $43.2 $1,332.5 $1,631.3 $04.5 $20.0 $85.0 $1702 $408.7 2007 949.8 3010.1 156.4 4086.5 2730.0 2260.1 1326.6 ees $1,280.3 $1,688.1 $43.2 $1,332.65 $1,631.35 $04.5 $80.0 $86.0 $188.2 $414.7 966.0 30809 190.2 4140.1 2784.1 2216.0 1366.1 ess $1,280.3 $1,988.1 $43.2 $1,332.5 $1,031.3 $04.5 $20.0 $85.0 $191.3 $4208 e822 4051.7 1621 4213.7 2028.2 2171.8 1386.5 ese $1,260.3 $1,588.1 $43.2 $1,332.5, $1,631.3 $04.5 $20.0 $85.0 $107.5 $427.0 2010 998.4 412204 104.9 4287.3 2872.4 2127.6 1414.0 ees $1,260.3 $1,588.1 $43.2 $1,332.5 $1,631.3 $04.65 $80.0 $85.0 $203.8 $433.3 2011 1014.6 4193.2 107.7 4360.9 2016.5 2083.5 1444.4 ess $1,280.3, $1,988.1 $43.2 $1,332.65 $1,631.3 $04.5 $80.0 $85.0 $210.3 $430.8 2012 1030.8 4203.0 17068 4434.5 2060.7 2030.3 1473.8 ees $1,280.3 $1,988.1 $43.2 $1,332.65 $1,631.3 $04.5 $80.0 $85.0 $216.8 $446.3 Page 1 of 2 1047.0 4334.7 173.4 4508.1 3004.0 1995.1 1603.2 ees $233.1 $287.1 $43.2 $270.3 $330.3 $04.5 $80.0 $85.0 $223.5 $453.0 2014 1063.8 4404.1 176.2 4680.2 1051.0 1932.1 ses $00 $0.0 $43.2 $43.2 $43.2 $04.5 $800 $85.0 $2302 $450.7 Lou 5. ANNUAL COST ($1000, ox 7.0% A CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000, 6% 70% G. PRESENT WORTH ($1000) TOTAL ANNUAL GOST ox 70% D. ACCUMULATED PRESENT ($1000, WORTH TOTAL ANNUAL COST * 70% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH o% 7.0% C. PRESENT WORTH ENERGY $/KWH 6% 7.8% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1993 $1.608.1 $1,040.09 $0.0 $1,600.1 $1,040.90 $1,606.1 $1,040.90 27344 $0.620 $0710 $0.620 sa710 $0.620 $0710 1994 $1,630.90 $1.938.7 $17 $1,008.2 $1,907.0 $1,961.3 $1,851.4 $3,257.55 $3.7024 27047 $0875 $0.682 $0.559 $0602 $1179 $1.372 1095 $1,0845 $1,083.3 $202.0 $1,3125 $1,504.2 $4.570.0 $5,386.5 $o.488 $o.se2 $0.40 $0 558 $1.630 sen 1906 $1,0801 $1,087.90 $201.6 $1,307.5 $1,006.3 $1,278.9 $1,562.4 $5.048.0 $0,938.0 2eis.2 $0470 $0.582 $0439 $0533 $2077 $2463 (ALTERNATIVE 5A) 1907 1908 $1,0038 $1.008.6 $1.0026 $1.007.4 $eo11 $2005 $1,.4027 © $1,408.1 $1.701.5 $1,708.09 $1.2403 $1.2140 $1,511.8 $1.4724 $7.005.2 $8,3008 $8.4507 $0,023.1 2075.4 © 3036.7 $0471 $0.484 $os72 $0.82 $0419 © $0.400 $0.508 $0.485 $2408 $2,000 $2071 $3.456 1999 $1.703.5. $2,002 3 $280.9 1.4136 $724 $1,183.09 91.4341 $9,.403.7 $11,367.2 $0.467 $0.563 $0,382 $0.463 $3.270 $3,920 $1,708.55 $2,007.3 $2002 $1.4103 $1.7181 $1.154.0 $1.307.0 $10,047.7 $12,754.2 3186.2 $0.450 $0.544 $0.300 $0443 $3.044 $4,302 1.71368 $2.0124 $288.4 $1.425.1 $1.724.0 $1.125.0 $1,300. $11,727 $14.1151 32184 $0.443 $0536 $0.360 $0423 $3.904 $4785 $7187 $2,017.65 $287.0 $1.431.2 $1.730.0 $1,006.90 $1,326. $12,8006 $15,441.0 32767 $0.437 $0628 $0335 $0.405 $4320 $5.190 $1,724.00 $2.0228 $280.0 $1.437.3 $1.730.2 $1,000.5 $1,201. $13,030.1 $16,7328 3336.9 $0431 $0.920 $0.321 $0.387 $4.040 $5.677 91,7206 $2,028.5 $205.2 $1.444.4 $7432 $1,043.5 $1,260.3 $14,0826 $17,002.2 3402.0 90.425 $0512 $0307 $0370 $4.056 $5.047 $1.736.4 $2.034.2 $283.8 $1.461.6 $1,750.5 $1.0182 $1,227.7 $16,000.8 $19.2100 3487.1 $0.419 $0.505 $0.204 $0.364 $5.250 $6.301 $1.741.3 $2,040.1 ses22 $1.469.1 $1,757.90 $093.6 $1.197.0 $16,004.3 $20,417.0 $0.413 $0408 $0.281 $0.330 $6.931 $6.640 2007 $1,747.22 $2.046.1 $280.5 $060.7 $1.1672 $17.004.0 $21,584.2 3697.3 $0.408 $0491 $0.270 $0324 ‘$5.801 $8.00 $1,753.3 $2,0521 $2787 $1,474.68 $1,773.4 $948.5 $1,138.3 $iaci0s $22,7225 3002.4 $0.403 $0.484 $0258 $0311 $6.050 $7.276 $1.750.5 $2,068.3 91.4827 $1,781.56 $023.0 $1102 $19.8344 $23,632.68 3727.5 $0.308 $0.478 $0.24 $0208 $6.307 $7,973 $1,706.90 $2,004.7 $2740 $1,400.09 $1,7808 ‘$902.0 $1,082.8 $20,736.5 $24,015.65 3702.6 $0.303 $0.472 $0.238 $0,206 $0.545 $7,850 2011 $1,723 $2.071.1 se728 $1.400.4 $1,7083 $9808 $1,066.3 $21,617.3 $26,971.8 3887.7 $0.389 $0406 $0.28 $0274 $0.73 $8.133 $1,788 $2.077.7 $270.7 $1,908.2 $1,807.0 $880.1 $1,030.5 $22,477.3 $27,002. 3 3022.8 $0394 $0.461 so2190 $0 263 $0.002 $8.305 Page 2ot2 2013 $7203 $783.3 $208.4 $400.9 $515.0 $255.2 $285.1 $22,732.06 $27,267.4 3087.0 0.116 $0.120 $0.04 $0071 $7,058 $8.407 2014 502.6 $502.9 $2061 $2368 $2368 $1273 $1273 $22,880.9 927.4147 4051.7 $0.058 $o.058 $0.031 $0.031 $7,088 $8.408 8cu 1, LOAD DEMAND A. DEMAND - KWH 8. ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 4% 0. TOTAL ENERGY REQUIREMENTS - MWH E MWHAVALABLE FROM NYAC HYDRO F. VILLAGE HYDRO USAGE - WH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. WH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B. NYAG HYDRO G. TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1000, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 5% 7.0% B. INSURANCE G. TOTAL FED COST ($1000) 5% 7.0% 4, PRODUCTION GOSTS ($1000) A. OPERATIONS AND MAINT 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE. B. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1009, 736.0 2e722 1189 3001.1 oo 00 1845.6 $0,873 $2,700 $12,673 $1,085.6 $1,.337.2 0 $1,085.6 $1,337.2 $04.6 $0.0 $85.0 300.1 $181.3 $630.0 1904 750.9 3037.7 121.5 3150.2 2105.5 304.5 963.7 $2,700 $2,700 $1,318.7 $1,0243 $43.2 $1,361.9 $1,007.5 $04.5 $40.0 $85.0 $117.0 $307.4 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC - INTERTIED TO BETHEL + NYAG HYDRO WITH H-FRAME, 3 WIRE, 3-PHASE TRANSMISSION LINE 1995 706.8 3103.2 124.1 3227.3 2236.4 2763.6 990.9 ses $1,318.7 $1,024.3 $43.2 $1,361.90 $1,007.5 $04.5 $80.0 $85.0 $122.4 $351.9 1906 780.7 3168.7 120.7 3205.4 2277.3 2722.7 1018.2 eee $1,318.7 $1,024.3 $43.2 $1,361.90 $1,067.5 $64.5 $80.0 $85.0 $127.1 $356.6 (ALTERNATIVE 6-0) 1997 1998 705.6 810.5 32342 © 3200.7 1204 1320 3363.5 3431.6 5000 5000 23181 23600 2081.9 2041.0 10454 = 10727 $0 $0 $0 $0 $0 $0 91.3187 $1,187 $1,624.3 $1,624.3 $43.2 $43.2 $1,361.0 $1,361.90 $1,667.5 $1,067.55 $04.5 $64.5 $90.0 $80.0 $86.0 $85.0 ° ° $131.8 $136.6 $361.3 $306.1 1999 825.4 3306.1 134.8 3400.7 2300.8 2600.2 1090.9 eee $1,3187 $1,624.3 $43.2 $1,361.09 $1,607.5 $04.5 $80.0 $86.0 1415 $371.0 e403 3430.6 137.2 3567.9 2440.7 2660.3, 1127.4 ess $1,318.7 $1,024.3 $43.2 $1,361.90 $1,067.5 $04.6 $80.0 $85.0 $146.5, $376.0 2001 955.2 3496.1 1308 3636.0 2481.6 2518.4 1154.4 ees $1,318.7 $1,624.3 $43.2 $1,361.09 $1,667.5 $04.5 $80.0 $26.0 $151.5 $381.0 2002 870.1 3661.8 142.5 3704.1 6000 2622.4 24776 1181.6 ees $1,318.7 $1,024.3 $43.2 $1,361.90 $1,007.5 $04.5 $80.0 $85.0 $186.7 $396.2 885.0 36271 145.1 3772.2 2563.3 2430.7 1208.9 ees $1.3187 $1,624.3 $43.2 $1,361.0 $1,607.5 $04.5 $80.0 $86.0 $162.0 $391.5 901.2 3007.9 1479 3846.8 2607.5 2302.5 1238.3 ees $1,3187 $1,024.3 $43.2 $1,361.90 $1,067.5 $04.6 $80.0 $85.0 $167.6 $307.1 917.4 3768.0 180.7 3010.4 2051.6 2348.4 1267.7 eee $1.318.7 $1,624.3 $43.2 $1,361.9 $1,607.56 $04.5 $80.0 $85.0 $173.4 $402.0 933.6 3830.4 193.6 3093.0 2005.8 2304.2 1207.2 ees $1.318.7 $1,024.3 $43.2 $1,361.0 $1,067.5 $64.5 $80.0 $86.0 $1702 $408.7 2007 o4o.8 30101 196.4 4006.5 2730.0 2260.1 1326.6 ess $1,3187 $1,624.3 $43.2 $1,361.9 $1,667.56 $04.5 $80.0 $85.0 $185.2 $414.7 968.0 3980.9 190.2 4140.1 2784.1 2216.9 1366.1 ees $1,318.7 $1,024.3 $43.2 $1,361.9 $1,007.5 904.5 $80.0 $85.0 $101.3 $420.8 922.2 4051.7 1621 42137 2928.2 2171.8 1386.5 ees $1.318.7 $1,624.3 $43.2 $1,361.9 $1,607.5 $04.5 $80.0 $86.0 $197.5 $427.0 2010 908.4 41204 164.9 4287.3 2872.4 2127.6 1414.9 ees $1,318.7 $1,624.3, $43.2 $1,361.9 $1,007.5 $04.5 $80.0 $85.0 $203.8 $433.3 2011 1014.6 41032 107.7 4300.9 2016.5 1444.4 eee $1.318.7 $1,624.3 $43.2 $1,301.9 $1,007.5 $04.5 $80.0 $95.0 $210.3 $430.8 2012 1030.8 4203.0 170.6 4434.5 2060.7 2030.3 14738 ess $1,318.7 $1,024.3 $43.2 $1,361.0 $1,067.5 $04.5 $80.0 $85.0 $216.8 $446.3 Page 1 of 2 2013 1047.0 4334.7 173.4 4606.1 3004.0 1996.1 1603.2 ees $233.1 $287.1 $43.2 $270.3 $330.3 $04.5 $80.0 $86.0 $223.6 $483.0 2014 1063.8 4404.1 176.2 4680.2 3048.1 1951.0 1932.1 bes $0.0 $0.0 $43.2 $43.2 $43.2 $04.5 $80.0 $85.0 $230.2 $450.7 6c0 6. ANNUAL GOST ($1000) 6% 70% A. GREDIT FOR GALES: TO BETHEL UTILITIES B. TOTAL ANNUAL GOST ($1000) o% 7.0% C. PRESENT WORTH ($1000) TOTAL ANNUAL COST 5% 7.0% D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL COST 5% 7.0% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $vKWH o* 7.6% G. PRESENT WORTH ENERGY #/KWH o% 7.6% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH. 5% 7.0% 1903 $1,725.5 $1,077.11 $0.0 $1,725.5 $1,077.1 $1,725.5 $1,077.11 $1,726.5 $1,071 2734.4 $0.631 $0.723 $0.63 $0.723 $0.031 $0.723 1994 $1,000.3 $1,974.9 $31.7 $1.637.5 $1,043.1 $1,580.8 $1,880.5 $3.315.3, $3,803.6 27047 $0,586 $0,605 $0.509 $0675 $1.200 $1,308 1995 $1,7138 $2,0104 $202.0 $1,421.68 $1,727.4 $1,340.2 $1,028.3 $4,056.5 $5,401.09 2864.9 $0.408 $0,608 $0469 $0.670 $1.009 $1.008 1906 $1,718.4 $2,024.1 $201.6 $1,426.0 $1,732.5 $1,305.68 $1,685.65 $5.061.3 $7,077.3 2015.2 $0.480 $0.504 $0.448 $0544 $2.117 $2512 (ALTERNATNE 6:4) 1997 $1,723.2 $2,028.8 $2011 $1,432 $1,737.7 $1,2724 $1,543. $7.233.7 $8,621.3 2075.4 $0.481 $0584 $0428 $0.510 $2.545 $3.031 1998 $1.728.0 $2,033.6 $2005 $1.437.4 $1,743.1 $1,240.0 $1,503.6 $8,473.6 $10,124.8 3036.7 $0.474 $0.674 $0.408 $0496 $2.953 $3.526 1999 $1,732.9 $2,038.5 $280.0 $1,443.0 $1,748.6 $1.208.5 $1,404.4 $0,682.1 $11,680.3 3095.9 $0466 $0565 ‘$0.30 $0.473 $3.344 $3.900 $1,737.86 $2,043.5 $289.2 $1,448.7 $1,754. $1,1770 $1,420.4 $10,860.0 $13,0156 3156.2 $0.45 $0.556 $0.373 $0.452 $3.717 $4.451 2001 $1,742.9 $2,048.55 $288.4 $1,454.5, $1,760.1 $1,148.2 $1,380.5 $12,008.2 $14,405.1 3218.4 $0,452 $0.547 $0.367 $0.432 $4074 $4.883 2002 $1,748.1 $2,083.7 $287.6 $1,460.56 $1,706.1 $1104 $1,363. $13,127.65 $15,768.7 3276.7 $0.446 $0.530 $0.342 $0.413 $4.415 95.297 2003 $1,753.3 $2,050.0 $286.6 $1,466.7 $1,723 $1,091.4 $1,.318.8 $14,2189 $17,077.65 3336.9 $0.440 $0.531 $0.327 $0. 305, $4,743 $8.002 $1,750.0 $2,064.6 $285.2 $1.473.8 $1.770.4 $1,064.7 $1,285.5 $15,283.6 $18,362.90 3402.0 $0.433 $0.523 $0.313 $0.378 $6.055 $6.070 $1,764. $2,070.4 $283.8 $1,481.0 $1,786.6 $1,038.7 $1,253.14 $10,322.3 $19,616.0 34071 $0.427 $0.515 $0.300 $0.361 95.365 $0.431 $1,770.68 $2,076.2 $282.2 $1.488.4 $1,704.1 $1,013.68 $1,221.7 $17,336.0 $20,837.7 3632.2 $0.421 $0.508 $0.287 $0.346 $5.042 90.777 2007 $1,776.86 $2,082.2 $280.5 $1,496.1 $1,801.7 $080.1 $1,191 $18,325.0 $22,028.86 3697.3 $0418 $0.501 $0.276 $0.331 $6.017 $7.108 $1,782.7 $2,088.3 $278.7 $1,803.09 $1,200.6 $065.3 $1,161.5 $19,200.3 $23,100.3 3662.4 $0.411 $0.404 $0.204 $0.317 $6.181 $7.425 $1,788.0 $2,004.56 $278.0 $1,.5120 $1,817.68 $042.2 $1,132.7 $20,232.56 $24,323.0 3727.5 $0.408 $0.488 $0.263 $0.304 $6.433 $7,720 $1,706.2 $2,100.8 $274.9 $1,820.3 $1,826.09 soi9.8 $1,104.7 $21,182.3 $25,427.7 3702.6 $0.401 $0.481 $0.243 $0.201 $6.676 $8.020 $1,801.86 $2,107.3 $272.8 $1.628.8 $1,834.4 $898.0 $1,077.58 $22,050.4 $20,605.2 3867.7 $0 306 $0.476 $0.233 $0.270 $6.900 ‘$8,300 2012 $1,808.2 $2,113.86 $270.7 $1,637.5 $1843.22 $9768 $1,061.1 $22,027 2 $27,556.4 3022.8 $0.302 $0.470 $0.224 $0.268 $7.132 $e.568 Page 2 ot 2 2013 $720.3 $783.3 $268.4 $460.0 $515.0 $256.2 $286.1 $23,1824 $27,841.65 3087.0 $0116 $0.120 $0.064 $0.071 $7196 $8.630 2014 $502.0 $502.9 $206.1 $236.8 $236.8 $127.3 $127.3 $23,300.7 $27,068.8 4051.7 $0.058 $0.058 $0.031 $0.031 $7,228 $8.670 Oto 1. LOAD DEMAND A. DEMAND - KWH B ENERGY - MWH G. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH MWH AVAILABLE FROM NYAC HYDRO F. VILLAGE HYDRO USAGE - MWH @._ SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES HH. MWH PURCHASES FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B.NYAC HYDRO . TOTAL INVEST. COST ($100 3. FKED COSTS ($1009) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% % 70% G. TOTAL FKED GOST ($1000) o% 7.0% 4, PRODUCTION COSTS ($1000, ‘A. OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE 8 SELF GENERATION C. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000, 1903 607.0 22222 2222 24444 oo oo 12222 $3,008 $3,008 $204.7 $320.1 $204.7 $320.1 $04.5 $0.0 $55.0 2444 $1412 $505.2 1904 622.0 2287.7 228.8 2518.5 00 oo 2616.5 ees $204.7 $326.1 $00 $204.7 $326.1 $045 $0.0 $660 $208.8 $408.3 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK WITH A-FRAME, SWGR TRANSMISSION LINE 1995 537.0 2363.2 235.3 00 oo ees $204.7 $326.1 $0.0 $2047 $326.1 $64.5 $0.0 $55.0 $300.4 $100 1996 552.0 24187 241.0 oo oo 2000.5 ees $204.7 $320.1 $264.7 $326.1 $045 $0.0 $95.0 $3121 $431.6 (ALTERNATIVE 7-A) 1907 1998 607.0 $82.0 24842 © 2640.7 248.4 255.0 27326 © 2804.6 ° ° 00 00 00 00 27326 © 2804.6 so $0 to $0 $0 $0 $204.7 © $204.7 $320.1 $326.1 $0.0 $0.0 $2047 $2047 $3201 $320.1 $04.5 $04.5 $0.0 $0.0 $56.0 $95.0 ° ° $3241 $336.4 $443.60 $455.0 + INTERTIED TO BETHEL 1990 2000 997.0 0120 2015.1 2080.6 201.5 208.1 2870.7 2048.7 ° ° 00 oo oo 00 2670.7 © 2048.7 $0 $0 $0 $0 $0 $0 $204.7 © $204.7 $320.1 $326.1 $0.0 $0.0 $204.7 $204.7 $3201 $326.1 $04.5 $04.5 $0.0 $0.0 $560 $95.0 ° ° $s488 © $301.5 $4083 © $481.0 2001 627.0 2746.1 2746 3020.7 oo oo 3020.7 ess $204.7 $320.1 $0.0 $264.7 $3261 $04.5 $0.0 $95.0 $374.5 $404.0 042.0 2611.0 281.2 3092.8 oo oo 3092.8 ses $204.7 $326.1 $0.0 $204.7 $3261 $04.5 $0.0 $95.0 $387.6 $607.1 657.0 28771 287.7 3104.8 oo 00 31048 ees $204.7 $320.1 $0.0 $2047 $320.1 $04.5 $0.0 $96.0 $401.1 $520.6 073.1 2047.0 2048 3242.6 oo 00 3242.6 ees $204.7 $326.1 $00 $204.7 $326.1 $04.5 $0.0 $55.0 $418.5 osg2 3018.6 301.9 3320.5 oo 00 ees $204.7 $320.1 $0.0 $204.7 $820.1 $04.5 $0.0 $65.0 $430.2 706.3 3080.4 308.9 3308.3 oo oo ees $2047 $326.1 $0.0 $204.7 $326.1 $045 $00 $550 $445.2 $904.7 2007 721.4 3160.1 316.0 3470.2 oo oo 3476.2 eee $204.7 $326.1 $0.0 $204.7 $320.1 $04.6 $0.0 $65.0 $460.5 $580.0 737.5 3230.9 323.1 00 oo 3654.0 ses $204.7 $326.1 $204.7 ‘$3201 $04.5 $0.0 $95.0 $476.1 $505.6 763.6 3301.7 3302 3631.8 0.0 00 ees $204.7 $326.1 $0.0 $204.7 $320.1 $04.5 $0.0 $65.0 $402.0 $011.5 709.7 33724 337.2 3708.7 oo oo 3700.7 ees $2047 ‘$3261 soo $204.7 $326.1 $04.5 $0.0 $55.0 $608.2 $027.7 2011 785.8 3443.2 344.3 3787.5 oo oo 3787.5 ees $2047 $320.1 $2047 $320.1 $04.5 $0.0 $55.0 $524.6 $0447 2012 801.9 3613.0 3514 3805.3 oo oo 3805.3 ees $2047 $320.1 $0.0 $2047 $326.1 seas $00 $65.0 $541.4 $000.0 Paget of 2 2013 818.0 3684.7 368.5 3043.2 oo oo 3043.2 ees $00 $0.0 $00 $00 $00 $045 $0.0 $65.0 $958.6 $0781 2014 es 30421 304.2 4006.3 oo oo ess $00 $00 soo $0.0 soo $04.5 $0.0 $55.0 $973.0 $003.4 Tto 5. ANNUAL COST ($1000) 6% 7.6% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) 8% 7.0% G. PRESENT WORTH ($1000) TOTAL ANNUAL COST 6% 7.0% D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST 5% 7.0% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $7KWH 5% 7.6% C PRESENT WORTH ENERGY $/KWH 8% 7.0% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 6% 7.6% $760.9 $831.2 $0.0 $760.0 $831.2 $760.6 $831.2 $760.0 $831.2 2044.4 $0.377 $0.407 $0377 $0.407 $0.377 $0.407 1994 $073.0 $734.4 $0.0 $673.0 $734.4 $053.4 $713.0 $1.423.3 $1,544.2 2104.7 $0.320 $0.34 $0.310 $0.339 $0.687 $0.745 1905 $084.6 $746.9 $00 $084.6 $745.9 $045.3 $703.1 $2,008.6 $2,247.4 2164.9 $0316 $0.345 $0.208 90.325 $0.085 $1.070 1996 $006.4 $787.7 $0.0 $008.4 $787.7 $637.3 $003.4 $2,705.90 $2,0408 $0.313 $0.341 $0.286 $0.312 $1.272 $1.382 (ALTERNATIVE 7-A) 1907 $708.4 $700.7 $0.0 $708.4 $700.7 $620.4 $683.9 $3,336.3 $3.624.7 2285.4 $0310 $0.337 $0.275 $0,200 $1.47 $1,081 1998 $720.0 $781.0 $0.0 $7206 $781.9 $021.6 $074.5 $3,056.8 $4.200.2 2345.7 $0.307 $0.333 $0.265, $0288 $1812 $1,959 1999 $733.0 $704.4 $0.0 $733.0 $704.4 $013.9 $005.3 $4,570.7 $4,004.5 2406.9 $0.305 $0,330 $0.265 $0.277 $2.067 $2,245 $746.7 $807.1 $00 $745.7 $807.1 $608.4 $056.2 $5,171 $5,620.7 2406.2 $0.302 $0.327 $0.246 $0.266 $2.313 $2611 2001 $758.7 $820.0 $0.0 $758.7 $820.0 $508.9 $647.3 $5.776.0 $0,268.0 2626.4 $0.300 $0.325 $0.237 $0.266 $2.560 $2.767 $771.9 $033.2 $0.0 $771.0 $833.2 $601.6 $638.6 $6,367.6 $8,006 6 2686.7 $0.208 $0.322 $0.220 $0.247 $2770 $3014 2003 $785.3 $846.6 $0.0 $785.3 $846.6 $084.3 $630.0 $6,961.9 $7,536.6 2646.0 $0.207 $0.320 $0.21 90.238 $2,999 $3.262 2004 $709.7 ‘$861.1 $0.0 $700.7 $801.1 $977.7 $6221 $7,620.7 $8,198.7 e720 $0.295 $0318 $0.213 $0.220 sa.2i2 $3.482 $814.5 $875.8 $0.0 $8145 $876.8 go71.2 $014.3 $8,100.90 $9,720 2777.1 $0.203 $0.315 ‘$0,206 $0.221 $3.418 $3.703 $820.5 $800.8 $0.0 ge205 $800.8 $604.8 $606.6 $8,605.7 $9,370.5 28422 $0202 $0.313 $0.199 $0.213 $3.017 $3.916 2007 $844.7 $906.1 $0.0 $e44.7 $006.1 $558.5 $500.0 $9,224.2 $9,078.6 2007.3 $0.201 $0312 $0.192 $0.206 $3.809 $4122 $860.3 $021.7 $00 $860.3 $021.7 $9622 $501.6 $9,776.4 $10,570.2 2072.4 $0.280 $0.310 $0.186 $0.199 $3.005, $4,321 $270.2 $037.5 $0.0 $876.2 $037.6 $546.0 $584.2 $10,322.4 $11,1544 3037.6 $0268 $0 300 $0.180 $0.192 $4.176 $4514 2010 $802.4 $063.7 $0.0 se024 $053.7 $639.9 $877.0 $10,802.3 $11,731.4 3102.6 $0.288 $0.307 $0.174 $0.188 $4,349 $4,700 2011 $008.9 $070.2 $00 ‘$008.9 $070.2 $633.9 $509.0 $11,306.2 $12,301.3 3167.7 $0.287 $0.306 $0.169 $0.180 $4.517 $4.880 2012 $025.7 $087.0 $0.0 $025.7 $087.0 $927.9 $962.0 $11,024.1 $12,804.2 3232.8 $0.296 $0.305 $0.163 $0.174 $4.680 $5.054 Page 2 of 2 2013 $078.1 $678.1 $00 $678.1 $078.1 $376.4 $376.4 $12,200.55 $13,2306 3297.0 $0.206 $0,206 $0114 $0.114 $4704 $6.108 2014 $003.4 $003.4 $00 $003.4 $003.4 $3727 $3727 $12,0722 $13,0124 3360.7 $0.207 $0.207 $0111 $0111 $4,905 95.279 cto 1. LOAD DEMAND A. DEMAND - KWH B. ENERGY - MWH C, TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH & MWHAVAILABLE FROM NYAC HYDRO F. VILLAGE HYDRO USAGE - MWH_ G. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B.NYAC HYDRO. . TOTAL INVEST. COST ($1009, 3. FKED COSTS ($1000) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% o% 7.0% B. INSURANCE G. TOTAL FED COST ($1000) 5% 7.0% 4, PRODUCTION GOSTS ($1000) ‘A. OPERATIONS AND MAINT. 1, TRANSMISSION LINE 2. HYDRO 3. ADMINISTRATIVE B. SELF GENERATION C. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000, 1993 607.0 2222.2 2222 24444 oo oo 12222 $3,586 $3,586 $300.6 $381.4 $300.6 $381.4 $04.5 $0.0 $56.0 244.4 $141.2 $908.2 1994 522.0 2287.7 228.8 2510.5 00 00 2516.5 $0 $o so $300.6 $381.4 $0.0 $300.6 $381.4 $64.5 $0.0 $65.0 $288.8 $408.3 POWER GOST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK - INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE 637.0 2363.2 236.3 2688.5 00 00 ees $300.6 $381.4 $0.0 ‘$300 6 $381.4 $645 $0.0 $66.0 $300.4 $410.0 1996 662.0 2418.7 2419 00 oo ees $300.6 $381.4 $0.0 $309.6 $381.4 $64.5 $0.0 $65.0 $3121 $431.6 (ALTERNATE 8:8) 1997 1998 607.0 682.0 24842 © 2640.7 248.4 265.0 27320 © 2804.6 ° ° oo 00 00 00 273268 2804.6 $0 $0 $0 $0 $0 $0 $3006 © $300.6 $3814 $381.4 $0.0 $0.0 $3006 $300.6 $381.4 $381.4 $04.5 $045 $0.0 $0.0 $55.0 $55.0 ° ° $3241 $3364 $4436 © $465.0 1999 697.0 2615.1 261.5 2876.7 00 0.0 2876.7 ese $300.6 $381.4 $300.6 $381.4 $64.5 $0.0 $96.0 $348.8 $468.3 6120 2080.6 268.1 2048.7 00 00 ees $300.6 $361.4 $0.0 $300.6 $3814 $64.5 $0.0 $55.0 $301.5 $481.0 2001 627.0 2746.1 274.6 3020.7 00 00 3020.7 ees $300.6 $381.4 $300.6 $381.4 $04.5 $0.0 $55.0 $374.5 $404.0 042.0 2811.0 261.2 3092.8 00 00 sss $309.6 $381.4 $0.0 $309.6 $381.4 $04.5 $0.0 $55.0 $387.6 $607.1 2003 657.0 2877.1 267.7 3164.8 00 00 3164.8 ees $309.6 $381.4 $0.0 $309.6 $381.4 $04.5 $0.0 $66.0 $401.1 $6206 073.1 2047.9 204.8 3242.0 oo oo 3242.6 ees $300.6 $361.4 $0.0 $300.6 $381.4 $04.5 $0.0 $56.0 $418.5 $636.0 680.2 3018.6 301.9 3320.5 0.0 oo 3320.5 ees $300.6 $381.4 $300.6 $381.4 $04.6 $0.0 $56.0 $4302 $540.7 706.3 3080.4 308.0 3308.3 0.0 00 ees $300.6 $381.4 $300.0 $381.4 $045 $0.0 $95.0 $446.2 $604.7 2007 721.4 3160.1 316.0 3476.2 00 oo 3476.2 ees $300.6 $381.4 $0.0 $300.6 $381.4 $04.5 $0.0 $65.0 $400.5 $680.0 737.5 3230.9 323.1 3654.0 00 0.0 3654.0 ese $300.6 $381.4 $0.0 $300.6 $381.4 $04.5 $0.0 $65.0 $476.1 $696.0 753.8 3301.7 330.2 3631.8 00 00 3631.8 ees $300.6 $381.4 $0.0 $300.6 $381.4 $04.5 $0.0 $66.0 $402.0 $611.5 2010 700.7 3372.4 337.2 3700.7 0.0 00 3700.7 ess $300.6 $381.4 $0.0 $300.6 $381.4 $04.5 $0.0 $55.0 $608.2 $027.7 2011 786.8 3443.2 344.3 3787.5 00 0.0 3787.5 ees $300.6 $381.4 $0.0 $300.6 $381.4 $04.5 $0.0 $96.0 $8246 $644.1 2012 801.0 3513.0 361.4 3805.3 oo oo 3805.3 ees $300.6 $381.4 $0.0 $300.6 $381.4 $04.5 $0.0 $95.0 $941.4 $060.0 Page 1 of 2 2013 818.0 3684.7 368.5 3043.2 00 0.0 3043.2 eee $00 $0.0 $0.0 $0.0 $0.0 $04.5 $0.0 $95.0 $558.6 $678.1 2014 est 3042.1 304.2 4006.3 0.0 oo Bes $0.0 $0.0 $00 $00 $0.0 $04.5 $00 $65.0 $673.0 $003.4 €£0 5. ANNUAL GOST ($1000) 6% 7.0% A. CREDIT FOR SALES: TO BETHEL UTILITIES B. TOTAL ANNUAL GOST ($1000) 8% 7.6% . PRESENT WORTH ($1000, TOTAL ANNUAL COST 5% 7.0% D. ACCUMULATED PRESENT ($1009) WORTH TOTAL ANNUAL GOST o% 7.0% 6. ENERGY GOST $/KWH A ENERGY SOLD MWH B. COST ENERGY $yKWH 6% 7.0% C. PRESENT WORTH ENERGY $/KWH o% 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 6% 7.6% 1993 $0148 $886.5 $0.0 $814.8 $886.5 $e148 $886.5 $14.8 $888.5 2044.4 $0300 $0.434 $0.309 $0.434 $0,300 $0434 1994 $717.9 $780.7 $0.0 $717.9 $789.7 $007.0 $760.7 $1,511. $1,063.2 2104.7 $0.341 $0.375 $0.331 $0,364 $0.730 $0.708 1995 $720.5 $8012 $0.0 $7206 $801.2 $087.6 $766.3 $2,100.4 $2,408.5 2164.9 $0.337 $0.370 sosie $0.349 $1.047 $1,147 1900 $741.3 $813.0 $0.0 $741.3 $813.0 $078.4 $744.0 $2,877.8 $3,152.5, 2208.2 $0.333 $0.305 $0.305 $0.334 $1,362 $1.48) (ALTERNATIVE 8:8) 1907 1998 $753.3 $706.5 $826.0 $8372 $0.0 $00 $7633 $705.5 $6250 © $837.2 $080.3 $660.3 $7330 © $722.2 $3.647.0 $4,207.3 $3,685.59 $4,607.7 2286.4 = 23457 $0330 $0.326 $o3er —-$0.357 $0.203 $0.282 $0321 $0,308 $1.045 $1,027 $1.802 $2.110 $777.9 $840.7 $00 $777.0 $840.7 $051.5 $711.6 $4,858.9 $6.310.3 2405.9 $0.323 $0.353 $0.271 $0.208 $2.197 $2.408 $700.6 $062.4 $0.0 $700.6 $862.4 $042.0 $701.2 $5.501.7 $0,020.5 2408.2 $0.321 $0.350 $0.261 $0.284 $2.458 $2.690 2001 $803.6 $876.3 $0.0 $803 6 $876.3 $634.4 $691.0 $0,136.1 $0,.711.5 2626.4 $0.318 $0.346 $0261 $0,274 $2.700 $2,963 $816.8 $e88.5 $0.0 $816.8 $980.5 $026.0 $081.0 $0,7621 $7,302.65 2686.7 $0.316 $0.343 $0.242 $0.263 $2.051 $3.227 2003 $630.2 $002.0 $0.0 $830.2 $002.0 $617.7 $6711 $7,370.8 $8,063.7 2646.9 $0314 $0.341 $0.233 $0.264 $3.164 $3.480 $944.6 $018.4 $0.0 $844.6 $016.4 $010.2 $062.0 $7,090.0 $8,726.7 2712.0 $0.311 $0.338 $0.225 $0.244 $3.400 $3.724 $850.4 $931.1 $0.0 $250.4 $931.1 $602.7 $053.1 $8,502.7 $0.378.7 2777.1 $0 300 $0.336 $0.217 $0.235 $3.620 $3,959 $874.3 $046.1 $00 $874.3 $046.1 $906.4 $644.3 $0,188.1 $10,023.0 2842.2 $0.308 $0.333 $0.209 $0.227 $3.636 $4.198 2007 $880.6 $061.4 $0.0 $889.6 $001.4 $588.2 $635.6 $9.776.3 $10,658.6 2907.3 $0.306 $0.331 $0.202 $o.210 $4.038 $4,405 $905.2 $077.0 $0.0 $006.2 $977.0 $681.0 $6271 $10,367.3 $11,285.7 2072.4 $0.305 $0.320 $0.195 $0.21 $4.234 94.016 $021.1 $002.8 $0.0 $021.1 $002.6 $574.0 $018.7 2010 $037.3 $1,009.0 $00 $037.3 $1,008.0 $967.1 $e105 $10,031. $11,408.3 $11,004.4 $12,5148 3037.5 $0,303 $0,327 $0.189 $0,204 $4423 $4.819 31026 $0.302 $0.3265 $0.183 $0.197 $4.60 $5.016 $053.8 $1,026.56 $0.0 $053.6 $1,026.5 $580.2 $002.4 $12,068.6 $13,117.2 3107.7 $0.301 $0.324 $0.177 $0.190 $4782 $6.206 2012 $070.6 $1,042.3 $00 $0706 $1,042.3 $653.5 $504.4 $12,.0121 $13,711.68 3232.8 $0.300 $0.322 $0.171 90.134 $4.054 $6.390 Page 2 of 2 2013 $678.1 $678.1 $0.0 $078.1 $078.1 $376.4 $376.4 $12,087.5 $14,087.1 3207.0 $0.208 $0.206 $0114 $0114 ‘$6.067 95.504 2014 $003.4 $003.4 $00 $003.4 $003.4 $3727 $3727 $13,300.2 $14,450.8 3360.7 $0.207 $0.207 $0.111 $0111 $6.170 96.015 TeV 1, LOAD DEMAND ‘A. DEMAND - KWH 1B. ENERGY - MWH G. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH E. MWH AVAILABLE FROM NYAG HYDRO. F. VILLAGE HYDRO USAGE - MWH_ @_ SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES. 2 INVESTMENT COSTS ($1000, A TRANSMISSION LINE B. NYAG HYDRO G. TOTAL INVEST. GOST ($1000, 3. FKED GOSTS ($1000, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 6% 7.0% B. INSURANCE G. TOTAL FIKED COST ($1000) 8% 7.0% 4, PRODUGTION COSTS ($1000, ‘A OPERATIONS AND MAINT 1, TRANSMISSION LINE: 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION C. PURCHASES FROM. BETHEL UTILITIES D. TOTAL PROD. GOSTS ($1000) 7300 20722 2072 3200.4 00 00 1034.7 $5,783 $6,783 $490.3 $016.0 $400.3 $015.0 $04.5 $0.0 $56.0 326.0 $191.3 $037.7 1904 760.9 3037.7 303.3 3341.5 00 00 3341.5 ees $400.3 $015.0 $0.0 $400.3 $615.0 $04.5 $0.0 $66.0 $386.9 $505.4 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC - INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE 1995 706.8 3103.2 310.3 3413.5, oo 00 3413.5 ees $400.3 $015.0 $00 $490.3 $015.0 $04.5 $0.0 $95.0 $308.4 $517.0 1900 780.7 3168.7 310.9 3486.6 00 3485.5 ees $400.3 $0150 $400.3 $015.0 $04.6 $0.0 $65.0 sate $620.7 (ALTERNATIVE 9-A) 1907 1998 706.6 810.5 3e342 © 32007 323.4 330.0 36676 3020.6 ° ° 00 00 00 00 36676 30206 $0 $0 $0 $0 $0 so $4003 $400.3 $6150 © $815.0 $0.0 $0.0 $4003 © $400.3 $0150 © $016.0 $046 $04.5 soo $0.0 $56.0 $65.0 ° 0 $424.2 $437.5 $643.7 $667.0 19090 825.4 3305.1 330.5 3701.7 00 00 3701.7 ees $490.3 $015.0 $0.0 $400.3 $016.0 $04.6 $0.0 $65.0 $451.0 $570.5 2000 840.3 3430.0 343.1 37737 00 00 3773.7 ees $400.3 $818.0 $0.0 $400.3 $615.0 $04.6 $0.0 $65.0 $404.8 $984.3 2001 266.2 3490.1 3406 3846.7 00 00 3848.7 ees $499.3 $615.0 $0.0 $409.3 $615.0 $04.5 $0.0 $55.0 $478.8 $508.3 2002 870.1 3601.6 386.2 3017.8 oo 00 3017.8 ess $400.3 $015.0 $00 $400.3 $015.0 $04.6 $0.0 $66.0 $403.1 $012.6 885.0 3627.1 362.7 3080.8 00 0.0 3080.8 ees $409.3 $015.0 $0.0 $400.3 $6150 $04.6 $00 $96.0 ‘$807.7 $027.2 901.2 3007.0 300.8 4067.6 0.0 00 4067.6 ese $400.3 $016.0 $0.0 $400.3 $615.0 $04.5 $0.0 $65.0 $6233 $os2.8 917.4 3768.6 370.9 4145.5 00 00 4145.5 ees $490.3 $016.0 $490.3 $015.0 $04.6 $0.0 $55.0 $630.1 $058.6 933.6 3830.4 383.9 4223.3 00 00 4223.3 ees $400.3 $616.0 $00 $400.3 $616.0 $04.5 $0.0 $96.0 $856.3 $074.8 oe 3010.1 301.0 4301.2 00 00 4301.2 eee $400.3 $016.0 $490.3 $015.0 $04.5 $0.0 $96.0 $671.8 $091.3 906.0 3080.9 308.1 43700 00 00 4370.0 ees $400.3 $016.0 $0.0 ‘$4003 $016.0 $04.6 $0.0 $65.0 $508.6 $708.1 oe22 4061.7 405.2 4460.8 00 00 4458.8 ees $400.3 $616.0 $0.0 $400.3 $615.0 $04.5 $0.0 $55.0 $608.7 $726.2 2010 908.4 41224 4122 4634.7 00 00 4634.7 ses $400.3 $015.0 $0.0 $400.3 $016.0 $04.5 $0.0 $95.0 $023.1 $742.6 2011 101406 4103.2 4103 46125 oo 00 4012.5 ees $400.3 $615.0 $0.0 $400.3 $015.0 $04.6 $0.0 $56.0 $e40.8 $760.3 2012 1030.8 4202.0 420.4 4690.3 00 00 4000.3 bes $400.3 $015.0 $00 $400.3 $015.0 $04.5 $0.0 $66.0 $058.0 $778.4 Paget of 2 1047.0 4334.7 433.6 4708.2 oo 00 4708.2 eee $0.0 $00 $00 $0.0 $0.0 $04.5 $0.0 $55.0 $677.3 $706.8 2014 1003.8 44041 4404 48445 00 00 4844.5 ees $0.0 $0.0 s00 $0.0 $0.0 $04.5 $0.0 $55.0 $005.9 $218.4 Stv 6, ANNUAL COST ($1000) 5% 7.0% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000, o* 7.0% G. PREGENT WORTH ($1000) TOTAL ANNUAL COST o* 7.0% D. ACCUMULATED PRESENT ($1000, WORTH TOTAL ANNUAL GOST o* 7.0% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY §KWH 6% 7.0% C. PRESENT WORTH ENERGY $/KWH ox 7.0% G. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 5% 7.0% 1903 $1.137.0 $1,262.7 $0.0 $1.137.0 $1,262.7 $1,137.0 $1,262.7 $1.137.0 $1,2627 27344 $0.416 $0.468 $0.416 $0.458 90.416 $0.458 1904 $1,004,7 $1,120.4 $00 $1,004.7 $1,1204 $075.4 $1,087.8 $2.1124 $2,340.5 2704.7 $0.360 $0.401 $0,349 $0389 $0.705 $0.847 1995 $1,017.2 $1,132 $00 $1,017.22 $1.132.0 $052.8 $1,067.0 $3,071.3 $3,408.4 $0,350 $0.307 $0.338 $0.374 $1,101 $1,221 1900 $1,030.00 $1,145.7 $0.0 $1,030.0 $1,146.7 $0426 $1,046.6 $4.013.0 $4,466.0 2015.2 $0.363 $0,303 $0.323 $0,300 $1424 $1,581 (ALTERNATIVE 0-4) 1997 1998 $1,043.1 $1,086.3 $1,198.8 — $1,172.0 $0.0 $0.0 $1,043.1 $1,066.3 $1,198.8 — $1,172.0 $020.7 © Sorte $1,020.6 — $1,011.0 $4,0406 $5,051.8 $5,.480.5 $6,407.5 2075.4 © 3036.7 $0361 $0.48 $0380 © $0.386 90.311 $0,300 $0346 © $0.333 $1736 © $2036 $1027 $2.260 1990 $1,060.8 $1,185.6 $0.0 $1,000.8 $1,186.68 $890.0 $002.0 $0,747.8 $7,400.4 3095.0 $0346 $0,383 $0,280 $0321 $2326 $2.581 $1,083.68 $1,100.3 $0.0 $1,083.6 $1,190.3, $es1.1 $076.2 $7,028.90 $3,406.6 3186.2 $0.343 $0.380 $0.270 $0 300 $2.604 $2,890 2001 $1.007.7 $1,213.4 $00 $1,007.7 $1,213.4 $200.5 $067.8 $9,406.4 $0.423.4 3216.4 $0.341 $0.377 $0.200 $0. 208 $2.874 $3,188 Hane $1,227.7 $0.0 $1,191.0 $1,2277 $e52.2 $040.0 $9,347.6 $10,304.3 3276.7 $0.330 $0.375 $0.260 $0.287 $3134 $3.475 $1,126.65 $2422 $0.0 $1.120.5 $1,242.2 $38.2 $024.3 $10,186.8 $11,288.6 3336.0 $0.338 $0.372 $0.261 $0.277 $3.385 $3,762 $1,142.1 $1,267.8 $0.0 $1,1421 $1.257.8 $826.1 $908.7 $11,010.80 $12,107.3 3402.0 $0.336 $0.370 $0.243 $0.267 $3,027 $4.010 $1,168.0 $1,273.7 $1,158.0 $1,273.7 se122 $803.3 $11.€23.0 $13,000.6 3407.1 $0.334 $0,367 $0.234 $0 268 $3.662 $4.277 $1,174.41 $1,260.8 $00 $1,1741 $1,2608 $700.5 $878.3 $12,022.06 $13,008.0 3632.2 $0.332 $0,305 $0.226 $0240 $4,088 $4,625 2007 $1,190.68 $1,306.3 $1,190.6 $1,306.3 $7871 $863.6 $13.400.7 $14,832.6 3607.3 $0.331 $0.363 $0.210 $0.240 $4,307 $4,705 $1,207.4 $1,323.1 $0.0 $1,207.4 $1,9231 $776.0 $840.2 $14,104.68 $15,081.68 3002.4 $0.330 $0.361 $o.212 so.2s2 $4518 ‘$4,097 $1,224.56 $1,340.2 $1,224.5 $1,340.2 $763.1 $836.2 $14,047.7 $16,617.0 3727.5 $0 328 $0,300 $0,205 $0224 $4723 $5.221 2010 $1,241.0 $1,367.68 $0.0 $1,247.0 $1,357.60 $751.4 $e214 $15,000.1 $17,338.3 3702.0 $0.327 $0.358 $0.198 $0217 $4.021 95.438 2011 $1,260.6 $1,764 $0.0 $1,260.68 $1,376.4 $730.9 $807.0 $10,430.0 $18,146.2 3887.7 $0.327 $0,357 $0.192 $0.200 $6.113 $8.047 $1,277 $1.303.4 $00 $1,277.7 $1,303.4 $726.7 $704.7 $17,107.60 $13,040.90 $0.326 $0.355 $0.19 $0.203 $5.200 $5 850 Page 2 of 2 2013 $700.8 $706.8 $700.6 $700.8 $4412 $aa.2 $17,008.8 $19,382.0 3087.0 $0,200 $0.200 90.111 $0111 $5 400 $5,000 2014 $e18.4 $e15.4 $0.0 $e18.4 $815.4 $438.3 $436.3 $19,047.1 $19,620.3 4051.7 $0.201 $0.201 $0.108 $0.108 $5.18 $6.000 geo 1. LOAD DEMAND A. DEMAND - KWH B. ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 4% D. TOTAL ENERGY REQUIREMENTS - MWH E. MWH AVAILABLE FROM NYAC HYDRO F. VILLAGE HYDRO USAGE - MWH @ SURPLUS MWH HYDRO ‘SALES TO BETHEL UTILITIES H.MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B. NYAC HYDRO. G. TOTAL INVEST. GOST ($1000) 3. FIKED COSTS ($1000) A DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 5% 7.0% B. INSURANCE C. TOTAL FIKED GOST ($1000, 5% 7.0% 4, PRODUGTION GOSTS ($1000) ‘A. OPERATIONS AND MAINT 1, TRANSMISSION LINE 2 HYDRO. 3. ADMINISTRATIVE. 8. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1993 736.0 2722 1180 3091.1 00 00 1945.5 $9,373 $0,373 $2093 $008.8 $809.3 $096.8 $04.5 $0.0 $55.0 3001 $181.3 $609.0 1904 760.9 3037.7 121.5 3150.2 00 00 3160.2 ees $800.3 $906.8 $200.3 $006.8 $04.5 $0.0 $55.0 $365.3 $484.8 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC - INTERTIED TO BETHEL WITH SINGLE POLE, 3 WIRE, 3-PHASE TRANSMISSION LINE 1995 705.8 3103.2 124.1 3227.3 00 oo 3227.3 ess $800.3 $996.8 $0.0 $800.3 $006.8 $04.5 $0.0 $65.0 $377.2 $406.7 1996 780.7 3168.7 126.7 3205.4 00 00 3205.4 eee $809.3 $906.8 $0.0 $800.3 $008.8 $04.5 $0.0 $65.0 $380.3 $508.8 (ALTERNATIVE 10-8) 1907 1998 706.6 810.5 3234.2 © 3200.7 120.4 132.0 33635 3431.6 ° ° 00 oo 00 00 3363.5 © 3431.6 $0 $0 $0 $0 $0 $0 $800.3 $809.3 $000.8 $096.8 $0.0 $0.0 $2093 $809.3 $oose $006.8 $04.5 $04.5 $0.0 $0.0 $56.0 $56.0 o ° $401.7 $4142 $621.2 $633.7 1990 826.4 3306.1 1346 3400.7 00 0.0 3490.7 eee $200.3 $068.6 $0.0 $200.3 $006.8 $04.6 $0.0 $55.0 $427.0 $540.5 840.3 3430.6 1372 3687.9 00 oo 3667.9 ees $800.3 $006.8 $00 $800.3 $006.8 $04.5 $00 $55.0 $440.1 $650.6 856.2 3490.1 1308 3636.0 00 0.0 3636.0 ees $800.3 $906.8 $0.0 $809.3 $006.8 $04.5 $0.0 $55.0 $453.3 $972.8 870.1 3661.6 1425 3704.1 00 00 37041 ess $800.3 $000.8 $0.0 ‘$808.3 $006.8 $04.5 $0.0 $65.0 $466.0 $986.4 885.0 3627.1 146.1 3772.2 oo 00 3772.2 ees $800.3 $906.8 $0.0 $208.3 $096.6 $04.5 $0.0 $65.0 $480.6 $600.1 01.2 3007.9 147.9 3845.8 00 00 3845.8 ses $800.3 $096.8 $0.0 $200.3 $996.8 $04.5 $0.0 $55.0 $405.4 $014.0 o17.4 3708.6 160.7 3019.4 0.0 0.0 3018.4 ees $200.3 $006.8 $0.0 $800.3 $006.8 $04.6 $0.0 $66.0 $610.4 $020.9 933.6 3830.4 1636 3993.0 00 00 3003.0 ses $809.3 $096.8 $0.0 $800.3 $006.8 $04.5 $0.0 $65.0 $626.7 $046.2 oo 3010.1 156.4 4086.5 00 0.0 ees $809.3 $900.8 $0.0 $800.3 $900.8 $64.5 $0.0 $55.0 $641.3 $660.8 966.0 3080.0 199.2 4140.1 00 0.0 4140.1 ese $809.3 $006.8 $0.0 ‘$800.3 $096.8 $04.5 $00 $65.0 $567.2 $676.7 92.2 4051.7 102.1 4213.7 00 0.0 4213.7 ees $809.3 $008.8 $0.0 $e00.3 $006.8 $04.5 $0.0 $55.0 $973.4 $002.0 2010 998.4 41224 164.9 4287.3 oo oo 4287.3 ees $800.3 $006.8 $0.0 $800.3 $006.8 $04.5 $0.0 $55.0 $580.8 $708.3, 2011 1014.6 4193.2 107.7 4360.9 00 0.0 4360.0 ees $800.3 $000.8 $0.0 $600.3 $000.8 $04.5 $0.0 $55.0 $606.6 $720.1 2012 1030.8 4203.0 1708 4434.5 00 00 4434.5 ese $800.3 $006.8 $0.0 $208.3 $006.8 $045 $0.0 $66.0 $023.7 $743.2 Page 1 of 2 2013 1047.0 4334.7 173.4 4508.1 00 00 4508.1 ess $0.0 $0.0 $0.0 $0.0 $0.0 $04.5 $0.0 $65.0 $641.2 $700.7 2014 1063.8 4404.1 176.2 4580.2 00 00 4580.2 ees $0.0 $0.0 $0.0 $0.0 $0.0 $04.5 $0.0 $65.0 $058.7 $778.2 Leo 6. ANNUAL GOST ($1000) 5% 7.6% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) 8% 7.0% G. PRESENT WORTH ($1000) TOTAL ANNUAL COST 8% 7.8% D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST 5% 7.0% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B, COST ENERGY $/KWH OK 7.0% G. PRESENT WORTH ENERGY $/KWH 6% 7.0% . ACCUMULATED PRESENT WORTH OF ENERGY $vKWH 8% 7.0% 1903 $1.4102 $1,606. $0.0 $1.4102 $1,600.8 $1.4102 $1,606.8 $1.410.2 $1,608.8 2734.4 $0.519 $0.568 $0510 $0.568 $0519 $0.5e8 1904 $1,204.1 $1,481.68 $0.0 $1,204.1 $1,481.6 $1,266.4 $1,436.5 $2,675.68 $3,046.3 2704.7 $0.463 $0.530 $0.460 $0.615 $0.069 $1.102 1995 $1,306.0 $1,403.5, $0.0 $1,308.0 $1,403.5 $1,231.0 $1,407.86 $3,008.6 $4,463.1 2854.9 $0.457 $0.623 $0.431 $0.493 $1.400 $1.695 1996 $1.3181 $1,506.6 $0.0 $1,318.17 $1,605.6 $1,206.2 $1,377.90 $5,112.90 $5,830.0 2016.2 $0.462 $0.516 $0.414 $0.473 $1814 $2,008 (ALTERNATIVE 10:4) 1997 $1.330.4 $1,518.00 $0.0 $1,3304 $1,518.0 $1,1821 $1.348.7 $0,204.9 $7,170.68 2076.4 $0.447 $0.510 $0.307 $0.463 $2211 $2,521 1998 $1,343.0 $1,630.59 $0.0 $1.343.0 $1,630.5 $1,198.5 $1,320.3 $7,463.4 $8,400.9 3036.7 $0.442 $0,504 $o.382 $0.435 $2.502 $2,056 1909 $1,365.8 $1,543.3 $0.0 $1,355.8 $1,543.3 $1,136.65 $1,202.56 $8,588.9 $0,702.4 $0.438 $0.400 $0.307 $0.417 $2,050 $3.374 $1,308.8 $1,056.4 $0.0 $1,308.8 $1,956.4 $1.113.0 $1,206.5 $9.701.8 $11,087.09 3166.2 $0.434 $0.493 $0.353 $0.401 $3312 $3.75 2001 $1,362.1 $1,509.7 $0.0 $1,382.1 $1.560.7 $1,001.0 $1,230.1 $10,702.9 912,207.0 3216.4 $0.430 $0.488 $0.330 $0.385 $3.0651 $4160 $1,305.06 $1,983.2 $0.0 $1,306.6 $1,683.2 $1,060.60 $1,.213.4 $11,802.5 $13.5104 3276.7 $0.426 $0.483 $0.326 $0.370 $3.07 $4530 2003 $1.400.4 $1,697.0 $0.0 $1,400.4 $1,697.0 $1,048.7 $1,188.35 si20112 $14,608.7 3336.9 $0.422 $0.470 $0.314 $0.366 $4.202 $4.886 2004 $1,424.22 $1,011.7 $0.0 $1.424.2 $1,011.7 $1,028.86 $1,164.3 $13,040.1 $15,863.0 3402.0 $0.419 0.474 $0.302 $0.342 $4,504 $5.20 $1,430.2 $1.626.7 $0.0 $1,430.2 $1,626.7 $1,000.4 $1,141.0 $14,040.5 $17,004.0 3407.1 90.415, $0.409 $0.26 $0.32 $4,885 $5.568 $1,464.5 $1,042.00 $0.0 $1,464.5 $1,642.00 $000.4 $1,118.14 $15,030.9 $18,122.1 3632.2 $0.412 $0.405 $0.280 $0.317 $5.186 $5.874 2007 $1,470.1 $1,067.6 $0.0 $1,470.1 $1,057.6 $071.0 $1,006.9 $10,011.8 $19,218.0 3697.3 $0.409 $0.401 $0.270 $0,306 $6.430 $6.179 $1,486.0 $1,073.65 $0.0 $1,486.0 $1.673.5 $053.8 $1,074. $17,806.6 $20,202.2 $0.4068 $0.457 ‘$0.260 $0.203 $5.690 $6.472 $1,502.1 $1,680.7 $0.0 $936.1 $1,063.0 $18,601.7 $21,346.1 3727.6 $0.403 $0.463 $0.251 $0.262 $6.047 $6.755 2010 $1,518.60 $1,706.2 $0.0 $1.518.6 $1,706.2 gorse $1,032.3 $19.720.5 $22,377.4 3702.68 $0.400 $0.450 $0242 $0.272 $6.190 $7,027 2011 $1,536.4 $1,723.0 $00 $1,535.4 $1,723.0 $001.0 $1,012 $20,622.3 $23,280.4 3857.7 $0.308 $0.447 $0.234 $0.202 96.423 $7200 2012 $1,652.5 $1,740.1 $0.0 $1,962.56 $1,740.1 $686.4 $002.3 $21,607.7 $24,381.8 $0.306 $0.444 $0.226 $0.253 $6.640 $7.542 Page 202 2013 $700.7 $760.7 $0.0 $760.7 $700.7 $421.2 $421.2 $21,928.90 $24,802 0 3087.0 $0.101 $0.101 $0.106 $0.106 $6.755 $7.048 2014 $778.2 $778.2 $00 $7782 $7782 $4183 $4183 $22,347.2 $25,221.3 4051.7 $0.192 $0.192 $0.103 $0.103 $0.658 $7.751 geo 1. LOAD DEMAND A. DEMAND - KWH 1B. ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 10% . TOTAL ENERGY REQUIREMENTS - MWH &. MWH AVAILABLE FROM NYAG HYDRO. F. VILLAGE HYDRO USAGE - MWH_ @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H.MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B. NYAC HYDRO. G. TOTAL INVEST. COST ($1000) 3. FXED COSTS ($1000) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 6% 7.0% B. INSURANCE G. TOTAL FED GOST ($1000, 8% 7.0% 4. PRODUCTION GOSTS ($1000, ‘A. OPERATIONS AND MAINT. 1, TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1903 1008.0 4146.9 4147 4501.6 0.0 00 2280.8 $6,045 $2,700 $9,645 $832.8 $1,026.8 $832.8 $1,026.8 $76.0 $0.0 $85.0 490.2 $208.1 $984.3 1994 10321 42545 425.4 4070.9 2500.0 0.0 2170.0 $2,700 $2,700 $1,005.0 $1,312.09 $43.2 $1,109.1 $1,360.1 $75.0 $40.0 $85.0 $260.9 $460.0 POWER GOST STUDY AKIACHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG, NAPASKIAK, OSCARVILLE & NAPAKIAK + NYAG HYDRO INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE 1006 1056.2 4302.0 436.2 4708.2 3178.0 16211 1619.3, eee $1,065.9 $1,312.09 $43.2 $1,109.1 $1,366.1 $75.0 $80.0 $86.0 $199.2 $430.2 1906 1080.3 4409.0 447.0 4016.0 3240.0 1760.1 1686.6 ees $1,086.0 $1,3120 $43.2 $1,100. $1,360.1 $76.0 $20.0 $85.0 $207.1 $447.1 (ALTERNATIVE 11-A) 1997 1104.4 4877.2 467.7 5034.9 3320.9 1070.1 1714.0 ess $1,065.0 91,3120 $43.2 $1,100.1 $1,356.1 $75.0 $80.0 $86.0 $215.1 $466.1 1998 1128.5 4084.7 408.5 5163.2 3301.0 1608.1 1701.3 ses $1,005.9 91,3129 $43.2 $1,100. $1,360.1 $75.0 $80.0 $85.0 $223.3 $463.3 1999 11826 4702.3 4702 6271.6 3402.9 1937.1 1808.6 bse $1,006.90 $1,312.90 $43.2 $75.0 $80.0 $86.0 $231.6 $471.6 1176.7 4890.9 490.0 5380.0 3633.0 1400.1 1856.0 ees $1,005.9 $1,129 $43.2 $1,100.1 $1,356.1 $75.0 $80.0 $85.0 $240.1 $480.1 2001 1200.8 007 6 500.7 6608.2 3604.0 1306.1 1903.3 eee $1,005.0 $1,312.90 $43.2 $1,100.14 $1,356.1 $76.0 $80.0 $86.0 $248.7 $488.7 1224.9 5116.0 511.6 5020.5 3675.9 1924.1 1060.6 ses $1,005.9 $1,129 $43.2 $1,100.14 $1,356.1 $75.0 $80.0 $85.0 $267.6 $407.5 2003 1249.0 52226 622.3 6744.9 3746.0 1283.1 1997.9 eee $1,005.9 $1.3120 $43.2 $1,100.1 $1,360.1 $75.0 $80.0 $85.0 $200.5 $506.5 12701 6364.3 535.4 3833.0 1106.1 2055.9 ees $1,005.9 $1.3129 $43.2 $1,100.14 $1,356.1 $76.0 $80.0 $85.0 $277.1 $917.1 1300.2 6480.1 648.0 6034.7 3020.8 1070.2 2113.9 eee $1,005.9 $1,312.90 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $85.0 $287.0 $527.0 1330.3, 5017.8 501.8 61706 4007.8 2171.8 ees $1,005.0 91.5120 $43.2 $1,100.1 $1,366.1 $75.0 $80.0 $25.0 $208.0 $638.9 1309.4 6740.6 676.0 6324.5 4094.7 905.3 2220.8 ees $1,065.0 $1.3129 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $85.0 $3100 $550.0 1308.5 5981.3 988.1 8469.4 4181.7 8183 2287.8 ees $1,065.06 $1,312.0 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $85.0 $321.4 $901.4 1420.6 6013.0 601.3 0014.3 4208.6 731.4 2345.7 ees $1,066.9 $1,3120 $43.2 $1,100.1 $1,350.1 $75.0 $80.0 $85.0 ° $333.1 $673.1 2010 1450.7 0144.8 614.6 6760.3 4365.6 044.4 2403.7 ese $1,006.9 $1.3129 $43.2 $1,100.1 $1,356.1 $75.0 $80.0 $85.0 $344.0 $984.0 2011 1480.8 0270.5 627.7 6904.2 4442.5 657.5 2401.7 ees $1,006.90 $1,3120 $43.2 $1,100.1 $1,360.1 $75.0 $20.0 $85.0 $366.9 $596.9 2012 15199 e408. 3 640.8 7049.1 46295 470.5 2510.6 ees $1,005.0 $1.3120 $43.2 $1,1001 $1,366.1 $75.0 $80.0 $85.0 $360.2 $000.2 Page 1 of 2 2013 1850.0 0540.0 054.0 7104.0 4016.4 383.6 2877.6 ees $233.1 $287.1 $43.2 $276.3 $330.3 $76.0 $80.0 $86.0 $381.7 $021.7 2014 19748 0044.6 064.5 7300.1 4085.5 314.5 2023.6 ees $00 $00 $43.2 $43.2 $43.2 $75.0 $80.0 $85.0 $302.7 $032.7 5. ANNUAL GOST ($1000) 8% 7.0% A GREDIT FOR SALES TO BETHEL UTILITIES 8. TOTAL ANNUAL COST ($1000) o% 7.0% C. PRESENT WORTH ($1000) TOTAL ANNUAL GOST o% 7.0% 1D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL GOST 6% 7.0% 6, ENERGY COST $7KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH 6% 7.0% PRESENT WORTH ENERGY $/KWH o% 7.0% ACGUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1993 $1.717.0 $1.9100 $0.0 $1,717.00 $1,010.0 $1.7170 $1,910.0 $1,717.0 $1,0100 3816.1 $0.450 $0.901 $0.450 $0.501 $0.450 $0.501 1904 $1,560.0 $1,8160 $00 $1,500.0 $1,816.0 $1.923.3 $1,703.22 $3,.240.4 $3,673.2 30141 $0.401 $0.404 $0.38 $0.460 $0.630 $0.061 1905 $1,548.2 $1,706. $1024 $1,365.68 $1,002.90 $1,278.00 $1,5108 $4,518.4 $5.184.0 4013.1 $0.338 $0 300 $0318 $0.376 $1,158 $1,328 1900 $1,990.1 $1,803.2 $197.4 $1,308.7 $1,015.7 $1,262.60 $1.4780 $5,770.09 $6,062.7 41120 $0 333 $0.33 $0.306 $0.360 $1402 $1087 (ALTERNATIVE 11°A) 1907 $1,5042 $1,811.2 gie22 $1,381.0 $1,620.0 $1.227.8 $1.447.3 $0,008.8 $8.110.0 4211.0 $0 326 $0387 $0202 $0344 $1,764 $2.031 1908 $1,9724 $1,8104 $176.9 $1,305.5 $1,042.5 $1,203.7 $1.4168 $8,202.56 $0,520.86 4310.0 $0.324 $0.381 $0270 $0.320 $2.033 $2.300 1990 $1,580.7 $1,827.7 $171.4 $1,400.3 $1,086.3 $1,1803 $1,387.2 $0,282.8 $10,014.0 4408.9 $0. 320 $0.376 $0.208 90.315 $2,301 $2074 $1,580.2 $1,836.2 $1057 $1.423.5 $1,670.5 $1.167.4 $1,358.3 $10,.6402 $12,2723 4807.0 $0.316 $0371 $0257 $0.301 $2.568 $2,976 2001 $1,507.8 $1,844.86 siso8 $1,438.1 $1,086.1 $1.136.2 $1,330.2 $11,075.4 $13,002.65 4008.0 $0312 $0.66 $0,246 $0.280 $2.904 $3264 $1,000.6 $1,853.6 $163.7 $1,462.90 $1,700.0 $1.113.6 $1,302.90 $12,789.0 $14,005 4 4705.8 $0.300 $0.361 90.237 $0.277 $3.041 $3541 $1.615.6 $1,802.86 $147.4 $1,468.2 $1,715.2 $1,002.56 $1.276.3 $13,861.5 $16,181.6 4804.8 $0.308 $0.367 $0.227 $0.206 $3.208 $3.607 $1,026.2 $1,873.22 $1300 $1,487.1 $1,734.2 $1.074.3 $1,2628 $14,065.86 $17,434.4 $0.302 $0362 so218 $0 254 $3,486 ‘$4,001 $1,636.60 $1,004.0 $1304 $1,508.6 $1,763.6 $1,056.7 $1,220.90 $10,0126 $16,004.4 6047.2 $0.208 $0.347 $0.200 0.244 $3,606, $4,305 $1,047.09 $1,805.0 $121.5 $1,620.4 $1,773.4 $1,030.4 $1,207.68 $17,051.90 $19,8720 $108.4 $0.205 $0.343 $0.201 $0.234 $3.807 4.538 2007 $1,050.1 $1,006.1 si24 $1,546.8 $1,703.86 $1,022.06 $1,185.0 $18,074.65 $21,067.0 $0.202 $0330 $0.193 $0224 $4,090 $4,763 $1.070.5 $1,017.55 $1020 $1,507.6 $1,814.60 $1,006.2 $1,104.7 $19,080.6 $22,222.06 54108 $0.200 $0335 90.180 $0215 $4270 $4.078 $1,082.11 $1.020.2 $03.2 $1,588.0 $1,835.0 $900.1 $i4at $20,070.86 $23,300.7 6532.0 $0.287 $0332 $0.170 $0.207 $4,465 $5.185 2010 $1,004.0 $1.041.0 $83.3 $1,6107 $1,857.7 $0745 $1.1240 $21,045.3 $24,490.6 5053.2 $0.285 $0.329 $0172 $0.100 $4.627 $5.384 2011 $1.708.0 $1,963.0 $73.0 $1,633.0 $1,880.0 sosa.2 $1,104.3 $22,004.56 $26,506.0 6774.4 $0.263 $0320 $0.106 $0.101 $4703 $5575 91.7183 $1,006.3 $026 $1,065.0 $1,002.09 $044.3 $1,085.2 $22,048.8 $20,080.2 $0.281 $0.323 $0.160 $0.184 $4.054 $5.750 Page 2 of 2 2013 $808.1 $0521 $51.6 $846.5 $900.5 $468.7 $408.68 $23.4175 $27,178.7 e168 $0.141 $0.160 $0.078 $0.083 $5.031 $8.842 2014 $0750 $0750 $420 $033.0 $033.0 $3403 $3403 $23,757.86 $27,5100 01131 $0.104 $0.104 $0.056 $0.050 $5.067 $5.807 O40 1, LOAD DEMAND A. DEMAND - KWH B ENERGY - MWH G. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH E. MWH AVAILABLE FROM NYAC HYDRO. F. VILLAGE HYDRO USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000, ‘A. TRANSMISSION LINE B. NYAC HYDRO G. TOTAL INVEST. GOST ($1000) 3. FKED COSTS ($1000, A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 5% 7.0% 8. INSURANCE G. TOTAL FKED GOST ($1000) 5% 7.0% 4, PRODUCTION COSTS ($1000) A OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE, B. SELF GENERATION G. PURCHASES FROM. BETHEL UTILITIES D. TOTAL PROD. COSTS ($1009, 1993 1008.0 4146.9 4147 4501.6 oo 00 $0,045 $2,700 $0,645 $832.8 $1,026. $932.8 $1,026.86 $76.0 $0.0 $85.0 4668.2 $208.1 $204.3 1904 1032.1 4264.5 425.4 4070.9 2600.0 00 2170.9 $2,700 $2,700 $1,065.0 $1,3120 $43.2 $1,109.1 $1.390.1 $75.0 $40.0 $85.0 $260.0 $450.0 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC, NAPASKIAK, OSGARVILLE & NAPAKIAK + NYAC HYDRO INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 11-8, 2% DISGOUNT RATE) 1905 1058.2 4302.0 436.2 4708.2 3178.9 19211 1619.3 ees $1,005. $1,3120 $43.2 $1,100. $1,366.1 $75.0 $80.0 $85.0 $992 $4302 1900 1080.3 4400.0 447.0 4910.6 3249.0 1760.1 1686.6 ees $1,005.9 $1,312.09 $43.2 $76.0 $80.0 $85.0 $207.1 $447.1 1997 1104.4 4877.2 487.7 6034.9 3320.9 1670.1 1714.0 ees $1,065.0 $1,312.90 $43.2 $1,100.1 $1,368.1 $75.0 $80.0 $85.0 $215.1 1908 1128.5 40847 408.5 5163.2 3301.9 1008.1 1761.3 ees $1,065.90 $1,312.90 $43.2 $1,109.1 $1,358.1 $75.0 $80.0 $86.0 $223.3 $463.3 1990 1182.6 4702.3 470.2 6271.6 3402.9 1637.1 1808.6 ees $1.086.9 $1,312.90 $43.2 $1,100.1 $1,386.1 $75.0 $80.0 $85.0 $231.6 $471.6 2000 1176.7 4800.9 490.0 6380.9 3633.9 1406.1 1856.0 ees $1,005.9 $1.3129 $43.2 $1,100.1 $1,366.1 $76.0 $80.0 $85.0 $240.1 $480.1 2001 1200.8 9007.5 600.7 3604.9 1306.1 1903.3 ees $1,006.09 $1,129 $43.2 $1,109 $1,366.1 $75.0 $80.0 $85.0 $248.7 $488.7 1224.9 5115.0 5115 5026.5 3076.9 13241 1950.6 ees $1,065.9 $1.3129 $43.2 $1,100.14 $1,396. $76.0 $80.0 $85.0 $267.5 $407.5 1249.0 52226 622.3 6744.0 3746.9 1263.1 1997.9 ees $1,005.90 $1,312.90 $43.2 $1,109.1 $1,366.1 $750 $80.0 $96.0 ° $200.5 $508.5 1270.1 5364.3 535.4 3833.9 1106.1 ses $1,066.9 $1,3120 $43.2 $1,100. $1,366.1 $756.0 $80.0 $85.0 $277.4 $617.1 1300.2 $486.1 548.6 0034.7 3920.8 1070.2 2113.0 ees $1,086.90 $1,312.90 $43.2 $1,109.17 $1,366.1 $76.0 $00.0 $85.0 $287.0 $627.0 1330.3 6017.8 561.8 01706 4007.8 21718 ees $1,066.9 $1,3120 $43.2 $1,100.1 $1,366.1 $76.0 $80.0 $85.0 $208.9 $638.9 2007 1300.4 5740.8 976.0 0324.5 4004.7 905.3 ees $1,005.9 $1,312.90 $43.2 $1,100.1 $1,366.1 $75.0 $80.0 $85.0 $310.0 $560.0 1300.5 5881.3 688.1 6400.4 4181.7 8183 2287.8 ees $1,005.09 $1,312.09 $43.2 $1,100.1 $1,366.1 $75.0 $80.0 $85.0 $321.4 $961.4 1420.8 0013.0 601.3 0614.3 4208.6 731.4 2346.7 ees $1,065.90 $1,3120 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $85.0 $333.1 $973.1 2010 1450.7 01448 0146 0760.3 4396.6 044.4 2403.7 eee $1,005.9 $1,312.09 $43.2 $1,100.1 $1,3606.1 $75.0 $80.0 $850 $344.0 $984.0 2011 1480.8 0276.5 027.7 6004.2 44425 997.5 2401.7 ees $1,005.0 91,3120 $43.2 $1,100.1 $1,3608.1 $75.0 $80.0 $85.0 $356.9 $596.9 1510.9 0408.3 640.8 7040.1 4520.5 4705 2610.68 ese $1,005.9 $1,3129 $43.2 $1,100.1 $1.366.1 $756.0 $80.0 $85.0 $300.2 $000.2 Page 1 of 2 2013 1550.0 0540.0 054.0 7104.0 4016.4 383.6 2677.6 ees $233.1 $267.1 $43.2 $276.3 $330.3 $76.0 $80.0 $85.0 $381.7 $621.7 2014 19748 00440 004.5 7300.1 4085.5 314.5 2023.6 ees $00 $0.0 $43.2 $43.2 $43.2 $75.0 $80.0 $85.0 $302.7 $632.7 Tho 5. ANNUAL COST ($1000) o% 7.8% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000, 8% 7.0% G. PRESENT WORTH ($1000) TOTAL ANNUAL GOST o% 7.0% D. ACCUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL COST 6% 7.6% 6. ENERGY COST $/KWH A ENERGY SOLD MWH. 8. COST ENERGY $/KWH 6% 7.0% C. PRESENT WORTH ENERGY $/KWH 8% 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY ®KWH 7.0% $1,717.00 $1,0100 $00 $1,717.0 $1,9100 $1,717.0 $1.910.0 $1.717.0 $1,9100 3815.1 $0.460 $0.501 $0.450 ‘$0.501 $0.450 $0.501 1904 $1,500.0 $1,816.0 $0.0 $1,509.0 $1,816.0 $1,538.35 $1,780.4 $3,265.3 $3,000.5, 30141 $0.401 90.464 $0.303 90.465 $0.843 $0.9658 1005 $1,548.2 $1,705.3 $1024 $1,366.68 $1,002 0 $1.303.2 $1,540.68 $4.658.5 $6,231.1 4013.1 $0.338 $0.300 $0.326 $0.384 $1.168 $1.330 1996 $1,556.1 $1,803.2 $187.4 $1,368.7 $1,015.7 $1,280.8 $1,522.60 $5,848.3 $0,763.6 41120 $0.333 $0,303 $0.314 $0.370 $1,481 $1.710 (ALTERNATIVE 11-8) 1007 $1,504.2 $1,811.2 sie22 $1,381.90 $1,020.0 $1,270.7 $1,604.90 $7,124.08 $8,268.5 4211.0 $0.328 $0.387 $0.303 $0.367 $1,786 $2,067 1998 $1,9724 $1,819.4 $176.9 $1,305.5 $1,642.56 $1,263.0 $1,487.68 $8,388.8 $9,746.2 43100 $0.324 $0.381 $0.203 $0.345 $2,078 $2412 $1,580.7 $1,827.7 $171.4 $1,400.3 $1,056.3 $1,251.4 $1,470.8 $0.640.3 $11,217.00 4408.0 $0.320 $0.376 $0.284 $0.334 $2.302 $2746 $1,980.2 $1,836.2 $105.7 $1.423.6 $1,670.5 $1,230. $1,454.3 $10,8705 $12,671.3 4507.0 $0.316 $0.371 $0.275 $0.323 $2,637 $3,068 $1,997.8 $1,844.8 $159.8 $1,438.1 $1,086.1 $1,227.4 $1,438.2 $12,106.9 $14,100. $0.312 $0.366 $0.266 $0.312 $2.903 $3381 $1,608.6 $1,853.6 $153.7 $1,462.09 $1,700.0 $1,215.86 $1,422.65 $13,322.7 $15,631.0 4705.8 $0.309 $0.361 90.268 $0.302 $3.161 $3.683 2003 $1,615.68 $1,802.68 $147.4 $1,408.2 $1,718.2 $1,204.4 $1,407.11 $14,927.1 $16,939.0 4804.8 $0.306 $0.367 $0.261 $0.203 $3.412 $3.976 $1.026.2 $1,873.2 $139.0 $1,487.1 $1,734.2 $1,196. $1,304.7 $15,723.1 $18,333.7 $0.302 $0.352 90.243 $0.263 $3,655 $4,250 $1,036.9 $1,884.0 $130.4 $1,506.68 $1,753.6 $1,187.0 $1,382.7 $10,911.0 $19,716.4 5047.2 $0.208 $0.347 $0.235 $0.274 $3.800 $4,533 $1,047.0 $1,895.0 $121.6 $1,926.4 $1,773.4 $1,180.0 $1.3700 $18,001.0 $21,087.3 5108.4 $0.205 90.343 $0.22 $0.265 $4110 $4,708 2007 $1,660.1 $1,006.1 $1124 $1,546.8 $1,703. $1,172.3 91,3605 $19,263.3 $22,446.8 $0.202 $0. 330 $o.222 $0,267 $4.340 $5.055 $1,070.5 $1,017.65 $102.0 $1,867.66 91,8146 $1,164.7 $1,348.35 $20,428.0 $23,706.1 54108 $0.200 $0.335 $0.215 $0240 $4655 $5,304 $1,920.2 $03.2 $1,988.9 $1,836.90 $1,197.4 $1,337.44 $21,585.4 $26,132.55 5632.0 $0.267 $0.332 ‘$0.209 $o.242 $4,765 $5.546 2010 $1,604.0 $1,041.0 $83.3 $1.610.7 $1,867.7 $1,150.3 $1,326.7 $22,736.7 $26,450.2 6053.2 $0.285 $0.320 $0.203 $0.235 $4.968 $5.781 2011 ‘$1,706.0 $1,063.0 $73.0 $1,633.0 $1,880.0 $1,143.4 $1,.3163 $23,870.1 $27,776.6 6774.4 $0.283 $0.326 $0.198 $0.228 $6.166 $6.00 2012 $1,7183 $1,905.3 $02.5 $1,055.0 $1,002.0 $1,136.6 $1,300.2 $25,015.7 $20,081.7 $0,281 $0.323 $0.103 90.222 $5.360 $6.230 Page 2 of 2 2013 $8081 $0521 $51.6 $940.5 $900.5 $509.6 $606.0 $26,586.4 $20,087.7 e018. sora $0.160 $0.095 $0.101 95.454 $0.331 2014 $075.0 $075.9 $20 $633.0 $033.0 $417.7 $4177 $20,003.0 $30,105.4 6113.1 90.104 $0.104 $0.068 $0.068 $6.522 $6.300 eno 1. LOAD DEMAND A DEMAND - KWH B ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH E MWHAVALABLE FROM NYAG HYDRO F. VILLAGE HYDRO USAGE - MwH SURPLUS MWH HYDRO SALES TO BETHEL UTLITIES H.MWH PURCHASES FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B_NYAC HYDRO. G. TOTAL INVEST. COST ($1000, 3. FED COSTS ($1009, A DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% ox 7.0% G. TOTAL FIKED GOST ($1000) o% 7.0% 4. PRODUCTION COSTS ($1009, A. OPERATIONS AND MAINT. 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION C. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1903 1008.0 4148.9 4147 4961.6 oo oo $8,045 $2,700 $9.045 $8328 $1,026.8 $es28 $1,026.8 $75.0 $0.0 $85.0 456.2 $208.1 $3043 1994 10321 4264.5 425.4 4070.9 2600.0 oo 21700 $2,700 $2,700 $1,005.6 $1.3120 $43.2 $1.100.1 $1.350.1 $76.0 $40.0 $85.0 $280.9 $450.9 POWER COST STUDY AKIACHAK, AKIAK, KWETHLUK, TULUKSAK, NYAG, NAPASKIAK, OSCARVILLE & NAPAKIAK + NYAC HYDRO INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 11-C, 4% DISCOUNT RATE) 1995 1056.2 43620 430.2 4708.2 3178.9 1821.1 19193 ess $1,005.9 $1.3120 $43.2 $1,100 $1,356.1 $75.0 $20.0 $85.0 sie92 1996 1080.3 4400.6 447.0 4010.6 3249.0 1780.1 1000.6 ese $1,085.9 1.3120 $43.2 $1,100.41 $1,380.1 $75.0 $80.0 $35.0 $207.1 $4471 1907 1104.4 4877.2 457.7 5034.9 1070.1 1714.0 ees $1,005.0 1.3129 $43.2 $1,100.1 $1.366.1 $75.0 $80.0 $85.0 ‘$215.1 1998 1128.5 4084.7 408.5 5163.2 3301.9 1608.1 1701.3 ees $1,065.9 H.29 $43.2 $1,1001 $1,350.1 $760 $30.0 $05.0 $223.3 $463.3 1999 11826 4702.3 4702 6271.68 3402.9 1937.1 1808.0 ese $1,065.9 $3120 $43.2 $1,100.1 $1,360.1 $75.0 $80.0 $85.0 $231.6 $471.6 11707 4800.9 490.0 5389.9 3633.9 1406.1 1856.0 eee $1,005.90 $3120 $432 $1,1001 $1,386.1 $75.0 $80.0 $85.0 $240.1 $480.1 1200.8 5007.5 500.7 9508.2 3004.9 1396.1 1903.3, ese $1,005.9 $1.3120 $43.2 $1,100.1 $1,366.1 $75.0 $80.0 $86.0 $248.7 1224.9 6115.0 5115 3078.9 19241 1950.6 ees $1.065.9 H28 $43.2 $1,101 $1,366.1 $75.0 $80.0 $85.0 $267.5 $497.5 1240.0 62226 8223 5744.9 3746.9 12531 1997.0 ees $1,006.9 1.20 $43.2 $1.100.1 $1.366.1 $75.0 $20.0 $85.0 $200.5 12701 5364.3 538.4 3833.9 1106.1 ess $1,065.9 $1.3129 $43.2 $1,100. $1,386.1 $75.0 $80.0 $85.0 $277.1 $617.1 1300.2 6486.1 S486 0034.7 1070.2 2113.9 ees $1,085.9 1.3129 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $26.0 $287.0 $927.0 1330.3 5017.8 501.8 01798 4007.8 902.2 2171.8 ees $1,005.9 $1.3120 $43.2 $1,100. $1,366.1 $75.0 $80.0 $35.0 $208.0 $638.9 2007 1300.4 5740.6 876.0 0324.5 4004.7 905.3 ees $1,005.9 28 $43.2 $1,100.1 $1,380.1 $75.0 $80.0 $25.0 $s10.0 1900.5 9681.3 688.1 e400. 41817 e183 2287.8 ees $1,065.90 $1.3129 $43.2 $1,100.1 $1,360.1 $75.0 $80.0 $85.0 $321.4 $5014 1420.6 6013.0 601.3 0614.3 731.4 2345.7 ese $1,005.9 #3120 $43.2 $1,1001 $1.396.1 $75.0 $80.0 $85.0 $333.1 $973.1 2010 1450.7 e144 0145 07503 0444 ees $1,065.90 $1.3120 $43.2 $1,100.1 $1.386.1 $75.0 $80.0 $850 $344.0 $584.0 2011 1480.8 0270.6 027.7 4442.5 557.5 2401.7 ees $1,006.9 $1,3120 $43.2 $1,100.1 $1,360.1 $75.0 $80.0 $85.0 $386.0 2012 1819.9 6408.3 040.8 7040.1 4705 25196 ees $1,005.9 1.20 $432 $1,100 $1,396.1 $750 $80.0 $85.0 $300.2 $000.2 Page 1 ot2 2013 1850.0 0540.0 054.0 7194.0 ac1e4 383.0 26776 ees $233.1 $267.1 432 $276.3 $330.3 $75.0 $80.0 $85.0 $381.7 $0217 2014 19748 004468 0045 7300.1 4085.5 3145 ees $00 $o0 $43.2 $43.2 $43.2 $76.0 $20.0 $860 $3027 $6327 eho 5. ANNUAL GOST ($1000) 5% 7.0% A CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) o* 7.0% C. PRESENT WORTH ($1000) TOTAL ANNUAL GOST % 7.0% D. ACCUMULATED PRESENT ($1000, WORTH TOTAL ANNUAL COST o* 7.0% 6. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH 6% 7.0% C. PRESENT WORTH ENERGY $/KWH * 7.0% . ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1993 $1.717.0 $1.9100 $1.717.0 $1,010.0 $1.7170 $1.9100 $1,717.0 $1,9100 3816.1 $0.460 $0.501 $0.460 $0.501 $0.450 $0.01 1904 $1,500.0 $1.8160 $00 $1,569.0 $1,816.0 $1,608.7 $1,740.2 $3.225.7 $3,060.2 30141 $0.401 $0.404 $0.386 90.446 90.836 $0.047 1906 $1,5482 $1,705.3 sio24 $1,365.68 $1,002. $1,203.5 $1,481.90 $4.470.3 $6.138.2 4013.1 $0.338 $0,300 $0.312 $0.00 $1148 1.316 1096 $7.956.1 $1.803.2 $187.4 $1,308.7 $1,015.7 $1.2108 $1.430.4 $5,696.0 $6.574.6 41120 $0.333 $0.303 $0.200 $0 340 $1444 $1,005 (ALTERNATIVE 11-G) 1907 1908 $1,5042 $1,972.4 $1.811.2 $1,6104 $is22 $1700 $1,381.90 $1,306.56 $1,0200 $1,042.65 $1.181.3 | $1,1470 $1,3024 — $1,360.0 $0.877.3 $8,024.3 $7,067.0 $0,317.0 4211.0 43100 $0326 © $0.24 $0387 $0361 $0281 $0.200 $0.331 $0.313 $1,724 $1,900 $1,006 $2,300 1990 $1,680.7 $1,827.7 714 $1,409.35 $1,068.3 $1,113.86 $1,308.0 $0,1381 $10,026.0 4408.9 $0.320 $0.376 $0,263 $0,207 $2.243 $2,600 $1,580.2 $1,838.2 $105.7 $1,423.5 $1,670.85 $1,081.8 $1,200.65 so.2108 $11,896.5 4607.9 $0.316 $0.371 $0.240 $0.282 $2,483 $2.88 $1,597.86 $1,8448 siso8 $1,438.1 $1,086.1 $1,050.8 $1,231.3 $11,2706 $13,1268 $0312 $0306 $0.228 $0.207 $2711 $3.155 $1,608.6 $1,863.6 $1937 $1,462.90 $1,700.0 $1,020.8 $1,104.4 $12,201.46 $14,321.1 4705.8 $0,309 $0.361 $0.217 90.264 $2028 $3.409 2003 $1.015.6 $1,802.6 $474 $1,408.2 $1.716.2 $001.0 $1,168.7 $13,2683.3 $15.470.0 $0.308 $0.367 $0,200 $0241 $3134 $3.060 $1,020.2 $1,873.22 $130.0 $1,487.1 $1,734.2 $068.0 $1,120.5 $14,2403 $10,006.4 4926.0 $0.302 $0.352 $0.100 $0.220 $3.331 $3.870 $1,030.0 $1,084.0 $130.4 $1,806.68 $1,763.68 $0410 $1,006.3 $15,100.3 $17,701.6 6047.2 $0.208 $0.347 $0.180 $0217 $3.517 $4,006 $1,047.0 $1,8965.0 $121.5 $1,620.4 $1,773.46 $0167 $1,005.1 $10,107.0 $18,706.7 6108.4 $0.206 $0.343 $0.177 $0.206 $3.004 $4302 2007 $1,050.1 $1,000.1 si24 $1,546.8 $1.703.8 $903.2 $1,036.90 $17,000.2 $19,802.6 $0.202 $0.330 $0.100 $0.196 $3.863 $4408 $1,070.58 $1.017.5 $1020 $1,607.6 $1,814.60 $8704 $1,007.68 $17.870.7 $20,8102 s410.8 $0 200 $0 335, $0.101 $0,186 $4,024 $4,084 $1,0821 $1,020.2 $03.2 $1,588.9 $1,636.0 $48.3 $080.2 $18,7100 $21,700.4 $0.267 $0.332 $0.153 $0.177 $4177 $4,801 2010 $1,004.0 $1,041.0 $833 $1.010.7 $1,867.7 ‘$820.0 $063.7 $19,545.9 $22,744.1 $0.285 $0.320 $0140 $0.160 $4.324 $5.030 $1,700.0 $1,063.0 $73.0 $1,633.0 $1,880.0 $800.1 $928.0 $20,352.0 $23,072.1 8774.4 $0.283 $0 326 $0.140 $0.167 $4.403 $5.100 2012 1.7183 $1,005.3 $1,065.90 $1,002.90 $765.0 $003 2 $21,.1370 $24,575.3 $0.281 $0323 $0.133 $0.153 $4,507 $5.344 Page 2 of 2 2013 $008.1 $0621 $516 $840.5 $000.5 $380.3 $411.0 $21.624.2 $24,086.3 oo16.8 $0141 $0.150 $0.004 $0.008 $4.001 95.412 2014 $075.9 $0750 $420 $633.0 $033.0 $277.8 $2778 $21,6020 $25,2041 0113.1 $0.104 $0.104 $0046 $0045 $4,706 $6.467 fh 1. LOAD DEMAND A DEMAND - KWH B ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH MWHAVAILABLE FROM NYAC HYDRO F. VILLAGE HYDRO USAGE - MwH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H.MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1009, A. TRANSMISSION LINE B.NYAG HYDRO. G. TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1000) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% 6% 7.0% B. INSURANCE G. TOTAL FIKED COST ($1000) 8% 70% 4, PRODUCTION COSTS ($1000) ‘A. OPERATIONS AND MAINT. 1, TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE: 8. SELF GENERATION C. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1008.0 4140.9 4147 4501.6 0.0 oo $0,045 $2,700 $0645, $932.8 $1,026.8 $932.8 $1,026.8 $76.0 $00 $86.0 4562 $208.1 $004.3 1904 1045.3 42614 4261 4709.8 2600.0 00 $2,700 $2,700 $1,006.0 $1,3120 $432 $1,100.1 $1,360.1 $76.0 $40.0 $86.0 $203.5 $403.5 POWER GOST STUDY AKIAGHAK, AKIAK. KWETHLUK, TULUKSAK, NYAC, NAPASKIAK, OSGARVILLE & NAPAKIAK + NYAC HYDRO INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 11:0, LOAD GROWTH +20%) 1905 1082.6 44150 4416 48875 32146 1785.5 1643.0 ees $1,065.9 $1.3120 $43.2 $1,108.1 $1,3561 $75.0 $80.0 $85.0 $2023 $4423 1096 11100 4950.4 455.0 5005.5 3303.3 1896.7 1702.2 ees $1,005.0 $1,3129 $43.2 $1.100.1 $1,360.1 $75.0 $80.0 $35.0 $211.0 $451.9 1907 1167.2 4084.0 408.5 5153.4 3302.1 1007.0 1761.4 ees $1,005.0 $1.3120 432 $1,100.14 $1,396.1 $76.0 $80.0 $85.0 $221.5 $401.5 1908 11046 481905 481.9 5301.4 3480.8 19192 1820.6 ees $1,005.90 $1.3120 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $85.0 $231.4 $471.4 1999 1231.8 4954.0 496.4 54404 1430.4 18707 ees $1,005.9 $1,312.09 $43.2 $1,1001 $1,396.1 $75.0 $80.0 $85.0 $241.5 $481.5 ‘2000 1200.1 5088.5 508.8 9507.3 3058.4 1341.6 1938.9 ese $1,005.0 $1,3120 432 $1,100.17 $1,366.1 $750 $80.0 $850 $251.7 $4017 2001 1306.4 6223.0 6223 67453 3747.2 12828 1908.1 ees $1,005.0 $1,312.90 $432 $1.100.1 $1,366.1 $75.0 $80.0 $85.0 $202.1 $9021 2002 1343.7 5367.5 535.7 5803.2 3635.9 11641 2067.3 ses $1,065.9 $1.3129 $432 $1,100.1 $1,366.1 $750 $80.0 $85.0 se728 $128 1381.0 $4920 549.2 e041.2 30247 1076.3 21165 eee $1,006.9 $1,3120 $43.2 $1,100.14 $1,360 $76.0 $80.0 $85.0 $2836 $523.6 14138 9003.8 508.4 0230.2 4038.1 oo19 21021 ees $1,005.0 $3120 432 $1,100.1 $1,360.1 $750 $20.0 $85.0 $200.6 $930.6 1448.6 $835.6 583.6 o419.2 4151.5 948.5 2207.7 ese $1,085.9 $1.3120 $43.2 $1,100.1 $1,356.1 $76.0 $80.0 $85.0 $300.0 $540.0 14704 6007.4 000.7 6008.1 4204.0 735.1 2343.3 eee $1,005.9 $1.3120 $432 $1,100.1 $1,360.1 $760 $80.0 $85.0 $3234 $963.4 2007 1122 o1702 01790 0707.1 ese $1,006.0 $1.3120 $43.2 $75.0 $80.0 $85.0 $337.1 $977.1 1845.0 6351.0 635.1 0980.1 44017 508.3 24044 ess $1,005.9 1.3129 $43.2 $1,100.1 $1,360.1 $76.0 $80.0 $850 $361.2 $601.2 1977.8 ose28 052.3 7176.1 4005.0 308.0 2570.0 eee $1,006.0 s1.s120 $43.2 $1,100.1 $1,396.1 $76.0 $800 $85.0 $308.5 $005.5 2010 1010.6 0004.6 060.5 7304.1 4784 261.6 20450 see $1,065.09 $1,3120 $432 $1,100.1 $1,360.1 $76.0 $20.0 $85.0 $380.1 2011 1043.4 0868.4 686.6 7553.0 4831.8 198.2 2721.2 ese $1,006.0 $1.3120 $43.2 $1,100.1 $1,390.1 $76.0 $80.0 $85.0 $304.9 $034.9 1076.2 7038.2 7038 7742.0 4045.2 s48 2700.8 ess $1,006.9 $1,312 32 $1.100.1 $1.366.1 $75.0 $80.0 $25.0 $4101 $050.1 Paget oat? 2013 1706.0 7210.0 721.0 7931.0 26724 ees $233.1 $207.1 $43.2 $2703 $330.3 $76.0 $80.0 $86.0 $426.6 $005.6 2014 1730.3 7325.4 732.5 8057.9 6134.7 1347 2923.2 ees $0.0 $00 $43.2 $43.2 $43.2 $75.0 $80.0 $85.0 $437.7 $077.7 Sto 5. ANNUAL GOST ($1000) o* 70% A. CREDIT FOR SALES: TO BETHEL UTLITES B. TOTAL ANNUAL GOST ($1000) * 70% C. PRESENT WORTH ($1000) TOTAL ANNUAL GOST 5% 7.0% D. AGGUMULATED PRESENT ($1000) WORTH TOTAL ANNUAL COST 5% 7.0% 6. ENERGY GOST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH o% 7.0% G. PRESENT WORTH ENERGY $/KWH * 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1903 $1.717.0 $1.0100 $0.0 $1.717.0 $1,010.0 $1.717.0 $1,010.0 91,7170 $1,910.0 3816.1 $0.460 $0,501 $0.450 $0.501 $0.450 $0,501 1904 $1,572.68 $1,819.6 $0.0 $1.5726 $1,810.68 $1,826.8 $1,706.60 $3.243.8 $3,070.7 3038.9 $0.300 $0.402 $0.368 $0440 $0.83 $0.040 1006 $1,961.4 $1,708.4 $188.7 $1,362.8 $1,000.68 $1,284.5 $1,5174 $4,528.4 $5,104.0 4062.6 $0.336 $0.306 $0310 $0.373 $1154 $1,323 1996 $1,600.0 $1,808.0 $1817 $1,370.2 $1,020.3, $1,202.2 $1,488.3 $5,700.68 $0,082.3 4180.4 $0.320 $0388 $0301 $0.366 $1.466 1.078 (ALTERNATIVE 11-0) 1907 $1,570.60 $1.817.7 $1745 $1,300.1 $1,043.1 $1,240.4 $1,460. $7.031.0 $8,1422 4310.1 $0.324 $0.361 $0288 $0.330 $1,743 $2017 1998 $1,980.5 $1,827.55 $167.1 $1.4134 $1.000.4 $1.2102 91.4323 $2.250.2 90.5745 4433.9 $0.310 $0.374 $0.275 $0323 $2.018 $2.340 1990 $1,500.6 $1,837.6 $1505 $1,431.1 $1,078.1 $9.448.7 $10,970.0 4967.6 $0314 $0.308 $0 203 $0.308 $2281 $2048 $1,600.8 $1,0478 $181.6 $1.4492 $1,000.2 $1,1783 $1,3702 $10,627.0 $12,36500 $0.310 $0,362 $0.252 $0 206 $2533 $2043 2001 $1,611.2 $1,958.2 $1435 $1,407.7 $1,.7148 $11,786.7 913.7127 4805.1 $0.305 $0.357 0.241 0.262 $2.74 $3.226 $1,021.68 $1,808.90 $136.1 $1,486.7 $1,733.8 $1,130.65 $1,328.68 $12,025.1 $19,041.5 4928.0 $0,302 $0,352 $0231 $0.270 $3,005 $3404 $1,032.7 $1,8707 $120.5 $1,606.2 $1,793.2 $1,120.7 $1,304.6 $14,046.0 $16,346.0 6062.6 $0.208 $0.347 $0222 $0258 $3.227 $3.762 $1,645.7 $1.6027 $1147 $1,531.0 $1.778.0 $1.108.0 $1,264.5 $15,151.90 $17.630.5 $210.7 $0.204 $0.341 sozi2 0.247 $3.430 $3900 $1,068.0 $1,006.0 $1025 $1,956.4 $1,803.4 $1,001.86 $1,204.90 $16,243.65 $18,806.4 $0.200 $0.336 $0.203 $0.230 $3,643 $4234 $1,0724 $1,0105 $00.0 $1,562.4 $1,820.4 $1,077.6 $1,246.68 $17,321.41 $20,141.2 $0,286 $0.331 90.105 s0.225 $3.637 $4,400 2007 $1,086.2 $1,033.2 $72 $1,600.1 $1,860.1 $1.003.8 $1,227.14 $18.3e48 $21,308.3 $0.263 $0,326 $0187 s0.216 $4,025 $4.076 $1,700.3 $1,047.3 $03.0 $1,036.3 $1,883.3 $1,050.3 $1,208.86 $10,436.1 $22,677.11 $0.280 $0 322 90.180 $0.207 $4,204 $4,883 $1,714.06 $1,001.6 $50.4 $1,004.2 $1.911.2 $1,037.1 $1,101.0 $20,4722 $23,708.1 6001.0 $0.277 $0.318 $0173 $0.108 $4.37 $6.081 $1,720.2 $1,978.2 $30.4 $1,002 $1.030.8 $1,024.2 $1.173.6 $21.400.4 $24,041.7 6150.0 $0.276 $0.315 90.108 $0.101 $4.543 $6.272 2011 $1,744.0 $1,901.0 $1,7220 $1,060.0 $1,011.5 $1,196.6 $22,507.9 $20,098.3 0317.1 $0.273 $0312 $0.100 $0.183 $4.704 95.455 2012 $1,750.2 $2,000.2 $73 $1,761.09 $1,008.09 $000.1 $1,140.0 $23,607.0 $27,2383 0475.1 $0.271 $0.300 $0.154 $0.178 $4 868 $6.631 Page 202 2013 $041.0 $006.0 g7.9 $040.7 $1,003.8 $626.0 $955.6 $24,032.86 $27.704.1 $0.143 $0.151 $0.070 $0 084 $4037 $6715 2014 $7200 $720.9 $730.3 $730.3 $307.4 $3074 $24.4302 $28,101.5 67303 $0.110 $0.110 $0 059 $0,050 $4.006 $8.74 9t0 1. LOAD DEMAND A DEMAND - KWH 1B ENERGY - MWH C. TRANSMISSION LINE LOSSES @ 10% D. TOTAL ENERGY REQUIREMENTS - MWH E MWH AVAILABLE FROM NYAC HYDRO F. VILLAGE HYDRO USAGE - MWH @. SURPLUS MWH HYDRO SALES TO BETHEL UTILITIES H. MWH PURCHASES: FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000) A. TRANSMISSION LINE B_NYAGHYDRO G. TOTAL INVEST. COST ($1000) 3. FKED COSTS ($1000) A. DEBT SERVICE INCLUDING CONSTRUCTION INTEREST @ 7.6% o% 70% B. INSURANCE G. TOTAL FKED COST ($1000, 6% 7.0% 4, PRODUGTION COSTS ($1000) A. OPERATIONS AND MAINT 1. TRANSMISSION LINE 2 HYDRO 3. ADMINISTRATIVE B. SELF GENERATION G. PURCHASES FROM BETHEL UTILITIES D. TOTAL PROD. COSTS ($1000) 1993 1008.0 4146.0 4147 4561.6 00 00 $6,045 $2,700 $9,045 $e22.8 $1,026.68 $es28 $1,026.86 $76.0 $0.0 $85.0 456.2 $208.1 $884.3 1904 1008.0 41400 4147 4501.6 2600.0 00 2081.6 $2,700 $2,700 $1,005.9 $3120 $43.2 $1,100. $1,368.1 $75.0 $40.0 $85.0 $246.2 $446.2 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC, NAPASKIAK, OSCARVILLE & NAPAKIAK + NYAC HYDRO INTERTIED TO BETHEL WITH SINGLE POLE, SWGR TRANSMISSION LINE (ALTERNATIVE 11-E, NO LOAD GROWTH 1995 1008.0 4146.0 4147 4601.6 3037.0 1963.0 1924.6 ees $1,006.9 $1,312.90 $43.2 $1,100.1 $1,366.1 $75.0 $80.0 $85.0 $187.5 $427.5 1906 1008.0 4140.9 447 4561.6 3037.0 1963.0 1524.6 ees $1,005.0 1.3120 $43.2 $1,100 $1,360.1 $75.0 $80.0 $85.0 $180.4 $420.4 1997 1008.0 4146.0 447 4561.6 3037.0 1903.0 1624.6 ese $1,005.0 $1,312.90 $43.2 $1,100.14 $1,366.1 $75.0 $80.0 $95.0 $1013 $431.3 1998 1008.0 4146.9 4147 4661.6 3037.0 1903.0 1824.6 ess $1,006.9 $1,312.09 $43.2 $1,100.14 $1,366.1 $76.0 $80.0 $85.0 $103.3 $433.3 1909 1008.0 4146.9 4147 4561.6 30370 1963.0 1624.6 ess $1,005.90 $1,312.90 $43.2 $1,100.1 $1,356.1 $75.0 $200 $85.0 $105.2 $436.2 2000 1008.0 4146.9 4147 4501.6 30370 1963.0 1924.6 ees $1,006.9 $1,.3120 $43.2 $1,100 $1,3561 $75.0 $200 $05.0 $07.2 $437.2 2001 1008.0 41400 4147 4601.6 3037.0 1983.0 16246 ees $1,085.0 $1.3120 $43.2 $1,1001 $1,2661 $75.0 $90.0 $06.0 $1003 $4303 1008.0 4146.9 4147 4501.8 3037.0 1063.0 1624.6 eee $1,005.0 $1,312.09 $43.2 $1,.1001 $1,356.41 $75.0 $80.0 $85.0 $201.3 $441.3 1008.0 4146.9 4147 4661.6 3037.0 1963.0 1924.6 ees $1,005.9 $1.3120 $43.2 $1,100.1 $1,366.1 $75.0 $20.0 $86.0 $203.4 $443.4 1008.0 41469 4147 4901.6 3037.0 1903.0 1824.6 es $1,005.9 $1,312.90 $43.2 $1.100.1 $1,386.1 $76.0 $80.0 $85.0 $205.5 $445.5 1008.0 4146.9 4147 4501.6 3037.0 1963.0 1524.6 ees $1,005.0 $1.3120 $43.2 $1,100 $1,360.1 $75.0 $20.0 $85.0 $207.6 $447.6 1008.0 4146.9 4147 4501.6 3037.0 1903.0 1624.6 ees $1,005.9 $1,312.09 $43.2 $1,100.14 $1,366.1 $76.0 $80.0 $85.0 $2008 saan.8 2007 1008.0 41400 4147 4661.6 3037.0 1963.0 1924.6 ees $1,005.0 $1,512.90 $43.2 $1,1001 $1,366.1 $75.0 $30.0 $85.0 $2120 $452.0 1008.0 4146.9 4147 4501.6 3037.0 1963.0 1524.6 ees $1,005.90 $1.3120 $43.2 $1,100.1 $1,396.1 $76.0 $80.0 $85.0 $2142 $454.2 1008.0 4146.0 4147 4661.6 3037.0 1063.0 1924.6 eee $1,065.9 Hse $43.2 $1,100.1 $1,350. $75.0 $80.0 $85.0 $2105 $450.5 2010 1008.0 41469 4147 4501.6 3037.0 1063.0 1624.6 ees $1,005.09 $3120 $43.2 $1,100.1 $1,356.1 $76.0 $80.0 $85.0 $2187 $466.7 2011 1008.0 4140.9 4147 4501.8 3037.0 1063.0 1824.6 ees $1,086.9 $1.3120 $43.2 $1,100. $1,390.1 $75.0 $20.0 $85.0 $221.0 $461.0 1008.0 4146.0 447 4501.0 3037.0 1063.0 1824.6 ess $1,005.9 $1.3120 $43.2 $1,100.1 $1,386.1 $76.0 $20.0 $85.0 $223.4 $4034 Page of 2 2013 1008.0 4140.9 4147 4601.6 3037.0 1063.0 1824.6 ess $233.1 $287.1 $43.2 $276.3 $330.3 $76.0 $20.0 $95.0 $2258 $405.8 2014 1008.0 41409 4147 4501.6 3037.0 1963.0 1624.6 ess $00 $00 $43.2 $432 $432 $75.0 $200 $85.0 seoe2 $408.2 Lho 5. ANNUAL COST ($1000) o% 7.0% A. CREDIT FOR SALES TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1000) 6% 7.0% G. PRESENT WORTH ($1000) TOTAL ANNUAL COST 8% 7.0% D. ACCUMULATED PRESENT ($1000, WORTH TOTAL ANNUAL COST 5% 7.0% 6. ENERGY COST $/KWH A. ENERGY SOLD MWH B. COST ENERGY $/KWH o% 7.0% . PRESENT WORTH ENERGY $vKWH o% 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.6% 1993 $1.717.0 $1,910.0 $0.0 $1,717.0 $1,100 $1,717.0 $1,100 $1.717.0 $1,010.0 3816.1 $0.460 $0.601 $0.460 $0.501 $0.450 ‘$0.501 19004 $1,555.3, $1,802.3 $00 $1,556.3 $1,802.3 $1,510.0 $1,7408 $3,227.0 $3,060.8 3816.1 $0.408 90.472 $0.306 $0.450 $0.64 $0.9590 1905 $1,636.6 $1,783.6 $207.4 $1.320.2 $1,976.2 $1,262.90 $1.486.7 $4,470.90 $5,146.06 3816.1 $0.348 $0.413 $0.328 $0,380 $1.174 $1,349 1990 $1,538.56 $1,786.6 $2102 $1,328.3 $1,875.3 $1,215.06 $1,441.60 $5,005.4 $0,587.2 3815.1 $0.348 $0.413 $0.319 $0.378 $1.493 $1,727 (ALTERNATIVE 11-6) 1907 $1,640.4 $1,787.4 $213.1 $1,327.4 $1,574.4 $1,1703 $1,308.8 $0,874.8 $7,086.0 3815.1 $0.348 $0.413 ‘$0 309 $0.307 $1,802 $2,003 1098 $1,542.4 $1,780.4 $216.9 $1,326.4 $1,673.4 $1.1442 $1,367.3 $8,010.0 $9,343.3 3816.1 $0.348 $0412 $0.300 $0.356 $2.102 $2449 1990 $1,644.3 $1,791.4 $218.0 $1,928.5 $1,972.65 $1,1101 $1,316.08 $0.120.0 $10,660.2 3815.1 $0.347 $0412 $0.201 $0.345, $2.303 $2.704 $1,546.3 $1,703.3 $221.8 $1,324.5 $1,671.65 $1.076.9 $1,277.8 $10,206.0 $11,038.0 3816.1 $0.347 $o.4i2 $0.282 $0.335 $2675 $3.120 $1,648.3 $1,705.4 $224.8 $1,323.65 $1,570.68 $1,044.8 $1,230.8 $11,2508 $13,177.8 3816.1 $0.347 some $0.274 $0,325 $2,040 $3.454 $1,560.4 $1,707.4 $227.8 $1,322.6 $1,500.6 $1,013.6 $1,203.0 $12,204.46 $14,380.8 3816.1 $0.347 $0.411 $0.26 $0.315 $3.215 $3: 760 2003 $1,952.5 $1,700.85 $230.9 $1,321.68 $1,668.6 $083.4 $1,167.2 $13,247.8 $16,547.0 3816.1 $0.346 $0411 $0.268 $0.306 $3.472 $4.076 $1,554.6 $1,801.6 $2340 $1.320.5 $1,567.68 $084.0 $1.132.4 $14,201.7 $16,680.4 3816.1 90.346 $0411 $0.250 $0.207 $3.72 $4,372 $1,666.7 $1,803.7 $237.2 $1.3105 $1.600.5 $025.5 $1,008.7 $16,127.2 $17,701 3816.1 $0.346 $0.411 $0.243 $0.288 $3.965 $4,000 $1,568.90 $1,805.90 $240.4 $1,318.5 $1,506.5 $207.8 $1,066.0 $16,026.0 $18,846.1 3816.1 $0.346 90.410 $0.235 $0.270 $4,200 $4.040 2007 $1,501.1 $1,808.1 $243.0 $1,317.4 $1,564.4 $871.0 $1,034.3 $16,606.0 $10,870.4 3816.1 $0.345 $0.410 $0.228 $0.271 $4,420 $6.211 $1,503.3 $1.810.3 $240.0 $1,316.4 $1,963.4 $844.9 $1,003.5 $17.740.0 $20,882.9 3816.1 $0.345 $0.410 $0.221 $0.263 $4,650 95.474 2000 $1,505.5 $8126 $250.3 $1.316.3 $1,562.3 $810.6 $073.6 $18,660.6 $21,860.5 3816.1 $0.345 $0.40 $0.215 $0.265 $4.865 $6.720 2010 $1,607.8 $1,814.8 $263.6 $1.3142 $1,961.2 $706.1 $044.5 $19,366.7 $22,801.0 3815.1 $0344 $0.409 $0.208 $0248 $6.073, $6.976 2011 $1,670.1 $1,817.2 $257.1 $1.313.1 $1,900.1 $71.3 $016.4 $20,126.9 $23,717.4 3815.1 $0.344 $0.40 $0.202 $0.240 $5.276 $0.217 $1,972.85 $1,810.5 $200.5 $1,311.09 $1,550.0 $748.2 $880.1 $20,875.1 $24,000.5 3816.1 $0344 $0.409 $0.196 $0.233 $6.472 $0.450 Page 202 2013 $742.1 $706.1 $204.1 $478.0 $932.1 $264.7 $204.6 $21,130.68 $24,901.0 3815.1 $0.126 $0.130 $0,060 $0.077 $6.541 $0.527 2014 $511.4 $511.4 $207.6 $243.8 $2438 $131.0 $131.0 $21,2708 $25,032.1 3816.1 $0.064 $0.064 $0.034 $0.034 $5.675 ‘$0.501 POWER COST STUDY AKIAGHAK, AKIAK, KWETHLUK, TULUKSAK, NYAC, NAPASKIAK, OSCARVILLE & NAPAKIAK Page 1 of 2 + NYAG HYDRO INTERTIED TO BETHEL WITH SINGLE POLE, 3 WIRE, 3 PHASE TRANSMISSION LINE (ALTERNATIVE 12:4) 1903-1004 1005 10081007 1998 1909 2000 2001 2002 2003 2004 2008 2008 2007 2008 2009 2010 2011 2012 2013 2014 1. LOAD DEMAND ‘A DEMAND - KWH 1008.0 10321 10682 10803 11044 11285 11526 11767 12008 12240 12400 12701 13002 13303 13004 13005 14206 14607 14008 16100 1860.0 B ENERGY - MWH 41480 4264.5 4302.0 44000 © 46772 «= 40847 «= 47023 «48000 © 80075 5115.0 «= 2220 «53543 «= 4861 = SH17.8 —-674GH «= S8B1.S NIG. 0144.8 «= O27HS = 8408S HOO C. TRANSMISSION 106.9 «1702 «1745 = 17881831 187.4 191.7 196.0 200.3 204.6 208.9 2142 2104 = eea7 230.0 235.3 240.5 245.8 261.1 260.3 201.0 LINE LOSSES @ 4% D. TOTAL ENERGY 43128 4424.6 © 4636.6 «40484 «4700.3 «48721 «© 40840 © 5008.9) 62078 §=— 83106 «= 431.5 ©5085 ©=— 5705.5 «= S42 = 807.5 = BT1HH = 253.6 ©3006 627.0 0804.6 0801.O 88104 REQUIREMENTS - MWH E. MWHAVAILABLE 0 ©2600» 8000 50008000 ‘6000 6000 ‘6000 6000 6000 5000 5000 5000 5000 000 ‘000 8000 6000 5000 ‘5000 6000 6000 FROM NYAG HYDRO F. VILLAGE HYDRO 0.0 26000 3021.0 30800 31502 32233 «32004 «933875 «034247 = 3401.8 «= 3558.0 )=— 3841.1 «37233 «= 380565 «= 8B7Z.7 «= BOHN 40SZT «= 41343 ARIS aOR 43810 44483 USAGE - MWH @. SURPLUS MWH HYDRO a0 00 10781 1011.0 18438 © 1778717008) 10426 = 18753 © 18082 1441.1 13680) 1278.7 11045) 1112310301 947.0 806.7 783.5 701.2 0190 903.7 SALES TO BETHEL UTILITIES H.MWH PURCHASES: 21564 10240 15146 15504 10041 16480 16036 17384 17831 18270 18726 10274 19822 20370 20018 21466 22014 22602 23110 23058 24200 24002 FROM BETHEL UTILITIES 2 INVESTMENT COSTS ($1000, A. TRANSMISSION LINE $10,073 $0 $0 $0 $0 $0 $0 $0 $0 $o $0 $o $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 B.NYAG HYDRO $2,700 $2,700 $0 to to $0 $0 $0 $0 $0 $0 $0 $o $0 fo $o $0 $0 $0 $0 $0 $0 G. TOTAL INVEST. GOST ($1000) $12,773 $2,700 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $0 $o 3. FIKED COSTS ($1000) A. DEBT SERVICE INCLUDING ‘CONSTRUCTION INTEREST @ 7.6% o% $1,1028 $1,336.0 $1,336.0 $1.3360 $1.330.0 $1,336.0 $1,336.0 $1,338.00 $1,3360 $1,3360 $1,338.0 $1,330.0 $1,336.00 $1.3380 $1.336.0 $1,336.0 $1,336.0 $1,330.0 $1.3380 $1.3380 = $233.1 $00 7.0% $1,358.4 $1,646.0 $1,045.6 $1,045.68 $1,045.60 $1.045.0 $1,045.6 $1,045.06 $1,045.60 $1,045.60 $1,045.0 $1.045.0 $1.645.0 $1,0456 $1,045.6 $1,045.60 $1.046.6 $1,046.6 $1.045.0 $1,0456 $2871 $0.0 B. INSURANCE Oo $432 $432 $432 $432 $43.2 $432 $432 $43.2 $43.2 $432 © $43.2 $43.2 $432 $43.2 $43.2 $43.2 $43.2 432 $432 $43.2 $43.2 G. TOTAL FIKED COST ($1000) 8% $1,1028 $1,3702 $1,3702 $1,3702 $1.3702 $1,3702 $1,3702 $1,3702 $1,3702 $1,3702 $1,3702 $1,3702 $1,3702 $1,3702 $1,702 $1,702 $1,3702 $1,372 $1,3702 $1.3702 $2703 $43.2 7.0% $1,368.4 $1,088.8 $1,088.8 $1,088.8 $1,088 $1,0888 $1.0888 $1,0888 $1,0888 $1,0888 $1,0888 $1,.0888 $10888 $1,088 $1,0088 $1.0688 $1.0888 $1,0886 $1,0088 $1.0888 $3303 $43.2 4. PRODUCTION COSTS ($1000) A. OPERATIONS AND MAINT 1. TRANSMISSION LINE $760 $750 $750 «= $750 $76.0 $76.0 $75.0 $75.0 $75.0 $75.0 $76.0 $76.0 $76.0 $760 = $760 $76.0 $75.0 $76.0 $750 © $750 $75.0 $75.0 2 HYDRO: $00 8©=—- $40.0 $800 $800 $800 $80.0 $80.0 $80.0 $80.0 $80.0 $80.0 $80.0 $80.0 $80.0 $80.0 $80.0 $800 $80.0 $80.0 $80.0 $80.0 $80.0 3. ADMINISTRATIVE $850 $850 «$8500 $8600 $850 $95.0 $96.0 $96.0 $85.0 $85.0 $96.0 $96.0 $26.0 $25.0 $05.0 $86.0 $95.0 $85.0 $950 6 $86.0 $25.0 $85.0 B. SELF GENERATION 431.3 ° o ° ° ° ° ° ° ° ° ° ° ° ° ° ° ° ° ° ° ° PURCHASES FROM $254.3 $2312 $1872 $1047 $2023 $2100 «$217.0 = $2260 «= $2341 = $2424 = $2600 = $2800 $271.1 «= $2815 = $2021 «= $B0ND«« $31SG = $3251 «= $3385 «= $3481 = $3800 §=— $3703 BETHEL UTILITIES D. TOTAL PROD. GOSTS ($100, $8455 $431.2 $4272 $4347 $4423 $4800 9 $457.0 «= $405.9) $474.1 «= $4824 «= $4000» $5009) $511.1 $5215 «= $8321 SNR S53) 0 $5051 = $5705 «= $5881 = $8099 = SOS oTu 5, ANNUAL GOST ($1000) 6% 7.0% A. CREDIT FOR SALES: TO BETHEL UTILITIES B. TOTAL ANNUAL COST ($1009, ox 7.0% C. PRESENT WORTH ($100 TOTAL ANNUAL COST 8% 7.0% D. AGGUMULATED PRESENT ($1000, WORTH TOTAL ANNUAL GOST o* 7.0% ©. ENERGY COST $/KWH A ENERGY SOLD MWH B. COST ENERGY $/KWH 6% 7.0% G. PRESENT WORTH ENERGY KWH % 7.0% C. ACCUMULATED PRESENT WORTH OF ENERGY $/KWH 7.0% 1903 $1,048.4 $2,204.0 $00 $1.048.4 $2,204.00 $1,048.4 $2,2040 $1,048.4 $2,204.0 3816.1 $0.511 $0578 $0.511 $0578 $0611 $0.678 1004 $1,810.3 $2,110.90 $00 $1,8103 $2.1199 $1,757.60 $2,058.2 $3,708.0 $4,2022 30141 $0.463 $0,542 $0.440 $0.526 $0,000 $1,104 1995 $1,800.4 $2.1100 $200.0 $1,507 4 $1,007.00 $1,505.7 $1,7075 $5.211.7 $8,0507 4013.1 $0.308 $0.476 $0.375 0.448 91.336 $1.651 1990 $1,813.09 $2,1236 $204.7 $1,000.2 $1,018.86 $1,472.7 $1,766.0 $0,004.3 $7,815.7 41120 $0.301 $0.407 $0,358 $0427 (ALTERNATIVE 12-8) 1907 $1,8215 $2,131.14 $200.1 $1,621.3 $1,030.0 $1.440.5 $1,716.68 98.1248 $9.531.3 4211.0 $0 385, $0.460 $0.342 $0.407 $2035 $2386 1998 $1,820.2 $2,138.68 $108.4 $1.4003 $1,676.4 $0,534 $11,207.7 4310.0 $0.370 $0.461 $0.327 $0.380 $2362 $2775 1999 $1,637.1 $2.140.7 $100.6 $1,040.5 $1,056.1 $1,378.0 $1,038.2 $10,013.00 $12,845.09 4408.0 $0.373 $0444 $0.313 $0372 $2075 $3140 $1,045 $2.1647 $185.6 $1,050.5 $1,0001 $1.3403 $1,001.1 $12,202.3 $14.4400 4807.0 $0.368 $0.437 $0 200 $0.365 $2074 $3,502 $1,853.3 $2,162.90 $1804 $1,872.90 $1,082.55 $1,320.68 $1,565.0 $13,562.90 $16.011.0 $0,363 $0.430 $0.287 $0340 $3201 $3841 $1,801.68 $2.171.2 $1751 $1,086.5 $1,006.2 $1,202.6 $1,520.90 $14,875.85 $17,541.86 4705.8 $0.358 $0.424 90.275 90.325 $3538 $4106 $1,870.1 $2.170.7 $1005 $1,700.68 $2.0102 $1,205.4 $1,405.68 $16,1400 $10,037.6 4804.8 $0. 364 $0.418 $0.203 $0.311 $3700 $4.478 $1,880.1 $2.1807 $ie2z0 $1,7181 $2,0277 Si2a12 $1,404.9 $17,3821 $20,502.4 4926.0 $0.340 0.412 $0.262 $0.207 $4,051 $4.775 $1,800.3 $2,1000 $154.3 $1.736.0 $2,045.68 $1.2176 $1,434.8. $18,500.7 $21,937.22 6047.2 $0.344 $0.405 $0.24) $0284 $4202 $5.060 $1,900.7 $2,210.3 $140.3 $1,7544 $2,004.0 $1,1047 $1,405.65. $19,704.4 $23,342.7 5108.4 $0.3390 $0,300 $0.231 $0.272 $4,623 $5.331 2007 $1,011.3 $2,220.90 $138.0 $1,732 $2,082.86 $1,1723 $1.377.0 $20,006.7 $24.710.7 $0.335 $0.304 $o.222 $0.260 $4.745 $5.502 $1,0220 $2.2317 $206 $1.7025 $2.1021 $1,150.56 $1,340.3 $22,117.2 $26,060.0 ss108 90.331 $0 388, $0.213 $0.249 $4.05 $5.841 $1,033.0 $2,242.06 1208 $8122 $2,121.68 $1,120.3 $1,322.2 $23,240.5 $27,301.2 66320 $0 328 $0.384 $0204 $0230 96.102 $6.080 $1,044.2 $2,263.86 S198 $1.6324 $2.1420 $1,108.6 $1,206.90 $24,365.1 $28,087.1 5063.2 $0.324 $0.370 90.106 $0,220 $6.368 $6.300 2011 $1,055.6 $2,206.2 $1026 $1.853.0 $2.1626 $1,088.56 $1,270.3 $25,443.5 $20,057.5 5774.4 $0321 $0.375 $0188 $0.220 $5546 $0.520 $1,007.2 $2,276.06 $031 $1.6742 $2,183.86 $1,008.8 $1,245.4 $20,5124 $31,202.68 $0.318 $0.370 $0.161 $0211 $5.728 $0.740 Page 2ot2 2013 $970.2 $930.3 $83.3 $703.0 $847.0 $430.1 $400.0 $26,051.4 $31,071.86 co18.8 $0.132 90.141 $0.073 $0.078 $6.601 so.818 2014 $053.6 $053.6 $765 $578.0 $5760 $3107 $3107 $27,202.1 $31,062.55 61131 $0.005 $0,006 $0.051 $0.051 $5.651 $6 800