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City of Chignik Lake Wind Resource Feasibility Assessment - Jun 2011 - REF Grant 2195409
Lake and Peninsula Borough Chignik Lake Wind Resource Assessment Final Report June 1, 2011 prepared for: Lamar Cotten Lake and Peninsula Borough 429 L Street Anchorage, Alaska 99501 Telephone: (907) 301-8737 Facsimile: (907) 246-6602 prepared by: Knight Piésold and Co. 1580 Lincoln Street, Suite 1000 Denver, Colorado 80203-1512 USA Telephone: (303) 629-8788 Facsimile: (303) 629-8789 E-mail:denver@knightpiesold.com KP Project No. 103-00240.01 DV-11-0348 Rev. No. Date Description Knight Piésold Client 0 6/1/2011 Issued as Final Rick R. Damiani Lamar Cotten Chignik Lake WRA Final Report, Rev 0 ES-1 Lake and Peninsula Borough Chignik Lake Wind Resource Assessment Final Report Executive Summary This report presents a feasibility-level investigation of several alternatives for the construction of a wind power facility at Chignik Lake, Alaska, and includes discussions of the site characteristics, wind climate, preliminary cost estimates, and an economic analysis. The report is also based on a site visit conducted in October/November 2009, and information from vendors, experience with similar projects, and published information on developed community-size wind power projects. Construction of a wind power facility at Chignik Lake presents many challenges in part due to its remoteness and distance from a major urban center. The village is located on the Alaska Peninsula approximately 470 miles southwest of Anchorage and is accessible only by boat or by air. The local runway is a 3,200-foot gravel airstrip that is suitable only for small aircraft. Water access is via the Chignik River, which is subject to tidal fluctuations, and is only navigable by boats with a shallow draft. These factors together with the high costs of mobilization, transport of equipment and materials, and of transmission line construction in remote areas yield a relatively high cost-per-installed-kilowatt (kW) of wind power. No major environmental or permitting obstacle is expected at this time. However, several state and federal agencies will need to be involved from the inception of the project. The current average electrical load for the village is about 48 kW, and significant growth in demand is not anticipated in the near future. In addition, there is no readily available market for any excess power that may be produced. Therefore, the concept for this study was to minimize costs by designing a facility that generally meets the current needs of the village, while at the same time utilizing excess wind power for space heating purposes and hot water. A 30-meter (100 foot) meteorological tower instrumented for wind data collection was erected and began collecting data in November 2009. Data was collected for over a year and the wind resource assessment for the local geographical area was primarily based on the measured data at this tower. The data underwent a rigorous quality assurance process to compensate for the tower shadowing effects on the anemometers and wind vanes. During the site survey in the fall of 2009, data on the electric and thermal loads of the village, the current diesel expenses, and the suitability of a new wind power installation was also gathered. Further, more recent (2011) data was collected on the cost of diesel. In order to verify the site suitability for wind turbine installations, and to calculate values of capacity factor (CF) and annual energy production (AEP) for various turbine models, a refined wind flow model was produced based on: measured wind data, correlations to long-term Automated Weather Observing System (AWOS) station data from a near-by airport (Chignik Bay), high-definition (1 meter [m]) digital elevation models, and surface roughness. Four turbine models (in their cold-weather package configurations) were considered: Northwind 100B/21 rated at 100 kW; Vestas V27 (marketed as A27) rated at 225 kW; Vergnet GEV-MP-C rated at Chignik Lake WRA Final Report, Rev 0 ES-2 275 kW (at the time of writing still without a certified cold weather package); and Enercon E33 rated at 330 kW. The four turbines differ in size and control systems. The Northwind and Enercon turbines do not have a gearbox, which simplifies maintenance. The Northwind 100 is the only turbine in the group which does not have pitch control. Pitch control assures an optimal energy capture at various wind speeds, regulates the RPMs at the highest wind speeds, and protects the machine by feathering the blades in potentially damaging strong wind events. At the same time, the moving parts are more numerous and the possibility of failures increases. The Vergnet turbine can be mounted on a guyed tubular tower that can be lowered for maintenance and in case of forecasted strong wind storms. All the other models come with standard monopole towers, which let the operator climb inside a weather-protected environment. The Northwind 100 could also be mounted on a new lattice system (Parafold), which allows the turbine to be lowered with a winch, does not require heavy cranes for the installation, and allows for simplified foundations. The Parafold system, however, is still in its infancy and should be re-evaluated at the time of project implementation. The calculated AEPs, assuming a 10 percent loss (due to turbine availability, electrical losses, soiling, etc.), range between 300 and 1,200 megawatt hours per year (MWh/yr) depending on the turbine model assumed, indicating a high wind penetration. Lower penetration levels are not economically viable at Chignik Lake. The various turbine candidate sites showed small variations in AEP for any given turbine model, thus allowing for some flexibility in the final site selection. Only one site significantly underperformed compared to the other sites and should be left as a last resort. The modeling was done at the most common and likely most cost effective tower height of 37 m. An economic analysis using the HOMER© Micropower Optimization Model (U.S. Department of Energy, 2005 [6]) was conducted for the four turbine models for the site that showed the best wind resource among those identified during the site survey. The HOMER© model output includes several economic measures, including present worth, that show the value of the difference between the wind power alternative and the current diesel-only system. Present worth shows how much the alternative system saves over the project lifetime compared to the diesel-only system, and is the primary measure for comparing the economic feasibility of the two systems. Each alternative was compared to the current diesel system using four assumed prices for diesel fuel: the current price of US$4.25 per gallon (data from City of Chignik Lake reflects purchase in Fall 2010), a price of US$5.50 per gallon (estimated cost of delivered fuel in Spring 2011), a price of US$6.92 per gallon (based on a crude oil price of US$125/bbl), and a price of US$8.30 per gallon (based on a crude oil price of US$150/bbl). This approach gives an idea of how the economics of each alternative compares to the current system assuming different prices for diesel, which is the major determinant of the cost of energy produced by the current system. While a due-diligence of the machines needs to be carried out before arriving at the final solution and selection of the most suitable model, the economic analysis has revealed the main results summarized in Table 1. These results are from analysis at the expected Spring 2011 diesel price of US$5.50 per gallon and at the most economic site (site 1). The color coding associated with the benefit/cost ratios identifies with green the ‘best economic alternative’, cyan the ‘second best’, orange the marginal, and red the unfeasible alternative. Chignik Lake WRA Final Report, Rev 0 ES-3 Table 1. Summary of economic results for alternatives at Site 1 with diesel price of US$5.50/gal. Option at Site 1 Capital (USD) Present Worth (USD) Discounted (Simple) Payback (years) Annual Worth (USD/year) Levelized COE (USD/kWh) Benefit/ Cost Ratio Northwind - 100 kW 1,391,682 -57,870 n/a (15.9) -3,854 0.467 0.986 Vestas -A27 - 225 kW 1,761,912 203,723 18.5 (14.2) 13,567 0.425 1.053 Vergnet - 275 kW 1,917,642 106,177 17.1 (13.5) 7,071 0.441 1.027 Enercon - 330 kW 2,115,894 171,103 17.9 (13.9) 11,395 0.430 1.044 2 Northwind - 200 kW 2,238,325 -351,507 n/a (17.6) -23,409 0.513 0.920 3 Northwind - 300 kW 3,035,716 -1,029,703 n/a (n/a) -68,574 0.621 0.796 The Vestas A27 and the Enercon E33 are the most economically attractive alternatives. As the price of diesel fuel increases, the Enercon becomes more attractive than the Vestas alternative. For a long-term diesel price of US$6.92/gal, the lowest levelized cost-of-unit-energy (COE) is obtained with an Enercon E33 installed at Site 1, resulting in a projected reduction in COE of about US$0.12/kWh. For a long-term diesel price of US$8.30/gal, the lowest levelized cost-of-unit-energy (COE) is obtained with an Enercon E33 installed at Site 1, resulting in a projected reduction in COE of about US$0.21/kWh. Enercon has a very solid reputation in the international market and has successfully installed turbines throughout the world and in harsh environments in Canada and Antarctica for wind-diesel applications. A patent-dispute prevented Enercon from exporting to the U.S. until 2010. The Vestas A27 has shown a relatively good track-record, and may be preferable to the Vergnet for the sheltered conditions inside the tower and nacelle. It is also worthy of mention that Vergnet does not currently offer a cold weather package which would be necessary for Chignik Lake. The manufacturer has communicated that it should become available in the near future. The Northwind 100B/21 has shown an impressive reliability, though it has only been in the market and operational for less than a decade. This model is considerably more expensive (50 percent) than the others on a per-installed-kW basis, and only at diesel prices at or above US$6.92/gal is economically promising. The analysis does not account for emergency maintenance following major unexpected events, but that could be a factor for machines having spare parts difficult to retrieve. For this reason, it is recommended that an inventory of spare parts be acquired at the time of project installation. Because of the harsh wind regime, it can also be expected that a 50-year wind gust may be encountered during the lifetime of the project, and discussion with the turbine manufacturer is encouraged to verify which components may fail under those circumstances. If 80 percent of the project’s initial capital is guaranteed by a state grant, all the configurations analyzed are economically advantageous to the local community and Borough. Results are given in Section 5.7. Recommendations for future activities include: x Investigate whether suitable financing is available to develop a wind power installation at Chignik Lake given the illustrated initial capital costs and economic benefits. Chignik Lake WRA Final Report, Rev 0 ES-4 x Initiate permitting process, starting with Federal Aviation Administration (FAA) determination of no- hazard to air navigation, while also initiating discussions with state and federal agencies to identify potential environmental and permitting issues. x Contact Enercon to assess exporting capabilities to the U.S. x Identify potential parallel projects that could share the costs for heavy construction equipment, transportation of materials, etc. x Conduct geotechnical investigations at the turbine installation site(s). x Identify and recruit local potential workers for construction activities, with the double benefit of reducing expenses and involving the local community in the project. x Identify suitable contractors and engineering/construction management firms. Chignik Lake WRA Final Report, Rev 0 i Lake and Peninsula Borough Chignik Lake Wind Resource Assessment Final Report Table of Contents Page Executive Summary ................................................................................................ ES-1 Section 1.0 - Introduction.......................................................................................... 1-1 1.1Background ................................................................................................................................... 1-1 1.2Scope of Work ............................................................................................................................... 1-1 1.3Sources of Information .................................................................................................................. 1-1 1.4Limitations and Disclaimer ............................................................................................................ 1-2 1.5Contributors and Contacts ............................................................................................................ 1-2 Section 2.0 - General Site Conditions ....................................................................... 2-1 2.1Site Location ................................................................................................................................. 2-1 2.2Climate .......................................................................................................................................... 2-1 2.3Geology ......................................................................................................................................... 2-1 2.4Permitting ...................................................................................................................................... 2-1 Section 3.0 - Preliminary Wind-Flow Modeling and Tower Installation ................. 3-1 3.1Wind Flow Modeling ...................................................................................................................... 3-1 3.2Site Survey and Data Acquisition .................................................................................................. 3-4 Section 4.0 - Refined Wind Resource Assessment ................................................. 4-1 4.1Refined Wind Resource Map ........................................................................................................ 4-1 4.2Turbine and System Alternatives .................................................................................................. 4-4 4.3Annual Energy Production Estimates ........................................................................................... 4-6 Section 5.0 - Economic Analysis .............................................................................. 5-1 5.1Inputs and Assumptions ................................................................................................................ 5-1 5.2System Alternatives Analyzed ...................................................................................................... 5-2 5.3Estimated Capital and Replacement Costs .................................................................................. 5-2 5.4Estimated Operation and Maintenance Costs .............................................................................. 5-3 5.5Estimated Diesel Prices ................................................................................................................ 5-4 5.6Economic Analysis Results ........................................................................................................... 5-4 5.7State Funding Impact .................................................................................................................. 5-10 Section 6.0 - Environmental and Construction Permitting ..................................... 6-1 6.1FAA Permitting .............................................................................................................................. 6-1 Chignik Lake WRA Final Report, Rev 0 ii 6.2Construction Permitting ................................................................................................................. 6-1 6.3Alaska Coastal Management Program ......................................................................................... 6-1 6.4U.S. Fish and Wildlife Service, Alaska Department of Fish and Game: Birds, Bats, Endangered Species Protection, Fish Habitat ................................................................................................................ 6-2 6.5State Historic Preservation Office and Office of History and Archeology ..................................... 6-2 6.6Land Uses and Rights-of-Way ...................................................................................................... 6-2 6.7Wetlands and Other Waters .......................................................................................................... 6-2 6.8National Environmental Policy Act Review ................................................................................... 6-2 6.9Tentative Cost Estimates associated with Environmental and Construction Permitting .............. 6-3 Section 7.0 - Conclusions and Recommendations ................................................. 7-1 7.1Wind Feasibility Study Conclusions .............................................................................................. 7-1 7.2Other Relevant Remarks............................................................................................................... 7-2 7.3Recommendations for Future Activities ........................................................................................ 7-2 Section 8.0 - References ............................................................................................ 8-1 Tables Table 1 Summary of economic results for alternatives at Site 1 with diesel price of US$5.50/gal. Table 2 Instrumentation Parameters. Table 3 Annual Energy Production and Capacity Factor for all four turbine models at four potential sites. Hub height held constant at 37 m. Table 4 AEP and CF for two largest turbines with 50 m hub heights. Table 5 Wind turbine system alternatives analyzed. Table 6 Estimated costs for installation of turbine alternatives, excluding transmission line (US$). Table 7 Total estimated cost of turbine installation at each site (US$). Table 8 Total estimated cost of multiple installments of the Northwind 100 turbine (US$). Table 9 Estimated replacement cost of turbines at the end of the project (US$). Table 10 Economic analysis results for four proposed turbines at four proposed sites with 37 m tower, Diesel @ $4.25/gal. Table 11 As in Table 10, Diesel @ US$5.50/gal. Table 12 As in Table 10, Diesel @ US$6.92/gal, in line with crude at US$125/bbl. Table 13 As in Table 10, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. Table 14 Economic analysis results for multiple Northwind 100 turbines at two proposed sites with 37-m tower, Diesel @ US$4.25/gal. Table 15 As in Table 14, Diesel @ US$5.50/gal. Table 16 As in Table 14, Diesel @ US$6.92/gal, in line with crude at US$125/bbl. Table 17 As in Table 14, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. Table 18 Economic analysis results for four proposed turbines at four proposed sites with 37-m tower and 80 percent state funding, Diesel @ US$4.25/gal. Table 19 As in Table 18, Diesel @ US$5.50/gal. Table 20 As in Table 18, Diesel @ US$6.92/gal, in line with crude at US$125/bbl Table 21 As in Table 18, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. Table 22 Economic analysis results for multiple Northwind 100 turbines at two proposed sites with 37-m tower with 80 percent state funding, Diesel @ US$4.25/gal. Table 23 As in Table 22, Diesel @ US$5.50/gal. Table 24 As in Table 22, Diesel @ US$6.92/gal, in line with crude at US$125/bbl. Table 25 As in Table 22, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. Figures Chignik Lake WRA Final Report, Rev 0 iii Figure 1 Filled contours of wind speed at 37 m above ground level (agl) as derived from a preliminary numerical model overlaid onto topographical contour lines in the geographical area surrounding Chignik Lake. Topo-contour interval is 5 m (lake is at ~2 m mean sea level [msl]). Topography, surface roughness and other factors affect the wind flow. This calculation employs data from nearby Chignik Bay to deduce a first approximation wind flow distribution at Chignik Lake Figure 2 Potential tower sites marked with small blue circles and red ‘x’ marks. Red circles are centered on either end of the airstrip and have a radius of 1.5 kilometer. Background is a LandSat satellite image Figure 3 As in Figure 2 with a USGS Topo-Map in the Background Figure 4 Wind Speed, Energy, and Direction distribution at Tower Location 01 (tip of Chignik Lake Peninsula) denoted as Current Site (reference is CB Tower) Figure 5 As in Figure 4 for Tower Site 07B Figure 6 View of the tower fully erected Figure 7 Wind Distribution at the Chignik Lake MET-Tower (CL_Tower) Figure 8 Wind Rose at the Chignik Lake MET-Tower (CL_TOWER) Figure 9 Turbulence at location of CL_TOWER with IEC standards Figure 10 Wind resource map: mean annual wind speeds at 37 m AGL for the Village of Chignik Lake. Horizontal resolution is 10 m Figure 11 Power curves for the four wind turbine models. Top row: NW100B/21, Vestas A27; bottom Figure 12 Seasonal electric demand at Chignik Lake.row: Vergnet GEV MP-C, Enercon E33 Figure 13 Seasonal thermal demand at Chignik Lake School Appendices Appendix A Wind Data Report from The Chignik Lake Met-Tower Appendix B Measure Correlate Predict: Correlation Between Tower Data and PAJC AWOS Station Appendix C Annual Energy Calculations, 37 m Hub-Heights (approximately 120 ft AGL) Appendix D Northwind 100B/21 Economics Appendix E Enercon E33 Economics Appendix F Vergnet GEV-MP-C Economics Appendix G Vestas A-27 Economics Appendix H Multiple Northwind 100B/21 (37 m Hub Height) Economics Chignik Lake WRA Final Report, Rev 0 1-1 Lake and Peninsula Borough Chignik Lake Wind Resource Assessment Final Report Section 1.0 - Introduction 1.1 Background Knight Piésold and Co. (Knight Piésold) was contracted by Lake and Peninsula Borough (LPB) to carry out a feasibility study for the community of Chignik Lake in the Southwest Alaskan Peninsula to verify the economic viability of a wind-diesel electric generation facility. The hybrid facility could provide lower cost of energy to the local community, which currently relies on diesel generators to provide electricity. Previous studies conducted in the area1 estimate that the cost of electricity generated by a small wind power facility could be up to US$0.03/kWh below the projected cost of electricity from diesel generators with heat recovery. This report highlights the main aspects involved in the study at Chignik Lake and the results of the economic analysis for four different types of wind turbines. This project (103-240/01) is part of a widespread wind regional assessment being carried out at various communities within the LPB boundaries. 1.2 Scope of Work The scope of work included both a preliminary and a detailed wind resource assessment (WRA), site survey to identify suitability of wind turbine installations, and collection of data for input to an economic analysis, namely: village electrical and thermal load data, village fuel expenses, vendors’ and contractors’ information, and quotations. Also included in the scope of work is a review of the permitting requirements. Following a site visit and an initial screening process, four sites were selected for a more detailed analysis, including a conceptual project layout, an estimate of power generation, a preliminary cost estimate, and an analysis of the economic feasibility. 1.3 Sources of Information Information used during the study included GPS data obtained during the site visit; information on wind data, power and fuel consumption from: the power plant maintenance personnel; the Lake and Peninsula Borough; the Lake and Peninsula School District; and the City of Chignik Lake; information on the design of the existing power plant from the City of Chignik Lake; information on the physical setting collected by Knight Piésold staff during a site visit; geologic maps and reports, topographic and land-usage maps from 1 Information Insights, 2008: The Lake and Peninsula Borough Regional Energy Plan, Fairbanks, Alaska. Chignik Lake WRA Final Report, Rev 0 2-1 Section 2.0 - General Site Conditions 2.1 Site Location The village is located on the Alaska Peninsula approximately 470 miles southwest of Anchorage and is accessible only by boat or by air. The local runway is a 3,200-foot gravel airstrip that is suitable only for small aircraft. Water access is via the Chignik River, which is subject to tidal fluctuations, and is only navigable by boats with a shallow draft. 2.2 Climate The nearest weather station is at Chignik Bay, about 15 miles northeast of Chignik Lake. The average annual precipitation at Chignik Bay is 83 inches, with an average annual snowfall of 46 inches. The climate of Chignik Lake is typical of the Alaska Peninsula, with cool, rainy summers and moderately cold winters with precipitation occurring as rain or snow. Seasonal temperature extremes can range from 10 degrees Fahrenheit (°F) in mid-winter to as high as 65°F in the summer. Average January temperatures range from 20°F to 31°F. Average July temperatures range from 46°F to 61°F. 2.3 Geology The area is characterized by sedimentary bedrock (sandstone, siltstone, conglomerate, shale, and coal), with mixed unconsolidated sedimentary deposits (alluvial, colluvial, glacial, and marine) in some areas. The mountains southwest of Chignik Lake are volcanic [2]. 2.4 Permitting At this time, no major permitting obstacles are foreseen, though state and federal agencies will need to be involved from the inception of the project. In particular, the presence of an important airport for the community will require the FAA to issue a determination of no hazard to air navigation posed by the wind turbine installation (see Section 6). Chignik Lake WRA Final Report, Rev 0 3-1 Section 3.0 - Preliminary Wind-Flow Modeling and Tower Installation 3.1 Wind Flow Modeling A numerical simulation was employed to look at wind flow trends around the town of Chignik Lake, Alaska. This simulation was necessary to identify candidate sites for the met-tower (and potentially the wind turbine to be deployed in the future) based on terrain and wind characteristics. The following extensive data was collected: USGS topographical maps, Digital Elevation Maps (DEMs), and satellite imagery. Additionally, surface roughness data was acquired based on satellite MODIS mission and analysis of aerial imageries and maps. Wind data was purchased for the AWOS station at Chignik Bay, Alaska (PAJC) and for a wind monitoring tower (CB tower) installed in proximity of the same town (approximately 13 miles to the east of Chignik Lake). The CB tower’s data had to be manipulated and correlated to PAJC to correct for some deficiencies in and to validate the data. As a result, a local climatology was calculated, and this was then numerically transferred to the site of interest. The acquired data was used in a WAsP® calculation to evaluate the wind speed trends over the topography about Chignik Lake. The results are shown in Figure 2. Figure 2. Filled contours of wind speed at 37 m above ground level (agl) as derived from a preliminary numerical model overlaid onto topographical contour lines in the geographical area surrounding Chignik Lake. Topo-contour interval is 5 m (lake is at ~2 m mean sea level [msl]). Topography, surface roughness and other factors affect the wind flow. This calculation employs data from nearby Chignik Bay to deduce a first approximation wind flow distribution at Chignik Lake. Note that these wind speed values were used qualitatively only, due to large uncertainties in the numerical calculations using wind data from 13 miles away. Town of Chignik Lake, AK Chignik Lake WRA Final Report, Rev 0 3-2 The accumulated results led to the identification of (14) fourteen candidate sites for tower installation. They can be seen as ‘x’ marks in Figure 2 through Figure 4. Most of the 14 locations were further analyzed to look at wind directional distribution. In most cases the predominant wind direction appeared to be WNW, or aligned with the runway at Chignik Lake. An example of this wind rose is provided for ‘Tower Location 01’ in Figure 5. Figure 3. Potential tower sites marked with small blue circles and red ‘x’ marks. Red circles are centered on either end of the airstrip and have a radius of 1.5 kilometer. Background is a LandSat satellite image. A geological map was also acquired to narrow down the number of potential installation sites based on soil conditions. However, the information in the USGS map was not adequate to discard any of the initially selected sites. An application was filed with the FAA to assess any potential hazard to air navigation for tower sites 1, 2, 3, 9, 10, 11, 13, and 14. Unfortunately, because of time restrictions and incumbent weather threats, the project could not wait for an FAA approval notice of no-hazard and those locations had to be discarded from the study. Note that the best locations for wind resource appear to be at the tip of the peninsula protruding into the lake. In particular, tower locations 1, 11, and 10 were the preferred location for a turbine installation due to the quality of the wind resource (highest expected wind speeds and lowest turbulence, minimum terrain and lowest surface roughness in the upwind direction [WNW]). Chignik Lake WRA Final Report, Rev 0 3-3 Figure 4. As in Figure 3 with a USGS Topo-Map in the Background. Chignik Lake WRA Final Report, Rev 0 3-4 Figure 5. Wind Speed, Energy, and Direction distribution at Tower Location 01 (tip of Chignik Lake Peninsula) denoted as Current Site (reference is CB Tower). 3.2 Site Survey and Data Acquisition In Fall 2009, staff members from Knight Piésold traveled to Chignik Lake, Alaska, carrying the meteorological instruments. At the same time, a used met-tower was shipped from Anchorage. Hardware components were missing from the tower and had to be purchased and fabricated by Knight Piésold personnel and subcontractors. The tower and instrumentation underwent a rigorous inventory check and functionality test; the top portion of the tower was then painted to FAA specs. A GPS-guided, photographical survey of most of the locations was executed during the first three days of the site visit. Select pictures from the survey are shown in Knight Piésold’s Met-Tower Installation Report [4] for the tower sites that were examined in greater detail. Some of the candidate sites were inaccessible due to the dense vegetation and absence of roads or trails. This made it impossible with the limited resource and time to erect a tower at those locations. Other locations required crossing of the river, and this turned out to be too big of a challenge for transportation and acquisition of the data from local project staff. FAA restrictions led to the selection of site 07b. Details of the installation are found in reference [4]. A view of the erected tower can be seen in Figure 7. After commissioning of the tower, Knight Piésold staff performed a few routine checks on data quality and tower hardware. Data was inspected for compliance for four days while staff was on site. The instrumentation on the tower is mounted according to the parameters as shown in Table 2. Official valid data collection started on 11/01/2009 at 11:00 AST. Chignik Lake WRA Final Report, Rev 0 3-5 Table 2. Instrumentation Parameters. Instrument Channel Name Height [m AGL] Orientation Cup Anemometer A1 28.3 330º Cup Anemometer A2 28.3 240º Cup Anemometer B 17.3 330º Wind Vane A 27.3 330º (offset=+150º) Temperature Probe T 3 0º The cup anemometers’ booms were oriented to minimize the tower shadow (aerodynamic effects due to the tower on the measurements), and according to the preliminary study which resulted in the wind direction and energy distribution rose as given in Figure 6. The cup anemometers were therefore oriented at 45º from the expected predominant WNW wind direction. Figure 6. As in Figure 5 for Tower Site 07B. Chignik Lake WRA Final Report, Rev 0 3-6 Figure 7. View of the tower fully erected. Chignik Lake WRA Final Report, Rev 0 4-1 Section 4.0 - Refined Wind Resource Assessment 4.1 Refined Wind Resource Map A refined WRA was conducted with the goal of assessing the wind regime at an altitude between 30 and 50 m AGL at various locations across the site. The model employed high resolution terrain elevation in the immediate proximity of the village. This data was kindly provided by Mr. Lamar Cotten (LPB Manager) and Mr. George Plumley (Planner, Dept. of Commerce, State of Alaska). Wind data from the combined anemometer readings at the installed meteorological tower described above was correlated to the long-term (last 10 years) data set at the Chignik Bay (PAJC) AWOS station. Wind speed and direction distributions as received from the met-tower can be seen in Figure 8 and Figure 9. The correlation coefficient proved to be 0.8 and this allowed the creation of a dependable long- term reference dataset (wind statistics) at high altitude (approximately at 30 m [100 feet] AGL). The wind climatology of the generic site at Chignik Lake was then devised by weighted averaging, over the terrain and surface characteristics, the information from the two wind statistics at the Chignik Lake AWOS station (approximately 10 m or 30 feet AGL) and the meteorological tower. Figure 8. Wind Distribution at the Chignik Lake MET-Tower (CL_Tower). Chignik Lake WRA Final Report, Rev 0 4-2 Figure 9. Wind Rose at the Chignik Lake MET-Tower (CL_TOWER). Chignik Lake WRA Final Report, Rev 0 4-3 Figure 10. Turbulence at location of CL_TOWER with IEC standards. Figure 10 shows the turbulence intensity measured at the meteorological tower as a function of wind speed. The smooth curves represent the IEC standards for turbulence. The turbulence intensity at the tower location is relatively high but within acceptable values for a category A wind turbine. A high resolution (10 m) resource map showing average annual wind speeds at a height of 37 m above ground was produced as output of the model. The wind resource map shows wind power classes ranging from 4 to 6. The yellow regions correspond to the high class 6 wind speeds and are, in general, the optimal sites for a wind turbine. Four of these potential sites were chosen for further analysis and are labeled in Figure 11 as WTG_1 through WTG_4. Chignik Lake WRA Final Report, Rev 0 4-4 Figure 11. Wind resource map: mean annual wind speeds at 37 m AGL for the Village of Chignik Lake. Horizontal resolution is 10 m. 4.2 Turbine and System Alternatives Given the results of the refined WRA, four different models of turbines were modeled at each of the four proposed locations. The turbines considered in this study are the following: x Northern Power Systems Northwind NW100B/21 rated at 100 kW x Vestas V27 (marketed as A27) rated at 225 kW x Vergnet GEV-MP-C rated at 275 kW x Enercon E33 rated at 330 kW Power curves for the four machines are given in Figure 12. Enercon GmbH (Enercon) has been engaged in a legal battle with General Electric (GE) for patent infringement; there has been extensive evidence that espionage against Enercon enabled the competitor GE to patent turbine components first [5]. Enercon was therefore effectively banned from exporting to the U.S. until 2010. New recent cross-patent agreements and the experience of Enercon technology for wind- diesel applications make that model suitable for this study. The four models have been selected as among the most reliable and effective machines for the conditions at Chignik Lake. They are either IEC class I or class II, with turbulence category A or B. From Figure 10, it can be seen that only turbine design category A is adequate for Chignik Lake. ASCE 7-05 [1] recommends a 50-year design wind speed of 58 meters per second (m/s) at 10 m AGL, which would translate into 65-66 m/s gusts at hub-heights, making it an IEC class I site. The Enercon E33 is the only class I machine. With the exception of the E33 and the Vergnet GEV MP-C, which could be lowered and protected during a strong wind storm, the other models would likely suffer from some considerable damage in such an event. For the expected life of the project (20 years), the probability of exposure to such a catastrophic event is on the order of 30 percent. This value is significant enough to warrant more discussion with the manufacturers to verify the expected damage and costs of repair under a 65 m/s (approximately 130 knots) wind gust. It is also worthy of note that the Vergnet machine currently does not have a cold weather package. Due to the cold climate at Chignik Lake, this would lead to a reduced annual energy production, and increased sensitivity of the project performance to the temperature. This machine is still included in the analysis though this issue would need to be addressed in the later stages of the project if Vergnet has not yet released the cold weather package they are currently developing. Chignik Lake WRA Final Report, Rev 0 4-5 Figure 12. Power curves for the four wind turbine models. Top row: NW100B/21, Vestas A27; bottom row: Vergnet GEV MP-C, Enercon E33. The four turbines differ in size, tower arrangement, and control systems. The Northwind and Enercon turbines do not have a gearbox, with simplified maintenance. The Northwind 100 is the only turbine in the group that does not have pitch control. Pitch control assures an optimal energy capture at various wind speeds, regulates the rotor speed at the highest wind speeds, and protects the machine by feathering the blades in potentially damaging strong wind events. At the same time, with active pitch control the moving parts are more numerous and the cost and likelihood of maintenance increases. The Vergnet turbine can be mounted on a guyed tubular tower that can be lowered for maintenance and in case of forecasted strong wind storms. All the other models come with standard monopole towers, which let the operator climb inside a weather-protected environment. The NW100 B/21 could also be potentially mounted on an innovative lattice tower system (Parafold) which allows the turbine to be lowered with a winch, does not require heavy cranes for the installation, and allows for simplified foundations. At the time of this report, Northern Power Systems would not release the costs of the individual components, and is not willing to sell an incomplete package with only nacelle plus blades. Therefore no reduction in costs is considered in the economic analysis, but during procurement phase this could be an option to re-evaluate. Regardless of the selected model alternative, the turbine generator would produce 3-phase, 60-hertz, 480-volt electricity. The 480-volt electrical output from the generator would be converted to 12.5 kilovolts (kV) by a step-up transformer and then connected to the village electrical grid by a 12.5 kV transmission line. The wind-power system for Chignik Lake should supply (to the extent possible) the thermal load that is currently supplied by diesel furnaces at the school. This would allow the system to reduce even further the cost of unit energy, making it more attractive. Thus, the proposed wind-power system includes an Chignik Lake WRA Final Report, Rev 0 4-6 electric hot water boiler, a supervisory control system, and a secondary load controller, which supply the thermal load during those times when wind generated power is in excess of demand. An installment of one of the larger machines would lead to significant amounts of excess energy generated, even after heating the school. This excess energy can be used in a number of configurations to further reduce the cost of energy. 4.3 Annual Energy Production Estimates Table 3 summarizes the AEP and CF for the various turbines at the various sites including a 10 percent loss due to turbulence, blade soiling, and other miscellaneous items that may cause degraded performance. This table was generated for a machine hub height of 37 meters. Table 3. Annual Energy Production and Capacity Factor for all four turbine models at four potential sites. Hub height held constant at 37 m. Turbine Model Potential Site 1 Potential Site 2 Potential Site 3 Potential Site 4 AEP (MWh) CF AEP (MWh) CF AEP (MWh) CF AEP (MWh) CF Northwind 100B/21 347 39.6%356 40.6%334 38.1%350 40.0% Vestas A27 752 38.2%772 39.2%720 36.5%760 38.6% Vergnet GEV-MP-C 932 38.7%957 39.7%896 37.2%943 39.1% Enercon E33 1210 41.9%1242 43.0%1166 40.3%1223 42.3% The variation in AEP over sites 1, 2, and 4 is about 2.5 percent and is considered within the modeling errors (1-3 percent). Site 3 shows approximately 4-6 percent less energy production than the other three sites and thus it should be left as a last resort in selection of the final turbine site. In general, all four potential sites show encouraging results which allows for some flexibility in the final siting. The Enercon turbine is the best performing machine with the highest CF at all four sites. The smaller Northwind machine is the second most efficient option. The much larger power rating of the Enercon turbine may require additional electronics and controllers to ensure a stable village grid under a very high renewable fraction (order of 80 percent). The renewable fraction is the portion of the load that is met by the wind turbine. However, the diesel cost savings associated with this higher power rating would be higher. The smaller Northwind machine still achieves relatively high renewable fractions (order of 40 percent) and may only require a relatively simpler control system which may lead to savings in the capital cost of the system. The other two machines fall somewhere in the middle of this range. Another way to quantify a wind turbine’s impact on electricity production is its penetration level. The average annual penetration level is the amount of energy produced by the wind turbine in a year, divided by the energy consumed by the load in a year. The Northwind, Vestas, Vergnet, and Enercon turbines give annual average penetration levels of about 83 percent, 178 percent, 221 percent, and 285 percent. These are all considered high or very high penetration levels. For the largest of the machines, the Vergnet and Enercon machines, there is value in considering a much taller tower and thus higher hub height. Table 4 shows the AEP and CF for these two larger machines with a hub height of 50 m. Chignik Lake WRA Final Report, Rev 0 4-7 Table 4. AEP and CF for two largest turbines with 50 m hub heights. Turbine Model Potential Site 1 Potential Site 2 Potential Site 3 Potential Site 4 AEP (MWh) CF AEP (MWh) CF AEP (MWh) CF AEP (MWh) CF Vergnet GEV-MP-C 997 41.4%1007 41.8%974 40.4%1011 42.0% Enercon E33 1289 44.6%1302 45.0%1261 43.6%1306 45.2% The increase in production due to the taller tower is site dependent and ranges from 4.5 to 8 percent. The use of these taller towers may involve complications with shipping and installation of the turbine, as well as additional costs. For this reason, the 50-m hub height alternatives are not included in the economic analysis at this time. The appropriate hub height for a turbine will be further addressed in the design phase of the project. Chignik Lake WRA Final Report, Rev 0 5-1 Section 5.0 - Economic Analysis 5.1 Inputs and Assumptions The economic analysis of a wind power installation at Chignik Lake was carried out for all four proposed sites as described above. The AEP used in the economic study is the AEP that corresponds to a specific turbine located at a specific site. These AEPs were calculated by the detailed analysis in WindPRO®. The actual discount rate assumed is 2.9 percent, with a nominal interest rate and inflation rate of 5 and 2 percent respectively. The project lifetime is 20 years. It is assumed that an electric boiler would be paired with the existing heating system at the school. The electric boiler would be governed by a dedicated secondary load controller to utilize excess wind energy coming from the turbine when the electric load is low, thus allowing a further reduction in fuel costs for heating. The interconnection of the turbine will occur either at the powerhouse or at the easternmost interconnection of the existing village transmission line, whichever is closest to the final location of the turbine. A separate supervisory controller is needed for high levels of wind penetration. The three larger turbines give average annual wind penetration levels of 180-280 percent and would thus require this extra controller. The smaller Northwind turbine shows wind penetration levels of about 80% and may or may not require this extra controller. For the purpose of this economic analysis it is assumed that this extra controller would be required and it is thus included in the cost analysis for all four turbine models. The seasonal electric load at Chignik Lake including the monthly maximum, average daily high, monthly mean, average daily low, and monthly minimum values, is given in Figure 13. It is estimated that the average electricity consumption is 1,150 kWh/day with average load of 48 kW and peaks to 112 kW during the winter months. Figure 13. Seasonal electric demand at Chignik Lake. The average daily thermal load data for Chignik Lake was estimated using data from Port Heiden, which is another community on the Alaska Peninsula with a population and climate similar to Chignik Lake. The average thermal load is estimated to be 1,195 kWh per day. Statistics for the estimated monthly thermal power consumption in kW at Chignik Lake, including the monthly maximum, average daily high, daily mean, average daily low, and monthly minimum values are shown in the Figure 14. Chignik Lake WRA Final Report, Rev 0 5-2 Figure 14. Seasonal thermal demand at Chignik Lake School. 5.2 System Alternatives Analyzed The system alternatives that were analyzed can be seen in Table 5. Table 5. Wind turbine system alternatives analyzed. Turbine Model Hub-Heights (m) Qty. NW100B/21 37 1,2,3 Vestas A27 37 1 Vergnet GEV-MP-C 37 1 Enercon E33 37 1 Higher hub-heights may be more profitable for the larger machines, but foundations and permitting may become more cumbersome and expensive. Transport of the turbines and specifically their towers may also become more challenging and expensive. Thus, it was decided to limit the analysis to the most common configurations as seen above. 5.3 Estimated Capital and Replacement Costs An opinion of probable project costs for the various alternatives was developed based on March 2011 U.S. dollars. The opinion of probable project costs includes construction, engineering, and contingency. Overall project cost was established by adding engineering, permitting, and legal fees. Engineering costs include preliminary and final design, procurement, construction management, and administration. Table 6 shows the estimated costs for the installation of the various alternatives and do not include the cost of transmission lines. The cost of transmission lines varies depending on the site the turbine will be installed. The total estimated cost of the turbine installment for each site can be seen in Table 7. The data were obtained after consulting with the turbine vendors and the following construction and transportation contractors: GeoTek Alaska, Inc., STG, Inc., Sustainable Automation Inc., Northland Services Marine Transportation, and Bellavance Trucking. These cost estimates should be considered accurate to within ±30 percent at the time of project implementation. Because of the remoteness of Chignik Lake, most of the capital costs come from having to transport personnel, materials, components, and special construction equipment to the site. The capital cost would increase or decrease depending on crude oil price fluctuations, as those affects transportation and manufacturing processes. However, there is very little information at this point to provide a solid justification to changes in the current estimates that are provided with a ±25 percent margin. Table 6. Estimated costs for installation of turbine alternatives, excluding transmission line (US$). Vestas Vergnet Enercon Northwind Turbine + Tower $422,500 $610,000 $615,000 $370,000 Shipment $195,000 $145,000 $195,000 $60,000 Transformer $36,050 $36,050 $41,200 $30,900 Supervisory Controller $105,000 $105,000 $105,000 $105,000 Chignik Lake WRA Final Report, Rev 0 5-3 Secondary Controller $40,000 $40,000 $40,000 $40,000 Boiler and misc. $25,000 $25,000 $25,000 $25,000 Power line (US$300k/mile) VARIES VARIES VARIES VARIES Geotechnical Investigation and Report $90,000 $90,000 $90,000 $90,000 Engineering/Permitting/Construction/Erection $451,377 $443,652 $548,712 $335,502 Total $1,364,927 $1,494,702 $1,659,912 $1,056,402 With 20% Contingency $1,637,912 $1,793,642 $1,991,894 $1,267,682 Installed Cost per kW $7,280 $6,522 $6,036 $12,677 Table 7. Total estimated cost of turbine installation at each site (US$). Site Vestas Vergnet Enercon Northwind 1 $1,761,912 $1,917,642 $2,115,894 $1,391,682 2 $1,978,912 $2,134,642 $2,332,894 $1,608,682 3 $1,792,912 $1,948,642 $2,146,894 $1,422,682 4 $1,823,912 $1,979,642 $2,177,894 $1,453,682 The total estimated cost of installing more than one Northwind 100 turbine at a given site can be seen in Table 8. The replacement cost of a turbine at the end of the project can be seen in Table 9. Table 8. Total estimated cost of multiple installments of the Northwind 100 turbine (US$). Site 1 Site 2 Site 3 Site 4 2 Northwind 100 $2,238,325 $2,672,325 $2,300,325 $2,362,325 3 Northwind 100 $3,035,716 $3,686,716 $3,128,716 $3,221,716 Table 9. Estimated replacement cost of turbines at the end of the project (US$). Vestas A27/225 Vergnet GEV-MP-C Enercon E33 Northwind 100B/21 Replacement Cost $200,000 $200,000 $250,000 $100,000 5.4 Estimated Operation and Maintenance Costs A fixed system operation and maintenance (O&M) cost of US$23,000 per year was used for both the combined wind power/diesel system and the current system. This is an average salary for a maintenance mechanic at the power house. US$1.25 per operational hour is the additional rate assumed for the O&M of diesel generators. For the wind system, an US$8,500/year O&M cost per installed turbine is assumed; this includes salary amounting to 1 day/month for a local mechanic plus 2 days every three months for a specialized mechanic from Anchorage and airfares. If two or three turbines are installed, the O&M is calculated at US$17,000 and US$25,500 respectively. The overall diesel generator O&M will be less in the combined system due to reduced diesel usage, however the salary of the local mechanic will be higher for the additional maintenance tasks at the wind turbine. The current O&M cost is based on information provided by the City of Port Heiden and by the Lake and Peninsula School District (LPSD) for Chignik Lake. It is assumed that the maintenance cost of the generators at Port Heiden is the same as the maintenance cost of the generators at Chignik Lake on a per kWh basis. Chignik Lake WRA Final Report, Rev 0 5-4 5.5 Estimated Diesel Prices Four different values for delivered diesel prices were assumed: US$/liter 1.12, 1.45, 1.83, 2.19 (US$/gal 4.25, 5.50, 6.92, 8.30). The current value at the time of compiling this report is approximately US$/gal 4.25 (LPSD data). The current price reflects delivery in the fall of 2010. At the time of this report the cost of delivered diesel for Spring 2011 was unknown but was assumed to be closer to $5.50 per gallon to reflect the recent increase in the price of crude oil. The largest estimates are in line with projected long- term crude oil price of US$125/bbl and US$150/bbl. See also LPB Energy Report [3]. 5.6 Economic Analysis Results The software program HOMER© [5] was employed to simulate the economic performance of the various turbines. In Appendices D-H, complete output reports from the program are provided for the various system alternatives. The HOMER© analysis produces several economic measures that show the value of the difference between the wind/diesel alternative under consideration and the current diesel-only system, taking into account the 20-year life cycle costs of both systems. Definitions of the economic measures shown in the following sections are as follows: x The present worth is the difference between the net present cost of the alternative system and the diesel-only system, where the net present cost is the present value of all system costs incurred over the project lifetime (including capital costs, replacement costs, O&M costs, and fuel costs) minus salvage value. Present worth shows how much the alternative system saves over the project lifetime compared to the diesel-only system, and is the primary measure for comparing the economic feasibility of the two systems. The present worth represents the avoided cost over the life of the project when operating the alternative system rather than the current system. x The discounted payback period is how long it would take to recover the initial investment in the alternative system using the assumed rates for interest (5 percent) and inflation (2 percent). x The annual worth is the present worth multiplied by the capital recovery factor, which is a ratio used to calculate the present value of a series of equal annual cash flows. x The Internal Rate of Return is the discount rate that makes the present value of the difference of the two cash flow sequences equal to zero. x The levelized cost of energy (COE) is the average cost per kWh of useful electrical energy produced by the system. This is calculated by dividing the annualized cost of producing electricity (the total annualized cost minus the cost of serving the thermal load) by the total annual electric energy production. x The benefit/cost ratios for each alternative compared to the diesel-only system were calculated by adding the net present cost to the present worth and then dividing by the net present cost. Table 10 through Table 13 shows the economic measures for the select wind/diesel alternatives, assuming four different values of diesel prices. The color coding associated with the benefit/cost ratio identifies with green the ‘best economic alternative’, blue the ‘second best’, orange the marginal, and red the unfeasible alternative. Table 10. Economic analysis results for four proposed turbines at four proposed sites with 37-m tower, Diesel @ $4.25/gal. NW - 100 kW 1 2 3 4 Capital (USD) 1,391,682 1,608,682 1,422,682 1,453,682 *Present Worth (USD) -379,192 -567,926 -450,302 -430,631 Discounted (simple) Payback Period (years) n/a (n/a) n/a (n/a) n/a (n/a) n/a (n/a) Chignik Lake WRA Final Report, Rev 0 5-5 **Annual Worth (USD) -25,253 -37,821 -29,988 -28,678 Internal Rate of Return (ROI) (%) n/a (4.83) n/a (4.30) n/a (4.54) n/a (4.67) Levelized Cost of Energy (USD/kWh) 0.431 0.461 0.443 0.440 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 0.895 0.850 0.877 0.882 Vergnet - 275 kW 1 2 3 4 Capital (USD) 1,917,642 2,134,642 1,948,642 1,979,642 *Present Worth (USD) -358,034 -554,506 -424,035 -410,571 Discounted (simple) Payback Period (years) n/a (18.3) n/a (n/a) n/a (19.6) n/a (18.8) **Annual Worth (USD) -23,844 -36,928 -28,239 -27,342 Internal Rate of Return (ROI) (%) 0.769 (5.41) n/a 0.39 (5.21) 0.52 (5.27) Levelized Cost of Energy (USD/kWh) 0.428 0.459 0.438 0.436 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 0.900 0.853 0.884 0.887 Vestas - 225 kW 1 2 3 4 Capital (USD) 1,761,912 1,978,912 1,792,912 1,823,912 *Present Worth (USD) -248,802 -436,678 -323,215 -300,408 Discounted (simple) Payback Period (years) n/a (17.3) n/a (20.0) n/a (18.9) n/a (17.8) **Annual Worth (USD) -16,569 -29,081 -21,525 -20,006 Internal Rate of Return (ROI) (%) 1.13 (5.71) 0.35 (5.19) 0.85 (5.45) 1.03 (5.56) Levelized Cost of Energy (USD/kWh) 0.411 0.440 0.422 0.419 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 0.928 0.880 0.909 0.915 Enercon - 330 kW 1 2 3 4 Capital (USD) 2,115,894 2,332,894 2,146,894 2,177,894 *Present Worth (USD) -349,788 -541,841 -414,091 -401,722 Discounted (simple) Payback Period (years) n/a (17.9) n/a (19.5) n/a (18.5) n/a (18.3) **Annual Worth (USD) -23,294 -36,084 -27,577 -26,753 Internal Rate of Return (ROI) (%) 1.03 (5.56) 0.214 (5.11) 0.698 (5.37) 0.802 (5.43) Levelized Cost of Energy (USD/kWh) 0.427 0.457 0.437 0.435 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 0.902 0.856 0.886 0.889 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 11. As in Table 10, Diesel @ US$5.50/gal. NW - 100 kW 1 2 3 4 Capital (USD) 1,391,682 1,608,682 1,422,682 1,453,682 *Present Worth (USD) -57,870 -238,991 -139,711 -106,532 Discounted (simple) Payback Period (years) n/a (15.9) n/a (17.6) n/a (16.5) n/a (16.1) **Annual Worth (USD) -3,854 -15,916 -9,304 -7,095 Internal Rate of Return ROI) (%) 2.44 (6.37) 1.22 (5.66) 1.81 (5.99) 2.09 (6.16) Levelized Cost of Energy (USD/kWh) 0.467 0.495 0.480 0.474 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 0.986 0.944 0.966 0.974 Vergnet - 275 kW 1 2 3 4 Capital (USD) 1,917,642 2,134,642 1,948,642 1,979,642 *Present Worth (USD) 106,177 -84,784 30,907 56,205 Discounted (simple) Payback Period (years) 18.5 (14.2) n/a (15.7) 19.7 (14.8) 19.2 (14.6) **Annual Worth (USD) 7,071 -5,646 2,058 3,743 Internal Rate of Return (ROI) (%) 3.49 (7.02) 2.47 (6.39) 3.07 (6.76) 3.20 (6.84) Levelized Cost of Energy (USD/kWh) 0.441 0.471 0.453 0.449 Chignik Lake WRA Final Report, Rev 0 5-6 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.027 0.979 1.008 1.014 Vestas - 225 kW 1 2 3 4 Capital (USD) 1,761,912 1,978,912 1,792,912 1,823,912 *Present Worth (USD) 203,723 23,555 117,641 154,873 Discounted (simple) Payback Period (years) 17.1 (13.5) 19.9 (14.9) 18.8 (14.1) 17.8 (13.8) **Annual Worth (USD) 13,567 1,569 7,834 10,314 Internal Rate of Return (ROI) (%) 4.11 (7.42) 3.03 (6.73) 3.60 (7.09) 3.80 (7.22) Levelized Cost of Energy (USD/kWh) 0.425 0.454 0.439 0.433 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.053 1.006 1.030 1.040 Enercon - 330 kW 1 2 3 4 Capital (USD) 2,115,894 2,332,894 2,146,894 2,177,894 *Present Worth (USD) 171,103 -14,267 97,829 121,891 Discounted (simple) Payback Period (years) 17.9 (13.9) n/a (15.4) 18.8 (14.4) 18.5 (14.3) **Annual Worth (USD) 11,395 -950 6,515 8,117 Internal Rate of Return (ROI) (%) 3.75 (7.20) 2.83 (6.62) 3.38 (6.96) 3.49 (7.03) Levelized Cost of Energy (USD/kWh) 0.430 0.460 0.442 0.438 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.044 0.996 1.025 1.031 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 12. As in Table 10, Diesel @ US$6.92/gal, in line with crude at US$125/bbl. NW - 100 kW 1 2 3 4 Capital (USD) 1,391,682 1,608,682 1,422,682 1,453,682 *Present Worth (USD) 311,814 139,383 217,619 266,353 Discounted (simple) Payback Period (years) 15.0 (12.1) 17.8 (13.7) 16.5 (12.9) 16.0 (12.6) **Annual Worth (USD) 20,765 9,282 14,492 17,738 Internal Rate of Return (ROI) (%) 5.20 (8.14) 3.82 (7.23) 4.49 (7.67) 4.80 (7.87) Levelized Cost of Energy (USD/kWh) 0.507 0.535 0.522 0.514 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.067 1.029 1.046 1.057 Vergnet - 275 kW 1 2 3 4 Capital (USD) 1,917,642 2,134,642 1,948,642 1,979,642 *Present Worth (USD) 640,305 455,763 554,388 593,207 Discounted (simple) Payback Period (years) 13.8 (11.2) 15.4 (12.4) 14.9 (11.7) 14.9 (11.5) **Annual Worth (USD) 42,642 30,352 36,920 39,505 Internal Rate of Return (ROI) (%) 6.23 5.08 (8.08) 5.77 (8.55) 5.91 (8.65) Levelized Cost of Energy (USD/kWh) 0.455 0.484 0.469 0.463 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.149 1.102 1.126 1.136 Vestas - 225 kW 1 2 3 4 Capital (USD) 1,761,912 1,978,912 1,792,912 1,823,912 *Present Worth (USD) 724,428 553,118 624,926 678,751 Discounted (simple) Payback Period (years) 12.9 (10.6) 15.0 (11.7) 13.6 (11.1) 13.4 (10.9) **Annual Worth (USD) 48,244 36,835 41,617 45,202 Internal Rate of Return (ROI) (%) 6.95 (9.39) 5.72 (8.52) 6.37 (8.98) 6.59 (9.13) Levelized Cost of Energy (USD/kWh) 0.442 0.469 0.458 0.449 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.172 1.126 1.145 1.159 Chignik Lake WRA Final Report, Rev 0 5-7 Enercon - 330 kW 1 2 3 4 Capital (USD) 2,115,894 2,332,894 2,146,894 2,177,894 *Present Worth (USD) 770,578 592,892 686,991 724,496 Discounted (simple) Payback Period (years) 13.5 (11.0) 15.0 (12.0) 14.3 (11.4) 13.9 (11.3) **Annual Worth (USD) 51,317 39,484 45,751 48,248 Internal Rate of Return (ROI) (%) 6.51 (9.08) 5.47 (8.35) 6.10 (8.79) 6.22 (8.87) Levelized Cost of Energy (USD/kWh) 0.434 0.463 0.448 0.442 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.185 1.136 1.161 1.172 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 13. As in Table 10, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. NW - 100 kW 1 2 3 4 Capital (USD) 1,391,682 1,608,682 1,422,682 1,453,682 *Present Worth (USD) 661,272 497,059 555,394 618,839 Discounted (simple) Payback Period (years) 12.1 (10.1) 14.2 (11.4) 13.0 (10.7) 12.6 (10.4) **Annual Worth (USD) 44,038 33,102 36,987 41,212 Internal Rate of Return (ROI) (%) 7.54 (9.81) 6.01 (8.71) 6.77 (9.25) 7.09 (9.48) Levelized Cost of Energy (USD/kWh) 0.546 0.572 0.562 0.552 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.128 1.093 1.106 1.119 Vergnet - 275 kW 1 2 3 4 Capital (USD) 1,917,642 2,134,642 1,948,642 1,979,642 *Present Worth (USD) 1,145,449 966,805 1,049,438 1,101,050 Discounted (simple) Payback Period (years) 11.1 (9.36) 12.5 (10.3) 11.6 (9.72) 11.5 (9.62) **Annual Worth (USD) 76,282 64,385 69,888 73,325 Internal Rate of Return (ROI) (%) 8.59 (10.6) 7.32 (9.67) 8.08 (10.2) 8.23 (10.4) Levelized Cost of Energy (USD/kWh) 0.469 0.497 0.484 0.476 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.245 1.199 1.220 1.234 Vestas - 225 kW 1 2 3 4 Capital (USD) 1,761,912 1,978,912 1,792,912 1,823,912 *Present Worth (USD) 1,216,820 1,053,892 1,104,609 1,174,157 Discounted (simple) Payback Period (years) 10.4 (8.83) 11.7 (9.76) 11.0 (9.24) 10.7 (9.09) **Annual Worth (USD) 81,035 70,185 73,562 78,194 Internal Rate of Return (ROI) (%) 9.39 (11.3) 8.03 (10.2) 8.75 (10.8) 8.99 (10.9) Levelized Cost of Energy (USD/kWh) 0.458 0.483 0.475 0.464 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.265 1.221 1.234 1.253 Enercon - 330 kW 1 2 3 4 Capital (USD) 2,115,894 2,332,894 2,146,894 2,177,894 *Present Worth (USD) 1,337,445 1,167,036 1,244,085 1,294,325 Discounted (simple) Payback Period (years) 10.9 (9.18) 12.0 (10.0) 11.3 (9.48) 11.2 (9.40) **Annual Worth (USD) 89,068 77,720 82,851 86,197 Internal Rate of Return (ROI) (%) 8.88 (10.9) 7.74 (9.99) 8.43 (10.5) 8.56 (10.6) Levelized Cost of Energy (USD/kWh) 0.438 0.465 0.453 0.445 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.299 1.251 1.272 1.286 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Chignik Lake WRA Final Report, Rev 0 5-8 Table 14 through Table 17 below show the results for multiple installations of the Northwind turbine at potential sites 1 and 2. These two sites represent the most economical (Site 1) and the least economical (Site 2) options for turbine installations. The other two sites (2 and 3) fall somewhere in between these two options. Table 14. Economic analysis results for multiple Northwind 100 turbines at two proposed sites with 37-m tower, Diesel @ US$4.25/gal. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 2,238,325 2,672,325 *Present Worth (USD) -814944 -1219934 Discounted (simple) Payback Period (years) n/a (n/a) n/a (n/a) **Annual Worth (USD) -54272 -81242 Internal Rate of Return (ROI) (%) n/a (4.23) n/a (3.62) Levelized Cost of Energy (USD/kWh) 0.501 0.565 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 Benefit/Cost Ratio 0.798 0.725 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 3,035,716 3,686,716 *Present Worth (USD) -1544894 -2170651 Discounted (simple) Payback Period (years) n/a (n/a) n/a (n/a) **Annual Worth (USD) -102883 -144556 Internal Rate of Return (ROI) (%) n/a (3.27) n/a (2.74) Levelized Cost of Energy (USD/kWh) 0.616 0.716 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 Benefit/Cost Ratio 0.676 0.597 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 15. As in Table 14, Diesel @ US$5.50/gal. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 2,238,325 2,672,325 *Present Worth (USD) -351507 -748715 Discounted (simple) Payback Period (years) n/a (17.6) n/a (n/a) **Annual Worth (USD) -23409 -49861 Internal Rate of Return (ROI) (%) 1.12 (5.61) n/a (4.79) Levelized Cost of Energy (USD/kWh) 0.513 0.576 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 Benefit/Cost Ratio 0.920 0.843 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 3,035,716 3,686,716 *Present Worth (USD) -1029703 -1648652 Discounted (simple) Payback Period (years) n/a (n/a) n/a (n/a) **Annual Worth (USD) -68574 -1648652 Internal Rate of Return (ROI) (%) n/a (4.40) n/a (3.68) Levelized Cost of Energy (USD/kWh) 0.621 0.719 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 Benefit/Cost Ratio 0.796 0.709 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Chignik Lake WRA Final Report, Rev 0 5-9 Table 16. As in Table 14, Diesel @ US$6.92/gal, in line with crude at US$125/bbl. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 2,238,325 2,672,325 *Present Worth (USD) 181855 -206397 Discounted (simple) Payback Period (years) 17.9 (13.9) n/a (16.1) **Annual Worth (USD) 12111 -13745 Internal Rate of Return (ROI) (%) 3.76 (7.20) 2.05 (6.14) Levelized Cost of Energy (USD/kWh) 0.528 0.589 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 Benefit/Cost Ratio 1.038 0.960 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 3,035,716 3,686,716 *Present Worth (USD) -436782 -1047898 Discounted (simple) Payback Period (years) n/a (17.5) n/a (n/a) **Annual Worth (USD) -29088 -69786 Internal Rate of Return (ROI) (%) 1.28 (5.70) n/a (4.77) Levelized Cost of Energy (USD/kWh) 0.626 0.723 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 Benefit/Cost Ratio 0.919 0.825 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 17. As in Table 14, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 2,238,325 2,672,325 *Present Worth (USD) 686118 306338 Discounted (simple) Payback Period (years) 14.6 (11.5) 17.2 (13.5) **Annual Worth (USD) 45693 20401 Internal Rate of Return (ROI) (%) 5.98 (8.70) 4.10 (7.42) Levelized Cost of Energy (USD/kWh) 0.542 0.602 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 Benefit/Cost Ratio 1.134 1.056 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 3,035,716 3,686,716 *Present Worth (USD) 123890 -479804 Discounted (simple) Payback Period (years) 18.9 (14.7) n/a (17.2) **Annual Worth (USD) 8251 -31953 Internal Rate of Return (ROI) (%) 3.33 (6.93) 1.44 (5.79) Levelized Cost of Energy (USD/kWh) 0.631 0.727 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 Benefit/Cost Ratio 1.022 0.924 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. It is clear from the results of the analysis that either a Vestas A27 or an Enercon E33 is the most suitable option for Chignik Lake. At a cost of fuel of US$5.50 per gallon (the estimated cost for Spring 2011), the most economical configuration for a wind turbine installment is a Vestas A27, 225 kW turbine located at potential site 1 with a benefit cost ratio of 1.053. An installment of this configuration would lead to a cost of energy of US$0.425 per kWh, an improvement of US$0.029 per kWh over the diesel only system. Trailing the Vestas closely, the second most economic configuration is an Enercon E33, 330 kW system installed at Chignik Lake WRA Final Report, Rev 0 5-10 site 1. This Enercon turbine becomes more economic as the price of diesel increases due to its higher power output and thus increased sensitivity to fuel prices. For the current estimated fuel price of US$5.50 per gallon, the Vestas turbine installed at site 1 would save approximately US$200,000, while the Enercon turbine would save approximately US$170,000 over the life of the project. If the cost of fuel increases to US$6.93 per gallon, the Enercon alternative becomes the most economic and would save US$770,000 while the Vestas would save about US$720,000 over the life of the project. The savings increase rapidly as diesel prices increase. The economic results indicate that the installment of more than one Northwind 100 turbine is not a feasible alternative. While it is possible that installing two Northwind 100s at Site 1 would give a positive present worth and thus save money, a single, larger turbine will always be a more economical alternative. This is due to the added cost of transmission lines for extra turbines. 5.7 State Funding Impact Lake and Peninsula Borough requested additional analyses based on the assumption that the project would be 80 percent funded by a grant from the state of Alaska. This analysis assesses the expense and return on investment incurred by the borough and the Town of Chignik Lake alone. The following tables summarize the results in the same fashion as Table 10 through Table 25. Under the state funding assumption all the alternatives are economically viable. For this reason, the color coding for benefit/cost ratio has changed to green for the most economical alternative, and blue for the less economic alternatives. In the 80 percent state funded case, the Enercon turbine is by far the most economical alternative. Potential Sites 1 and 4 give approximately equal results again allowing for some flexibility in the final siting of the turbine. The analysis again shows that although multiple installations of the Northwind turbine are economic, they are never as economically attractive as a single larger turbine. At US$5.50/gal diesel cost, an Enercon turbine installed at either site 1 or 4 would represent a savings of approximately US$1,860,000 over the life of the project. It would seem the Vergnet turbine is the second most economical alternative. However it must be kept in mind that as of now Vergnet does not have a cold weather package, and thus it is not a recommended alternative at this point. Table 18. Economic analysis results for four proposed turbines at four proposed sites with 37-m tower and 80 percent state funding, Diesel @ US$4.25/gal. NW - 100 kW 1 2 3 4 Capital (USD) 278,336 321,736 284,536 290,736 *Present Worth (USD) 734,154 719,020 687,844 730,410 Discounted (simple) Payback Period (years) 4.56 (4.21) 5.17 (4.74) 4.87 (4.48) 4.73 (4.36) **Annual Worth (USD) 48,892 47,884 45,808 48,642 Internal Rate of Return (ROI) (%) 23.9 (24.2) 21.1 (21.5) 22.4 (22.7) 23.0 (23.3) Levelized Cost of Energy (USD/kWh) 0.255 0.257 0.262 0.255 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 1.296 1.288 1.272 1.294 Vergnet - 275 kW 1 2 3 4 Capital (USD) 383,528 426,928 389,728 395,928 *Present Worth (USD) 1,176,080 1,153,208 1,134,879 1,173,143 Discounted (simple) Payback Period (years) 4.06 (3.78) 4.49 (4.15) 4.23 (3.93) 4.17 (3.88) **Annual Worth (USD) 78,322 76,799 75,578 78,126 Internal Rate of Return (ROI) (%) 26.6 (27.1) 24.1 (24.6) 25.6 (26.0) 25.9 (26.4) Levelized Cost of Energy (USD/kWh) 0.185 0.188 0.191 0.185 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Chignik Lake WRA Final Report, Rev 0 5-11 Benefit/Cost Ratio 1.576 1.559 1.545 1.574 Vestas - 225 kW 1 2 3 4 Capital (USD) 352,382 395,782 358,582 364,782 *Present Worth (USD) 1,160,728 1,146,452 1,111,115 1,158,722 Discounted (simple) Payback Period (years) 3.83 (3.58) 4.25 (3.94) 4.02 (3.75) 3.95 (3.68) **Annual Worth (USD) 77,300 76,349 73,996 77,166 Internal Rate of Return (ROI) (%) 28.2 (28.6) 25.5 (25.9) 26.9 (27.3) 27.4 (27.8) Levelized Cost of Energy (USD/kWh) 0.187 0.189 0.195 0.187 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 1.565 1.554 1.528 1.563 Enercon - 330 kW 1 2 3 4 Capital (USD) 423,179 466,579 429,379 435,579 *Present Worth (USD) 1,342,927 1,324,474 1,303,424 1,340,593 Discounted (simple) Payback Period (years) 3.95 (3.68) 4.32 (4.00) 4.09 (3.81) 4.05 (3.77) **Annual Worth (USD) 89,433 88,204 86,803 89,278 Internal Rate of Return (ROI) (%) 27.3 (27.8) 25.1 (25.6) 26.4 (26.9) 26.7 (27.2) Levelized Cost of Energy (USD/kWh) 0.158 0.161 0.164 0.159 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 0.371 0.371 Benefit/Cost Ratio 1.717 1.700 1.681 1.715 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 19. As in Table 18, Diesel @ US$5.50/gal. NW - 100 kW 1 2 3 4 Capital (USD) 278,336 321,736 284,536 290,736 *Present Worth (USD) 1,055,476 1,047,955 998,435 1,054,003 Discounted (simple) Payback Period (years) 3.39 (3.18) 3.84 (3.58) 3.61 (3.38) 3.52 (3.30) **Annual Worth (USD) 70,290 69,789 66,492 70,192 Internal Rate of Return (ROI) (%) 31.7 (31.8) 28.1 (28.3) 29.8 (30.0) 30.6 (30.7) Levelized Cost of Energy (USD/kWh) 0.290 0.291 0.299 0.290 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.356 1.353 1.331 1.355 Vergnet - 275 kW 1 2 3 4 Capital (USD) 383,528 426,928 389,728 395,928 *Present Worth (USD) 1,640,291 1,622,930 1,589,821 1,639,919 Discounted (simple) Payback Period (years) 3.07 (2.90) 3.39 (3.18) 3.20 (3.01) 3.16 (2.97) **Annual Worth (USD) 109,236 108,080 105,875 109,212 Internal Rate of Return (ROI) (%) 34.7 (35.1) 31.6 (32.0) 33.4 (33.8) 33.8 (34.2) Levelized Cost of Energy (USD/kWh) 0.197 0.200 0.205 0.197 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.690 1.677 1.654 1.689 Vestas - 225 kW 1 2 3 4 Capital (USD) 352,382 395,782 358,582 364,782 *Present Worth (USD) 1,613,253 1,606,685 1,551,971 1,614,004 Discounted (simple) Payback Period (years) 2.90 (2.74) 3.21 (3.02) 3.04 (2.87) 2.98 (2.82) **Annual Worth (USD) 107,436 106,998 103,355 107,486 Internal Rate of Return (ROI) (%) 36.7 (37.1) 33.3 (33.7) 35.1 (35.5) 35.7 (36.1) Levelized Cost of Energy (USD/kWh) 0.202 0.203 0.211 0.201 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.671 1.666 1.629 1.671 Enercon - 330 kW 1 2 3 4 Chignik Lake WRA Final Report, Rev 0 5-12 Capital (USD) 423,179 466,579 429,379 435,579 *Present Worth (USD) 1,863,818 1,852,048 1,815,344 1,864,206 Discounted (simple) Payback Period (years) 2.99 (2.83) 3.27 (3.07) 3.10 (2.92) 3.07 (2.89) **Annual Worth (USD) 124,122 123,339 120,894 124,148 Internal Rate of Return (ROI) (%) 35.6 (36.0) 32.7 (33.1) 34.4 (34.8) 34.7 (35.2) Levelized Cost of Energy (USD/kWh) 0.162 0.164 0.169 0.162 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 0.457 0.457 Benefit/Cost Ratio 1.865 1.855 1.824 1.865 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 20. As in Table 18, Diesel @ US$6.92/gal, in line with crude at US$125/bbl NW - 100 kW 1 2 3 4 Capital (USD) 278,336 321,736 284,536 290,736 *Present Worth (USD) 1,425,160 1,426,330 1,355,765 1,426,304 Discounted (simple) Payback Period (years) 2.62 (2.48) 2.96 (2.80) 2.78 (2.64) 2.72 (2.57) **Annual Worth (USD) 94,910 94,988 90,288 94,986 Internal Rate of Return (ROI) (%) 40.6 (40.7) 36.0 (36.1) 38.2 (38.3) 39.2 (39.3) Levelized Cost of Energy (USD/kWh) 0.331 0.330 0.342 0.330 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.405 1.406 1.378 1.406 Vergnet - 275 kW 1 2 3 4 Capital (USD) 383,528 426,928 389,728 395,928 *Present Worth (USD) 2,174,419 2,163,476 2,113,302 2,176,922 Discounted (simple) Payback Period (years) 2.40 (2.28) 2.65 (2.51) 2.50 (2.37) 2.47 (2.34) **Annual Worth (USD) 144,807 144,078 140,737 144,974 Internal Rate of Return (ROI) (%) 44.0 (44.4) 40.0 (40.4) 42.4 (42.8) 42.9 (43.3) Levelized Cost of Energy (USD/kWh) 0.212 0.213 0.221 0.211 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.786 1.779 1.747 1.787 Vestas - 225 kW 1 2 3 4 Capital (USD) 352,382 395,782 358,582 364,782 *Present Worth (USD) 2,133,958 2,136,248 2,059,255 2,137,881 Discounted (simple) Payback Period (years) 2.26 (2.16) 2.51 (2.38) 2.37 (2.26) 2.33 (2.22) **Annual Worth (USD) 142,113 142,265 137,138 142,374 Internal Rate of Return (ROI) (%) 46.6 (47.0) 42.2 (42.6) 44.5 (44.9) 45.3 (45.7) Levelized Cost of Energy (USD/kWh) 0.218 0.218 0.230 0.218 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.760 1.761 1.714 1.762 Enercon - 330 kW 1 2 3 4 Capital (USD) 423,179 466,579 429,379 435,579 *Present Worth (USD) 2,463,294 2,459,207 2,404,506 2,466,811 Discounted (simple) Payback Period (years) 2.34 (2.23) 2.56 (2.43) 2.43 (2.31) 2.40 (2.29) **Annual Worth (USD) 164,045 163,773 160,130 164,279 Internal Rate of Return (ROI) (%) 45.0 (45.4) 41.4 (41.8) 43.5 (43.9) 43.9 (44.4) Levelized Cost of Energy (USD/kWh) 0.166 0.167 0.175 0.165 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 0.557 0.557 Benefit/Cost Ratio 1.994 1.990 1.948 1.997 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Chignik Lake WRA Final Report, Rev 0 5-13 Table 21. As in Table 18, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. NW - 100 kW 1 2 3 4 Capital (USD) 278,336 321,736 284,536 290,736 *Present Worth (USD) 1,774,618 1,784,005 1,693,540 1,778,234 Discounted (simple) Payback Period (years) 2.15 (2.06) 2.44 (2.32) 2.29 (2.18) 2.24 (2.13) **Annual Worth (USD) 118,182 118,807 112,783 118,423 Internal Rate of Return (ROI) (%) 48.9 (49.1) 43.4 (43.5) 46.1 (46.2) 47.2 (47.3) Levelized Cost of Energy (USD/kWh) 0.369 0.368 0.382 0.368 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.439 1.443 1.411 1.440 Vergnet - 275 kW 1 2 3 4 Capital (USD) 383,528 426,928 389,728 395,928 *Present Worth (USD) 2,679,563 2,674,519 2,608,352 2,684,764 Discounted (simple) Payback Period (years) 1.99 (1.90) 2.19 (2.09) 2.06 (1.98) 2.04 (1.95) **Annual Worth (USD) 178,448 178,112 173,705 178,794 Internal Rate of Return (ROI) (%) 52.7 (53.2) 48.0 (48.4) 50.8 (51.2) 51.4 (51.8) Levelized Cost of Energy (USD/kWh) 0.225 0.226 0.237 0.225 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.854 1.851 1.813 1.858 Vestas - 225 kW 1 2 3 4 Capital (USD) 352,382 395,782 358,582 364,782 *Present Worth (USD) 2,626,351 2,637,022 2,538,939 2,633,287 Discounted (simple) Payback Period (years) 1.87 (1.80) 2.07 (1.98) 1.96 (1.88) 1.93 (1.85) **Annual Worth (USD) 174,904 175,615 169,083 175,366 Internal Rate of Return (ROI) (%) 55.8 (56.3) 50.6 (51.0) 53.4 (53.8) 54.3 (54.7) Levelized Cost of Energy (USD/kWh) 0.234 0.232 0.248 0.233 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 1.824 1.830 1.775 1.828 Enercon - 330 kW 1 2 3 4 Capital (USD) 423,179 466,579 429,379 435,579 *Present Worth (USD) 3,030,160 3,033,351 2,961,599 3,036,640 Discounted (simple) Payback Period (years) 1.94 (1.86) 2.12 (2.03) 2.01 (1.92) 1.99 (1.91) **Annual Worth (USD) 201,796 202,008 197,230 202,277 Internal Rate of Return (ROI) (%) 53.9 (54.3) 49.5 (50.0) 52.1 (52.6) 52.6 (53.1) Levelized Cost of Energy (USD/kWh) 0.170 0.169 0.181 0.169 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 0.651 0.651 Benefit/Cost Ratio 2.088 2.090 2.038 2.093 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 22. Economic analysis results for multiple Northwind 100 turbines at two proposed sites with 37-m tower with 80 percent state funding, Diesel @ US$4.25/gal. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 447,665 534,465 *Present Worth (USD) 975716 917926 Discounted (simple) Payback Period (years) 5.29 (4.84) 6.28 (5.66) **Annual Worth (USD) 64979 61130 Internal Rate of Return (ROI) (%) 20.6 (21.2) 17.3 (18.1) Levelized Cost of Energy (USD/kWh) 0.216 0.226 Chignik Lake WRA Final Report, Rev 0 5-14 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 Benefit/Cost Ratio 1.435 1.399 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 607,143 737,343 *Present Worth (USD) 883679 778722 Discounted (simple) Payback Period (years) 6.28 (7.07) 8.25 (7.80) **Annual Worth (USD) 58849 51860 Internal Rate of Return (ROI) (%) 15.3 (16.4) 12.3 (13.7) Levelized Cost of Energy (USD/kWh) 0.231 0.248 Diesel Only Cost of Energy (USD/kWh) 0.371 0.371 Benefit/Cost Ratio 1.379 1.319 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 23. As in Table 22, Diesel @ US$5.50/gal. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 447,665 534,465 *Present Worth (USD) 1439153 1389145 Discounted (simple) Payback Period (years) 3.89 (3.63) 4.60 (4.25) **Annual Worth (USD) 95842 92511 Internal Rate of Return (ROI) (%) 27.7 (28.0) 23.5 (24.0) Levelized Cost of Energy (USD/kWh) 0.229 0.237 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 Benefit/Cost Ratio 1.558 1.528 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 607,143 737,343 *Present Worth (USD) 1398870 1300722 Discounted (simple) Payback Period (years) 5.05 (4.63) 6.13 (5.54) **Annual Worth (USD) 93159 86623 Internal Rate of Return (ROI) (%) 21.4 (22.0) 17.6 (18.4) Levelized Cost of Energy (USD/kWh) 0.236 0.251 Diesel Only Cost of Energy (USD/kWh) 0.457 0.457 Benefit/Cost Ratio 1.534 1.479 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 24. As in Table 22, Diesel @ US$6.92/gal, in line with crude at US$125/bbl. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 447,665 534,465 *Present Worth (USD) 1972515 1931463 Discounted (simple) Payback Period (years) 2.98 (2.82) 3.53 (3.30) **Annual Worth (USD) 131361 128627 Internal Rate of Return (ROI) (%) 35.7 (36.0) 30.4 (30.7) Levelized Cost of Energy (USD/kWh) 0.244 0.25 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 Benefit/Cost Ratio 1.664 1.642 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 607,143 737,343 Chignik Lake WRA Final Report, Rev 0 5-15 Present Worth (USD) 1991791 1901475 Discounted (simple) Payback Period (years) 3.82 (3.56) 4.62 (4.26) Annual Worth (USD) 132645 126630 Internal Rate of Return (ROI) (%) 28.1 (28.5) 23.4 (23.8) Levelized Cost of Energy (USD/kWh) 0.241 0.255 Diesel Only Cost of Energy (USD/kWh) 0.557 0.557 Benefit/Cost Ratio 1.675 1.625 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Table 25. As in Table 22, Diesel @ US$8.30/gal, in line with crude at US$150/bbl. 2 NW - 100 kW (200 kW) 1 2 Capital (USD) 447,665 534,465 Present Worth (USD) 2476778 2444198 Discounted (simple) Payback Period (years) 2.45 (2.33) 2.88 (2.73) Annual Worth (USD) 164943 162773 Internal Rate of Return (ROI) (%) 43.2 (43.5) 36.8 (37.1) Levelized Cost of Energy (USD/kWh) 0.258 0.263 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 Benefit/Cost Ratio 1.742 1.725 3 NW - 100 kW (300 kW) 1 2 Capital (USD) 607,143 737,343 Present Worth (USD) 2552463 2469568 Discounted (simple) Payback Period (years) 3.10 (2.92) 3.74 (3.50) Annual Worth (USD) 169983 164463 Internal Rate of Return (ROI) (%) 34.3 (34.7) 28.6 (29.0) Levelized Cost of Energy (USD/kWh) 0.246 0.259 Diesel Only Cost of Energy (USD/kWh) 0.651 0.651 Benefit/Cost Ratio 1.782 1.738 * Represents the avoided cost over the life of the project when operating the alternative system rather than the diesel system. ** Represents the avoided cost on an annual basis when operating the alternative system rather than the diesel only system. Chignik Lake WRA Final Report, Rev 0 6-1 Section 6.0 - Environmental and Construction Permitting In this Section, the necessary steps for the Permitting of the project are described. They include Environmental and Building Permitting. There are a number of agencies that will have jurisdiction on the project. While the project is on private land belonging to the native corporation at Chignik Lake, if federal or state actions such as funding or issuance of permits or licenses are involved, then the appropriate federal and state agencies will need to be consulted to start the regulatory permitting process. 6.1 FAA Permitting The FAA will need to release a “determination of no hazard to navigation” for the wind turbine at the selected site. This is usually not necessary for small wind turbines, even in proximity of small airports where terrain is relatively flat. Due to the complex terrain at Chignik Lake, a FAA Form SF 7460-1 will need to be filed well in advance of other activities, since the FAA has shown extensive delays in their responses in the past. It is expected that it will be necessary to coordinate with the Anchorage (Alaskan Region) office. Estimated time for permit is 90 days from filing. 6.2 Construction Permitting A Construction General Permit (CGP) will be needed from the Alaska Department of Environmental Conservation (ADEC) for the construction of the project. In order to get this permit, a Storm Water Pollution Prevention Plan (SWPP) will need to be completed which will include measures to mitigate detrimental effects to the environment during construction. This includes digging and pouring of foundations, tower erection, transformer construction, power line burial and potential power line poles along the road from the site to the interconnection point. Note that the impacted area is foreseen to be larger than one acre (threshold value for this permitting requirement) due to the transmission line corridor from the wind turbine site to the interconnection point. A Notice of Intent (NOI) must be submitted to the U.S. Environmental Protection Agency (EPA) within this phase. Additionally, consultations with the U.S. Fish and Wildlife Service (USFWS) and the State Historic Preservation Office will be required, together with the agencies’ determinations of “no significant effect to species or historical environment” as per Sections 6.4 and 6.5. Other building permits and electrical reviews may be needed by the entity in charge of the utility at the village. Generally speaking, the executive mechanical, civil, and electrical drawings will need to be stamped by one or more licensed professional engineers in the State of Alaska. Note that the assistance of LPB will be required in the determination of these further requirements. Estimated time for permit is 90 days from filing. 6.3 Alaska Coastal Management Program Chignik Lake is entirely included within the coastal boundaries established by the Alaska Department of Natural Resources (ADNR), Division of Coastal and Ocean Management (DCOM). Consultation with ADNR and Alaska Coastal Management Program (ACMP) will include a Coastal Project Questionnaire (CPQ) to be filled out in order to identify other agencies that may be required to be consulted regarding Chignik Lake WRA Final Report, Rev 0 6-2 the project. If at least one state or federal permit is required, a complete ACMP consistency review will be necessary. Estimated time for permit: 90 days from filing. 6.4 U.S. Fish and Wildlife Service, Alaska Department of Fish and Game: Birds, Bats, Endangered Species Protection, Fish Habitat The USFWS will need to be contacted in the development of the project. First, a review will be conducted of the draft guidelines that the Alaska Regional Office of USFWS has issued. Knight Piésold will then contact local Fish and Game offices (ADF&G), and village individuals to verify that there are no bird migratory paths affected by the installation of the wind turbine and associated power lines, roosting or nesting habitat of endangered plant or animal species. Site soil preparation may involve some coordination in order to comply with USFWS guidelines. It is known that sea-gulls and eagles are present in the area; however, no eagle nest was observed at the selected site for the wind turbine, nor is the site considered a bird gathering place. The USFWS may require pre- and post-construction observation periods based on these observations and Knight Piésold will contact ADF&G on this regard. With only one wind turbine installation expected, the impact to any bird or mammal species should be insignificant, but the USFWS will need to be made aware of the project to address issues associated with potential wildlife fatalities during operation. 6.5 State Historic Preservation Office and Office of History and Archeology A letter from State Historic Preservation Office (SHPO) stating that “no historic properties will be adversely affected by the project” will be required. An archeological survey may be required for access and construction footprint. Procedures will be coordinated with a state archeologist. Estimated time for concurrence is 30 days from filing. 6.6 Land Uses and Rights-of-Way No federal land is expected to be affected by the project, therefore only a written notice to proceed by the native corporation of Chignik Lake is required to allow project implementation. If other private land is involved, further written authorizations will be required. Note that the assistance of LPB would be required in the determination of Land Status for the areas of interest to the project. 6.7 Wetlands and Other Waters No further permit with the US Army Corps of Engineers is foreseen, since the project will not involve any construction activities in jurisdictional wetlands. However, a jurisdictional wetland survey will need to be conducted to determine the existence of any such wetlands within the project area that might be impacted by the project. 6.8 National Environmental Policy Act Review Although it is not likely that a full-blown environmental impact statement (EIS) will be required under the National Environmental Policy Act (NEPA), the preparation of an environmental assessment (EA) would most likely be required for federal and state agencies permitting requirements. The EA is an abbreviated NEPA process document that is intended to assess the potential environmental impacts of the project, provide for mitigation as required and to confirm minimal impact to the environment. The EA would be Chignik Lake WRA Final Report, Rev 0 6-3 used by the regulatory agency(s) to issue a Finding of No Significant Impact (FONSI) to the environment, thereby circumventing the need for an EIS. Note that LPB would be required to assist in this determination. 6.9 Tentative Cost Estimates associated with Environmental and Construction Permitting It is not trivial to assess the costs at this stage of the project, especially since there are many unknowns in terms of effective permits required. Per client’s request, however, Knight Piésold is offering a best estimate of the costs based on the current knowledge of the factors involved in this project. This estimate (in US$) may change vastly in either direction when the project implementation gets underway. FAA permitting: $3,000 Construction Permitting: $14,500 ACMP Permitting: $1,500 USFWS-ADF&G Consultation: $3,000 SHPO-OHA Consultation: $10,000 Land Uses Rights-of-Way: $1,800 Wetlands Surveying: $10,000 Estimated total cost: $43,800 Note that this estimate does not include preparation of an EA as part of the NEPA review process. Chignik Lake WRA Final Report, Rev 0 7-1 Section 7.0 - Conclusions and Recommendations 7.1 Wind Feasibility Study Conclusions The following conclusions of the present study can be drawn: x The wind at Chignik Lake varies across the area from class 4 to class 6. x Potential Site 1 is the most attractive site for a wind turbine in both terms of energy production and in terms of economics. x A high penetration level is the only economically viable option for wind power at Chignik Lake, which implies a relatively sophisticated primary and secondary load control system to be implemented in addition to heat storage solutions at the school. x Initial investments for a wind turbine installation at Chignik Lake range between US$1.2M and US$2M, or US$3.7M for multiple turbine installations. These cost estimates should be considered accurate to within plus or minus 25 percent. x The per-installed-kW cost ranges between US$6,000 and US$13,000 depending on the model and quantity of turbines. x For the lowest US$4.25/gal diesel price analyzed, no wind power system is economically competitive. x The COE can be lowered from 0.02 to 0.21 US$/kWh (diesel prices of US$5.50/gal through US$8.30/gal) with respect to the diesel-only system, depending on the turbine and final installation site. x At a diesel price of $5.50/gal, the Vestas A27 is the most suitable option for Chignik Lake. Installing an A27 at site 1 would save $203,723 over the life of the project, or $13,567 per year. x At a diesel price of $6.92/gal, the Enercon E33 is the most suitable option for Chignik Lake. Installing an E33 at site 1 would save $770,578 over the life of the project, or $51,317 per year. x At a diesel price of $8.30/gal, the Enercon E33 is again the most suitable option for Chignik Lake. Installing an E33 at site 1 would save $1,337,445 over the life of the project, or $89,068 per year. x Both Vestas A27 and the Enercon E33 turbines are valid alternatives at diesel prices of $5.50, $6.92, and $8.30 per gallon. The A27 installed at 37 m hub-height achieves a decrease in COE of 0.03, 0.11, and 0.19 US$//kWh respectively for diesel prices of $5.50, $6.92, and $8.30 per gallon. The E33 installed at 37 m hub-height achieves a decrease in COE of 0.03, 0.12, and 0.22 US$//kWh respectively for diesel prices of $5.50, $6.92, and $8.30 per gallon. x The Vergnet GEV MP-C is also a proven technology which could fit well at Chignik Lake. The standard Vergnet tower is a guyed tower which can be lowered for maintenance and for protection in case of strong wind events. Icing and harsh meteorological conditions in Alaska may constitute a challenge to the operations of a tiltable tower, though that presents an advantage in terms of construction, since it does not require heavy cranes. Vergnet does not have a currently available cold weather package, and that would prevent deployment at Chignik Lake. A cold weather package is being developed by the manufacturer. x While the NW 100B/21 does not achieve feasibility status in the economic model (except in the 37-m hub-height two-turbine configuration and diesel price equal or greater than US$6.92/gal), it should be emphasized that the manufacturer and support is in the US, and that several installations in Alaska have proven very reliable so far (less than a decade). x All the configurations become economically viable if the project is awarded 80 percent of the capital cost as an externally provided grant. x All the configurations generate some amount of excess electricity, even after heat recovery at the school. If this excess energy could be used to heat other buildings, or in any number of other fashions, the cost of electricity would decrease even further. Chignik Lake WRA Final Report, Rev 0 7-2 7.2 Other Relevant Remarks x The choice of turbine model should account for accessibility to spare parts. It is reasonable to assume that the NW100B/21 has some advantage there, though difficult to quantify. Due to the remoteness of Chignik Lake, an inventory of spare parts should be acquired at the time of project commissioning for any given model. x The possibility of a catastrophic failure needs to be evaluated with the turbine manufacturers. The harsh wind regime is such that a damaging wind gust may be encountered with a probability of 30 percent throughout the lifetime of the project. The turbine manufacturer will need to provide a risk assessment based on the predicted extreme wind conditions and an evaluation of potential damage and related costs to be expected. x For any of the alternatives, costs for a wind power project will be high due to the physical setting. Material transport and construction costs will be high, since the contractors capable of performing the work are located in Anchorage. x Construction materials and equipment for all alternatives will need to be shipped to Chignik Lake via sea. x The small size of the job will not favor a reduction of construction costs under bidding, because only a limited number of contractors are likely to submit bids. x If multiple wind turbines are to be installed in the region, for example at Port Heiden as well as Chignik Lake, further exploration into cost savings may be beneficial. Combining shipment, mobilization, and construction of multiple projects in the area could result in significant cost savings for any individual project. x While permitting is not seen as a major obstacles, the number of local, state, and federal agencies that need to be involved is large, and if the project is selected, permitting procedures will need to be established early on. 7.3 Recommendations for Future Activities If LPB decides to continue with the implementation of the wind power project at this site, recommendations include: x Investigate whether suitable financing is available to develop a wind power project at Chignik Lake with the economics as illustrated in this report. In case of positive outcome of the previous point: x Initiate contacts with Enercon and other vendors. x Identify a project manager and a firm to oversee the engineering. x Initiate geotechnical investigations to assess the requirements for a sound foundation. x Identify other potential construction projects at Chignik Lake and surrounding towns for sharing of costs associated with construction activities, transportation, and logistics. x Initiate permitting procedures. Chignik Lake WRA Final Report, Rev 0 8-1 Section 8.0 - References [1] ASCE Standard ASCE/SEI 7-05, Minimum Design Loads for Buildings and Other Structures, ASCE 2005. [2] Detterman, R.L., T.P. Miller, M.E. Yount, and F.H. Wilson, 1981, Geologic Map of the Chignik and Sutwik Island Quadrangles, Alaska, Miscellaneous Investigations Series Map I-1229, U.S. Geological Survey, Fairbanks Alaska. [3] Information Insights, 2008: The Lake and Peninsula Borough Regional Energy Plan, Fairbanks, Alaska. [4] Knight Piésold report, Lake and Peninsula Borough Chignik Lake Wind Resource Assessment Met- Tower Installation Report, dated November 16, 2009. [5] Report A5-0264/2001 of the European Parliament (English), available at European Parliament website. [6] U.S. Department of Energy, 2005, HOMER Version 2.1, Micropower Optimization Software Model, National Renewable Energy Laboratory, Golden, Colorado. www.knightpiesold.com Appendix A Wind Data Report from “The Chignik Lake Met-Tower” DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 1 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Main results Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) Mast position: UTM WGS 84 Zone: 4 East: 516,816 North: 6,234,342 Measurement heights and wind speeds (in this report) Disabled data not included in overview table below ID Height Data recovery Records U_max U_mean *) [m] [%] [m/s] [m/s] 28.0m - A1A2 28.0 100.0 71979 27.3 6.7 *) U_mean is simple arithmetic average Scale: 50,000 No profiles when only one height is selected. A-1 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 2 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Main results Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) Statistics Signal Unit Count Of Mean Weibull Weibull Weibull period mean A k [%] 28.0m - A1A2 WS, all m/s 71979 100.0 6.72 6.81 7.61 1.65 28.0m - A1A2 WD, all Degrees 72006 100.0 256.73 A-2 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 3 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Missing data - calendar view Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) Height:28.0m - A1A2 - some records missing, disabled, erroneous, or out of range current day Signal:WS - all records missing, disabled, erroneous, or out of range current day Day Month/Year%Total12345678910111213141516171819202122232425262728293031 Nov/2009 0.0 0 000000000000000000000000000000 Dec/2009 0.0 0 0000000000000000000000000000000 Jan/2010 0.0 1 0000000000000001 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Feb/2010 0.0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 Mar/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Apr/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 May/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Jun/2010 0.2 9 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 7 1 0 0 0 0 0 0 0 0 0 Jul/2010 0.0 1 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 Aug/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Sep/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Oct/2010 0.0 2 0 0 0 0 0 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 0 0 0 1 0 0 0 0 0 0 Nov/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Dec/2010 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Jan/2011 0.3 13 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 13 0 0 0 0 0 0 Feb/2011 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Mar/2011 0.0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 Total 0.0 27 Signal:WD Day Month/Year%Total12345678910111213141516171819202122232425262728293031 Nov/2009 0.0 0 000000000000000000000000000000 Dec/2009 0.0 0 0000000000000000000000000000000 Jan/2010 0.0 0 0000000000000000000000000000000 Feb/2010 0.0 0 0000000000000000000000000000 Mar/2010 0.0 0 0000000000000000000000000000000 Apr/2010 0.0 0 000000000000000000000000000000 May/2010 0.0 0 0000000000000000000000000000000 Jun/2010 0.0 0 000000000000000000000000000000 Jul/2010 0.0 0 0000000000000000000000000000000 Aug/2010 0.0 0 0000000000000000000000000000000 Sep/2010 0.0 0 000000000000000000000000000000 Oct/2010 0.0 0 0000000000000000000000000000000 Nov/2010 0.0 0 000000000000000000000000000000 Dec/2010 0.0 0 0000000000000000000000000000000 Jan/2011 0.0 0 0000000000000000000000000000000 Feb/2011 0.0 0 0000000000000000000000000000 Mar/2011 0.0 0 0000000000000000 Total 0.0 0 A-3 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 4 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-4 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 5 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-5 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 6 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-6 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 7 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-7 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 8 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-8 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 9 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-9 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 10 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-10 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 11 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-11 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 12 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Time series graphs Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) A-12 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 13 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Monthly wind speeds Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) Monthly wind speeds 28.0m - A1A2 Month 2009 2010 2011 Mean Mean of month January 8.03 5.80 6.92 6.92 February 6.79 8.68 7.74 7.74 March 8.23 5.82 7.43 7.03 April 6.12 6.12 6.12 May 6.44 6.44 6.44 June 5.62 5.62 5.62 July 4.28 4.28 4.28 August 5.46 5.46 5.46 September 5.11 5.11 5.11 October 5.35 5.35 5.35 November 8.11 6.54 7.32 7.32 December 8.16 9.45 8.81 8.81 mean, all data 8.13 6.46 6.89 mean of months 8.14 6.45 6.77 6.35 A-13 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 14 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Frequency distribution (TAB file data) Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) Frequency distribution (TAB file data) 28.0m - A1A2 Bin Start End Sum 0-N 1-NNE 2-ENE 3-E 4-ESE 5-SSE 6-S 7-SSW 8-WSW 9-W 10-WNW 11-NNW Mean 6.72 2.47 3.03 5.36 5.39 5.30 4.03 3.59 5.93 6.06 8.34 10.52 4.59 0 0.49 1650 60 95 181 246 163 108 95 121 180 176 118 107 1 0.50 1.49 4576 215 232 502 962 613 195 182 255 442 469 301 208 2 1.50 2.49 5247 135 235 661 1490 623 136 142 185 644 650 202 144 3 2.50 3.49 6427 88 170 899 1667 573 134 177 317 1236 881 177 108 4 3.50 4.49 7570 53 110 1249 1738 447 113 182 413 1925 1018 217 105 5 4.50 5.49 6983 47 56 1284 1397 290 92 133 432 1889 1006 267 90 6 5.50 6.49 6204 23 24 1000 1017 248 84 80 431 1555 1309 365 68 7 6.50 7.49 6036 10 23 749 830 221 68 39 451 1499 1474 606 66 8 7.50 8.49 5556 4 19 489 476 234 44 19 376 1336 1742 783 34 9 8.50 9.49 4644 5 10 366 355 202 28 17 233 1115 1514 760 39 10 9.50 10.49 3714 2 2 254 248 155 13 7 175 798 1261 764 35 11 10.50 11.49 3085 3 8 216 226 125 10 9 153 439 1131 734 31 12 11.50 12.49 2441 6 15 120 234 102 5 7 97 289 893 648 25 13 12.50 13.49 1993 0 12 100 181 85 4 11 49 161 719 652 19 14 13.50 14.49 1525 1 8 66 129 72 7 7 23 60 613 528 11 15 14.50 15.49 1258 0 5 43 134 59 12 3 12 18 535 422 15 16 15.50 16.49 1041 0 0 28 129 42 2 0 3 21 397 407 12 17 16.50 17.49 769 0 0 16 97 33 5 0 9 9 228 363 9 18 17.50 18.49 478 0 0 4 59 17 5 1 6 4 153 226 3 19 18.50 19.49 315 0 0 1 58 19 7 0 1 1 72 156 0 20 19.50 20.49 190 0 0 0 32 12 0 0 0 1 30 114 1 21 20.50 21.49 103 0 0 0 23 5 0 0 0 0 7 68 0 22 21.50 22.49 71 0 0 0 16 4 0 0 0 0 4 47 0 23 22.50 23.49 54 0 0 0 17 2 0 0 0 0 3 32 0 24 23.50 24.49 23 0 0 0 8 3 0 0 0 0 0 12 0 25 24.50 25.49 17 0 0 0 1 0 0 0 0 0 0 16 0 26 25.50 26.49 7 0 0 0 0 0 0 0 0 0 0 7 0 27 26.50 27.49 2 0 0 0 0 0 0 0 0 0 0 2 0 28 27.50 28.49 0 0 0 0 0 0 0 0 0 0 0 0 0 29 28.50 29.49 0 0 0 0 0 0 0 0 0 0 0 0 0 30 29.50 30.49 0 0 0 0 0 0 0 0 0 0 0 0 0 31 30.50 31.49 0 0 0 0 0 0 0 0 0 0 0 0 0 32 31.50 32.49 0 0 0 0 0 0 0 0 0 0 0 0 0 33 32.50 33.49 0 0 0 0 0 0 0 0 0 0 0 0 0 34 33.50 34.49 0 0 0 0 0 0 0 0 0 0 0 0 0 35 34.50 35.49 0 0 0 0 0 0 0 0 0 0 0 0 0 36 35.50 36.49 0 0 0 0 0 0 0 0 0 0 0 0 0 37 36.50 37.49 0 0 0 0 0 0 0 0 0 0 0 0 0 38 37.50 38.49 0 0 0 0 0 0 0 0 0 0 0 0 0 39 38.50 39.49 0 0 0 0 0 0 0 0 0 0 0 0 0 40 39.50 40.49 0 0 0 0 0 0 0 0 0 0 0 0 0 41 40.50 0 0 0 0 0 0 0 0 0 0 0 0 0 A-14 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 11:46 AM / 15 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 11:45 AM Meteo data report - Weibull data overview Mast:Merged A1 and A2 data; A1A2_MergedPeriod:Full period: 11/1/2009 - 3/16/2011 (16.4 months) Height:28.0m - A1A2 Weibull data Sector A k f Mean wind speed [m/s] [m/s] 0-N 2.82 1.221 0.91 2.64 1-NNE 3.30 1.109 1.42 3.18 2-ENE 6.05 1.780 11.43 5.38 3-E 5.70 1.271 16.35 5.29 4-ESE 5.79 1.280 6.04 5.37 5-SSE 4.67 1.255 1.49 4.34 6-S 4.32 1.505 1.54 3.90 7-SSW 6.96 2.154 5.20 6.16 8-WSW 6.91 2.237 18.92 6.12 9-W 9.58 2.273 22.62 8.48 10-WNW 12.06 2.513 12.50 10.70 11-NNW 5.17 1.249 1.57 4.82 Mean 7.61 1.650 100.00 6.81 A-15 www.knightpiesold.com Appendix B Measure Correlate Predict: Correlation Between Tower Data and PAJC AWOS Station DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 12:00 PM / 1 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 12:00 PM/2.7.486 MCP - Measure data - overview Calculation:MCP CL_TOWER to AWOS Meteo data objects 1: Local measurements (site data): Merged A1 and A2 data.28.0m - A1A2 First date: 11/1/2009 Last date: 3/16/2011 Time step: 10 min Data points: 72006 Enabled:100.0 % Mean wind speed: 6.81 m/s Time Series Data: Yes 2: Long term reference: Chignik Airport.10.0m - First date: 2/25/1998 Last date: 3/6/2011 Time step: 20 min Data points: 216940 Enabled:100.0 % Mean wind speed: 5.41 m/s Time Series Data: Yes Filter values Filter for site data Averaging time: 60 min B-1 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 12:00 PM / 2 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 12:00 PM/2.7.486 MCP - Calculation:MCP CL_TOWER to AWOS 1: Local measurements (site data)Merged A1 and A2 data Height 28.00 m Period 11/1/2009 to 3/16/2011 1.4 years Mean wind speed 6.77 m/s Filters used (Averaging) 2: Long term reference Chignik Airport Height 10.00 m Period 2/25/1998 to 3/6/2011 13.0 years Mean wind speed 5.41 m/s Filters used Not Filtered Calculation setup Method Find transfer function for each sector Number of sectors 16 Skip angle differences larger than 360.00 Skip wind speeds less than 2.00 Regression model (wind speed)Linear (1st order polynomial) Regression model (wind direction)Constant (0th order polynomial) Wind speed model - use residual resampling Yes Wind direction model - use residual resampling Yes Results Measure height a.g.l.28.0 m Mean wind in measure height 6.98 m/s r - wind speed 0.7088 s - wind speed 2.1831 m/s r - wind index 0.8560 s - wind index 13.9450 % Time of calculation 5/5/2011 11:52 AM B-2 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 12:00 PM / 3 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 12:00 PM/2.7.486 MCP - Regression MCP report (basic/overview) Calculation:MCP CL_TOWER to AWOS MCP method used: Regression MCP Long term reference data: Chignik Airport Height: 10.00 Concurrent site data: Merged A1 and A2 data Height: 28.00 B-3 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 12:00 PM / 4 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 12:00 PM/2.7.486 MCP - Regression MCP report - details on wind speed fit Calculation:MCP CL_TOWER to AWOS B-4 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 12:00 PM / 5 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 5/5/2011 12:00 PM/2.7.486 MCP - Regression MCP report - details on wind veer fit Calculation:MCP CL_TOWER to AWOS B-5 www.knightpiesold.com Appendix C Annual Energy Calculations, 37-m Hub-Heights (approximately 120 ft AGL) Table of Contents Turbine Manufacturer Height Page Number Enercon 37 m C-1 Northwind 37 m C-9 Vergnet 37 m C-17 Vestas 37 m C-25 DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 1 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Main Result Calculation:AEP - from WRA - Enercon 330 Wake Model No model Calculation Settings Air density calculation mode Individual per WTG Result for WTG at hub altitude 1.251 kg/m³ to 1.256 kg/m³ Air density relative to standard 102.1 % Hub altitude above sea level (asl) 69.2 m to 106.0 m Annual mean temperature at hub alt. 4.0 °C to 4.2 °C Pressure at WTGs 995.4 hPa to 999.9 hPa Relative humidity 0.6 % Wake Model Parameters No model parameters Wake calculation settings Angle [°] Wind speed [m/s] start end step start end step 0.5 360.0 1.0 0.5 30.5 1.0 Scale 1:50,000 New WTG Resource file(s) C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Calculated Annual Energy for Wind Farm Specific results¤) WTG combination Result Result-10.0% GROSS (no loss) Park Capacity Mean WTG Full load Mean wind speed PARK Free WTGs efficiency factor result hours @hub height [MWh/y] [MWh] [MWh/y] [%] [%] [MWh/y] [Hours/year] [m/s] Wind farm 5,378.4 4,840.5 5,378.4 100.0 41.8 1,210.1 3,667 8.0 ¤) Based on Result-10.0% Calculated Annual Energy for each of 4 new WTGs with total 1.3 MW rated power WTG type Power curve Annual Energy Park Terrain Valid Manufact. Type-generator Power, Rotor Hub Creator Name Result Result-10.0% Efficiency Mean rated diameter height wind speed [kW] [m] [m] [MWh] [MWh] [%] [m/s] 1 A Yes ENERCON E-33 MODIFIED-330 330 33.4 37.0 USER Level 0 - guaranteed* - - 02/2004 1,344.0 1,210 100.0 7.96 2 A Yes ENERCON E-33 MODIFIED-330 330 33.4 37.0 USER Level 0 - guaranteed* - - 02/2004 1,379.8 1,242 100.0 8.08 3 A Yes ENERCON E-33 MODIFIED-330 330 33.4 37.0 USER Level 0 - guaranteed* - - 02/2004 1,295.3 1,166 100.0 7.78 4 A Yes ENERCON E-33 MODIFIED-330 330 33.4 37.0 USER Level 0 - guaranteed* - - 02/2004 1,359.2 1,223 100.0 8.03 WTG siting UTM WGS84 Zone: 4 East North Z Row data/Description UTM WGS84 Zone: 4 [m] 1 New 513,897 6,234,263 39.5 Potential Location 1 2 New 512,766 6,234,395 32.2 Potential Location 2 3 New 516,138 6,234,010 59.1 Potential Location 3 4 New 514,327 6,233,422 69.0 Potential Location 4 C-1 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 2 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Production Analysis Calculation:AEP - from WRA - Enercon 330 WTG:All new WTGs, Air density varies with WTG position 1.251 kg/m³ - 1.256 kg/m³ Directional Analysis Sector 0 N 1 NNE 2 NE 3 ENE 4 E 5 ESE 6 SE 7 SSE 8 S 9 SSW 10 SW 11 WSW 12 W 13 WNW 14 NW 15 NNW Total Roughness based energy [MWh] 36.9 53.6 207.3 273.2 222.1 274.4 201.4 98.0 109.9 113.5 281.4 971.1 1,773.9 592.9 117.6 51.2 5,378.4 Resulting energy [MWh] 36.9 53.6 207.3 273.2 222.1 274.4 201.4 98.0 109.9 113.5 281.4 971.1 1,773.9 592.9 117.6 51.2 5,378.4 Specific energy [kWh/m²]1,535 Specific energy [kWh/kW]4,075 Utilization [%] 47.4 47.6 38.9 40.1 40.5 39.2 37.2 33.2 40.1 38.9 34.2 29.5 31.9 32.2 31.8 39.8 33.4 Operational [Hours/year] 150 207 499 682 603 632 457 278 257 181 340 1,105 2,023 716 197 170 8,496 Full Load Equivalent [Hours/year] 28 41 157 207 168 208 153 74 83 86 213 736 1,344 449 89 39 4,075 C-2 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 3 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Power Curve Analysis Calculation:AEP - from WRA - Enercon 330 WTG:1 - ENERCON E-33 MODIFIED 330 33.4 !-! Level 0 - guaranteed* - - 02/2004, Hub height: 37.0 m Name:Level 0 - guaranteed* - - 02/2004 Source:Enercon Source/Date Created by Created Edited Stop wind speed Power control CT curve type [m/s] 4/30/2004 USER 6/23/2006 7/7/2010 25.0 Pitch User defined According to Enercon specification ct_E-33_330kW berechnet * Uncertainties in measurement of power curves can lead to different power curves for the same turbine, so ENERCON uses calculated curves for energy calculations and guarantees. For reference and verification, measured power curves are available at ENERCON (not for use in energy calculations or guarantees!) HP curve comparison - Note: For standard air density and weibull k parameter = 2 Vmean [m/s] 5 6 7 8 9 10 HP value [MWh] 406 661 925 1,181 1,397 1,588 ENERCON E-33 MODIFIED 330 33.4 !-! Level 0 - guaranteed* - - 02/2004 [MWh] 498 770 1,042 1,291 1,507 1,684 Check value [%] -18 -14 -11 -9 -7 -6 The table shows comparison between annual energy production calculated on basis of simplified "HP-curves" which assume that all WTGs performs quite similar - only specific power loading (kW/m^2) and single/dual speed or stall/pitch decides the calculated values. Productions are without wake losses. For further details, ask at the Danish Energy Agency for project report J.nr. 51171/00-0016 or see WindPRO manual chapter 3.5.2. The method is refined in EMD report "20 Detailed Case Studies comparing Project Design Calculations and actual Energy Productions for Wind Energy Projects worldwide", jan 2003. Use the table to evaluate if the given power curve is reasonable - if the check value are lower than -5%, the power curve probably is too optimistic due to uncertainty in power curve measurement. Power curve Original data from Windcat, Air density: 1.225 kg/m³ Wind speed Power Ce Wind speed Ct curve [m/s] [kW] [m/s] 1.0 0.0 0.00 1.0 0.00 2.0 0.0 0.00 2.0 0.75 3.0 5.0 0.35 3.0 0.76 4.0 13.7 0.40 4.0 0.76 5.0 30.0 0.45 5.0 0.76 6.0 55.0 0.47 6.0 0.75 7.0 92.0 0.50 7.0 0.76 8.0 138.0 0.50 8.0 0.76 9.0 196.0 0.50 9.0 0.75 10.0 250.0 0.47 10.0 0.73 11.0 292.8 0.41 11.0 0.71 12.0 320.0 0.35 12.0 0.68 13.0 335.0 0.28 13.0 0.47 14.0 335.0 0.23 14.0 0.36 15.0 335.0 0.18 15.0 0.28 16.0 335.0 0.15 16.0 0.24 17.0 335.0 0.13 17.0 0.20 18.0 335.0 0.11 18.0 0.16 19.0 335.0 0.09 19.0 0.14 20.0 335.0 0.08 20.0 0.12 21.0 335.0 0.07 21.0 0.10 22.0 335.0 0.06 22.0 0.09 23.0 335.0 0.05 23.0 0.08 24.0 335.0 0.05 24.0 0.07 25.0 335.0 0.04 25.0 0.06 Power, Efficiency and energy vs. wind speed Data used in calculation, Air density: 1.255 kg/m³ New WindPRO method (adjusted IEC method, improved to match turbine control) <RECOMMENDED> Wind speed Power Ce Interval Energy Acc.Energy Relative [m/s] [kW] [m/s] [MWh] [MWh] [%] 1.0 0.0 0.00 0.50- 1.50 0.0 0.0 0.0 2.0 0.1 0.02 1.50- 2.50 0.5 0.5 0.0 3.0 5.2 0.35 2.50- 3.50 3.4 3.9 0.3 4.0 14.2 0.40 3.50- 4.50 10.9 14.9 1.1 5.0 31.0 0.45 4.50- 5.50 25.9 40.7 3.0 6.0 56.7 0.48 5.50- 6.50 50.2 90.9 6.8 7.0 94.5 0.50 6.50- 7.50 83.2 174.2 13.0 8.0 141.7 0.50 7.50- 8.50 122.1 296.2 22.0 9.0 200.1 0.50 8.50- 9.50 159.3 455.5 33.9 10.0 254.1 0.46 9.50-10.50 182.7 638.2 47.5 11.0 296.1 0.40 10.50-11.50 184.0 822.2 61.2 12.0 322.2 0.34 11.50-12.50 164.1 986.2 73.4 13.0 335.0 0.28 12.50-13.50 130.4 1,116.6 83.1 14.0 335.0 0.22 13.50-14.50 93.1 1,209.8 90.0 15.0 335.0 0.18 14.50-15.50 60.8 1,270.5 94.5 16.0 335.0 0.15 15.50-16.50 36.3 1,306.9 97.2 17.0 335.0 0.12 16.50-17.50 19.8 1,326.7 98.7 18.0 335.0 0.10 17.50-18.50 9.9 1,336.6 99.4 19.0 335.0 0.09 18.50-19.50 4.5 1,341.0 99.8 20.0 335.0 0.08 19.50-20.50 1.9 1,342.9 99.9 21.0 335.0 0.07 20.50-21.50 0.7 1,343.6 100.0 22.0 335.0 0.06 21.50-22.50 0.3 1,343.9 100.0 23.0 335.0 0.05 22.50-23.50 0.1 1,344.0 100.0 24.0 335.0 0.04 23.50-24.50 0.0 1,344.0 100.0 25.0 335.0 0.04 24.50-25.50 0.0 1,344.0 100.0 C-3 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 4 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Enercon 330 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 513,897 North: 6,234,263 Potential Location 1 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.70 5.08 2.866 1.7 1 NNE 5.74 5.11 2.830 2.3 2 NE 6.84 6.06 2.110 5.5 3 ENE 7.00 6.20 2.140 8.0 4 E 6.80 6.02 2.054 7.2 5 ESE 7.40 6.55 2.180 7.9 6 SE 7.40 6.56 2.064 5.6 7 SSE 6.00 5.39 1.570 3.2 8 S 6.90 6.12 2.426 3.0 9 SSW 8.60 7.69 3.100 2.0 10 SW 10.34 9.31 3.560 3.5 11 WSW 11.10 9.93 3.100 12.0 12 W 11.00 9.88 3.370 24.9 13 WNW 10.60 9.49 3.170 8.9 14 NW 8.80 7.79 2.210 2.3 15 NNW 5.80 5.15 1.870 2.0 All 8.99 7.96 2.297 100.0 C-4 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 5 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Enercon 330 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 512,766 North: 6,234,395 Potential Location 2 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.52 5.82 2.951 1.9 1 NNE 6.23 5.54 2.743 2.6 2 NE 6.90 6.11 2.110 5.6 3 ENE 6.92 6.12 2.140 7.1 4 E 6.50 5.76 2.040 6.3 5 ESE 7.50 6.64 2.190 8.0 6 SE 7.90 7.00 2.080 6.2 7 SSE 7.30 6.53 1.633 3.8 8 S 8.43 7.47 2.456 3.3 9 SSW 10.02 9.00 3.359 1.9 10 SW 10.52 9.47 3.535 3.7 11 WSW 10.69 9.56 3.080 10.4 12 W 10.79 9.69 3.380 24.3 13 WNW 11.00 9.86 3.240 9.8 14 NW 10.03 8.89 2.376 2.8 15 NNW 6.83 6.06 1.858 2.3 All 9.12 8.08 2.362 100.0 C-5 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 6 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Enercon 330 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 516,138 North: 6,234,010 Potential Location 3 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.10 4.54 2.812 1.5 1 NNE 5.51 4.91 2.841 2.1 2 NE 7.10 6.29 2.111 5.2 3 ENE 7.26 6.43 2.144 9.0 4 E 7.10 6.29 2.080 8.3 5 ESE 7.41 6.56 2.160 7.4 6 SE 7.04 6.24 2.030 4.9 7 SSE 5.80 5.20 1.600 2.8 8 S 6.63 5.88 2.361 2.6 9 SSW 7.80 6.95 2.854 2.0 10 SW 9.40 8.45 3.430 3.5 11 WSW 10.59 9.47 3.099 13.8 12 W 10.60 9.51 3.340 25.7 13 WNW 10.40 9.29 3.024 7.4 14 NW 7.60 6.73 2.063 2.1 15 NNW 5.00 4.44 1.860 1.7 All 8.78 7.78 2.321 100.0 C-6 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 7 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Enercon 330 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 514,327 North: 6,233,422 Potential Location 4 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.40 5.68 2.480 1.9 1 NNE 6.80 6.06 2.840 2.7 2 NE 7.75 6.87 2.120 7.2 3 ENE 7.05 6.25 2.100 8.1 4 E 6.60 5.85 2.080 6.6 5 ESE 7.10 6.29 2.190 6.5 6 SE 7.10 6.29 2.080 4.8 7 SSE 6.25 5.58 1.685 3.3 8 S 7.20 6.38 2.100 3.2 9 SSW 9.10 8.11 2.890 2.6 10 SW 10.90 9.78 3.304 5.3 11 WSW 11.50 10.29 3.150 15.9 12 W 10.90 9.78 3.340 20.3 13 WNW 9.80 8.77 3.170 7.6 14 NW 8.31 7.36 2.301 2.1 15 NNW 6.40 5.68 1.880 2.0 All 9.07 8.03 2.311 100.0 C-7 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 8 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:33 PM/2.7.486 PARK - WTG distances Calculation:AEP - from WRA - Enercon 330 Scale 1:50,000 New WTG WTG distances Z Nearest WTG Z Horizontal distance Distance in rotor diameters [m] [m] [m] 1 39.5 4 69.0 944 28.3 2 32.2 1 39.5 1,138 34.1 3 59.1 4 69.0 1,905 57.0 4 69.0 1 39.5 944 28.3 C-8 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 1 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Main Result Calculation:AEP - from WRA - Northwind 100 Wake Model No model Calculation Settings Air density calculation mode Individual per WTG Result for WTG at hub altitude 1.251 kg/m³ to 1.256 kg/m³ Air density relative to standard 102.1 % Hub altitude above sea level (asl) 69.2 m to 106.0 m Annual mean temperature at hub alt. 4.0 °C to 4.2 °C Pressure at WTGs 995.4 hPa to 999.9 hPa Relative humidity 0.6 % Wake Model Parameters No model parameters Wake calculation settings Angle [°] Wind speed [m/s] start end step start end step 0.5 360.0 1.0 0.5 30.5 1.0 Scale 1:50,000 New WTG Resource file(s) C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Calculated Annual Energy for Wind Farm Specific results¤) WTG combination Result Result-10.0% GROSS (no loss) Park Capacity Mean WTG Full load Mean wind speed PARK Free WTGs efficiency factor result hours @hub height [MWh/y] [MWh] [MWh/y] [%] [%] [MWh/y] [Hours/year] [m/s] Wind farm 1,540.3 1,386.3 1,540.3 100.0 39.5 346.6 3,466 8.0 ¤) Based on Result-10.0% Calculated Annual Energy for each of 4 new WTGs with total 0.4 MW rated power WTG type Power curve Annual Energy Park Terrain Valid Manufact. Type-generator Power, Rotor Hub height Creator Name Result Result-10.0% Efficiency Mean wind rated diameter speed [kW] [m] [m] [MWh] [MWh] [%] [m/s] 1 A No NORTHWIND 100 Arctic-100 100 21.0 37.0 USER Arctic 100 385.2 347 100.0 7.96 2 A No NORTHWIND 100 Arctic-100 100 21.0 37.0 USER Arctic 100 395.2 356 100.0 8.08 3 A No NORTHWIND 100 Arctic-100 100 21.0 37.0 USER Arctic 100 370.7 334 100.0 7.78 4 A No NORTHWIND 100 Arctic-100 100 21.0 37.0 USER Arctic 100 389.2 350 100.0 8.03 WTG siting UTM WGS84 Zone: 4 East North Z Row data/Description UTM WGS84 Zone: 4 [m] 1 New 513,897 6,234,263 39.5 Potential Location 1 2 New 512,766 6,234,395 32.2 Potential Location 2 3 New 516,138 6,234,010 59.1 Potential Location 3 4 New 514,327 6,233,422 69.0 Potential Location 4 C-9 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 2 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Production Analysis Calculation:AEP - from WRA - Northwind 100WTG:All new WTGs, Air density varies with WTG position 1.251 kg/m³ - 1.256 kg/m³ Directional Analysis Sector 0 N 1 NNE 2 NE 3 ENE 4 E 5 ESE 6 SE 7 SSE 8 S 9 SSW 10 SW 11 WSW 12 W 13 WNW 14 NW 15 NNW Total Roughness based energy [MWh] 11.1 16.2 60.0 79.2 64.5 79.4 58.2 28.4 31.8 32.4 79.8 277.3 504.2 168.9 33.9 14.9 1,540.3 Resulting energy [MWh] 11.1 16.2 60.0 79.2 64.5 79.4 58.2 28.4 31.8 32.4 79.8 277.3 504.2 168.9 33.9 14.9 1,540.3 Specific energy [kWh/m²]1,112 Specific energy [kWh/kW]3,851 Utilization [%] 36.2 36.3 28.5 29.4 29.8 28.7 27.2 24.4 29.4 28.1 24.5 21.3 22.9 23.2 23.1 29.4 24.2 Operational [Hours/year] 143 197 476 651 574 603 436 265 245 173 324 1,053 1,928 683 188 162 8,100 Full Load Equivalent [Hours/year] 28 40 150 198 161 198 146 71 80 81 200 693 1,261 422 85 37 3,851 C-10 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 3 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Power Curve Analysis Calculation:AEP - from WRA - Northwind 100WTG:1 - NORTHWIND 100 Arctic 60Hz 100 21.0 !O! Arctic 100, Hub height: 37.0 m Name:Arctic 100 Source:SpecSheet Source/Date Created by Created Edited Stop wind speed Power control CT curve type [m/s] 10/12/2009 USER 10/12/2009 10/12/2009 25.0 Stall Standard stall HP curve comparison - Note: For standard air density and weibull k parameter = 2 Vmean [m/s] 5678910 HP value [MWh] 146 222 306 379 427 493 NORTHWIND 100 Arctic 60Hz 100 21.0 !O! Arctic 100 [MWh] 147 222 298 369 431 482 Check value [%] 0 0 2 3 -1 2 The table shows comparison between annual energy production calculated on basis of simplified "HP-curves" which assume that all WTGs performs quite similar - only specific power loading (kW/m^2) and single/dual speed or stall/pitch decides the calculated values. Productions are without wake losses. For further details, ask at the Danish Energy Agency for project report J.nr. 51171/00-0016 or see WindPRO manual chapter 3.5.2. The method is refined in EMD report "20 Detailed Case Studies comparing Project Design Calculations and actual Energy Productions for Wind Energy Projects worldwide", jan 2003. Use the table to evaluate if the given power curve is reasonable - if the check value are lower than -5%, the power curve probably is too optimistic due to uncertainty in power curve measurement. Power curve Original data from Windcat, Air density: 1.225 kg/m³ Wind speed Power Ce Wind speed Ct curve [m/s] [kW] [m/s] 1.0 0.0 0.00 1.0 0.10 2.0 0.0 0.00 2.0 0.10 3.0 0.0 0.00 3.0 0.10 4.0 3.7 0.27 4.0 0.80 5.0 10.5 0.40 5.0 0.82 6.0 19.0 0.41 6.0 0.85 7.0 29.4 0.40 7.0 0.82 8.0 41.0 0.38 8.0 0.78 9.0 54.3 0.35 9.0 0.74 10.0 66.8 0.31 10.0 0.68 11.0 77.7 0.28 11.0 0.62 12.0 86.4 0.24 12.0 0.55 13.0 92.8 0.20 13.0 0.49 14.0 97.3 0.17 14.0 0.43 15.0 100.0 0.14 15.0 0.38 16.0 100.8 0.12 16.0 0.32 17.0 100.6 0.10 17.0 0.28 18.0 99.8 0.08 18.0 0.25 19.0 99.4 0.07 19.0 0.21 20.0 98.6 0.06 20.0 0.20 21.0 97.8 0.05 21.0 0.19 22.0 97.3 0.04 22.0 0.17 23.0 97.3 0.04 23.0 0.16 24.0 98.0 0.03 24.0 0.15 25.0 99.7 0.03 25.0 0.14 26.0 0.13 27.0 0.12 28.0 0.11 29.0 0.10 Power, Efficiency and energy vs. wind speed Data used in calculation, Air density: 1.255 kg/m³ New WindPRO method (adjusted IEC method, improved to match turbine control) <RECOMMENDED> Wind speed Power Ce Interval Energy Acc.Energy Relative [m/s] [kW] [m/s] [MWh] [MWh] [%] 1.0 0.0 0.00 0.50- 1.50 0.0 0.0 0.0 2.0 0.0 0.00 1.50- 2.50 0.0 0.0 0.0 3.0 0.0 0.00 2.50- 3.50 0.6 0.6 0.1 4.0 3.8 0.27 3.50- 4.50 3.2 3.7 1.0 5.0 10.8 0.40 4.50- 5.50 8.8 12.5 3.3 6.0 19.5 0.41 5.50- 6.50 16.8 29.4 7.6 7.0 30.1 0.40 6.50- 7.50 26.2 55.6 14.4 8.0 42.0 0.38 7.50- 8.50 35.9 91.5 23.8 9.0 55.6 0.35 8.50- 9.50 44.3 135.8 35.3 10.0 68.4 0.31 9.50-10.50 49.4 185.2 48.1 11.0 79.6 0.28 10.50-11.50 49.6 234.8 60.9 12.0 88.5 0.24 11.50-12.50 45.0 279.8 72.6 13.0 95.1 0.20 12.50-13.50 37.0 316.8 82.2 14.0 99.7 0.17 13.50-14.50 27.5 344.2 89.4 15.0 102.4 0.14 14.50-15.50 18.5 362.7 94.2 16.0 103.3 0.12 15.50-16.50 11.2 373.9 97.1 17.0 103.0 0.10 16.50-17.50 6.1 380.0 98.6 18.0 102.2 0.08 17.50-18.50 3.0 383.0 99.4 19.0 101.8 0.07 18.50-19.50 1.4 384.3 99.8 20.0 101.0 0.06 19.50-20.50 0.6 384.9 99.9 21.0 100.2 0.05 20.50-21.50 0.2 385.1 100.0 22.0 99.7 0.04 21.50-22.50 0.1 385.2 100.0 23.0 99.7 0.04 22.50-23.50 0.0 385.2 100.0 24.0 100.4 0.03 23.50-24.50 0.0 385.2 100.0 25.0 102.1 0.03 24.50-25.50 0.0 385.2 100.0 C-11 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 4 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Northwind 100 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 513,897 North: 6,234,263 Potential Location 1 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.70 5.08 2.866 1.7 1 NNE 5.74 5.11 2.830 2.3 2 NE 6.84 6.06 2.110 5.5 3 ENE 7.00 6.20 2.140 8.0 4 E 6.80 6.02 2.054 7.2 5 ESE 7.40 6.55 2.180 7.9 6 SE 7.40 6.56 2.064 5.6 7 SSE 6.00 5.39 1.570 3.2 8 S 6.90 6.12 2.426 3.0 9 SSW 8.60 7.69 3.100 2.0 10 SW 10.34 9.31 3.560 3.5 11 WSW 11.10 9.93 3.100 12.0 12 W 11.00 9.88 3.370 24.9 13 WNW 10.60 9.49 3.170 8.9 14 NW 8.80 7.79 2.210 2.3 15 NNW 5.80 5.15 1.870 2.0 All 8.99 7.96 2.297 100.0 C-12 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 5 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Northwind 100 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 512,766 North: 6,234,395 Potential Location 2 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.52 5.82 2.951 1.9 1 NNE 6.23 5.54 2.743 2.6 2 NE 6.90 6.11 2.110 5.6 3 ENE 6.92 6.12 2.140 7.1 4 E 6.50 5.76 2.040 6.3 5 ESE 7.50 6.64 2.190 8.0 6 SE 7.90 7.00 2.080 6.2 7 SSE 7.30 6.53 1.633 3.8 8 S 8.43 7.47 2.456 3.3 9 SSW 10.02 9.00 3.359 1.9 10 SW 10.52 9.47 3.535 3.7 11 WSW 10.69 9.56 3.080 10.4 12 W 10.79 9.69 3.380 24.3 13 WNW 11.00 9.86 3.240 9.8 14 NW 10.03 8.89 2.376 2.8 15 NNW 6.83 6.06 1.858 2.3 All 9.12 8.08 2.362 100.0 C-13 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 6 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Northwind 100 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 516,138 North: 6,234,010 Potential Location 3 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.10 4.54 2.812 1.5 1 NNE 5.51 4.91 2.841 2.1 2 NE 7.10 6.29 2.111 5.2 3 ENE 7.26 6.43 2.144 9.0 4 E 7.10 6.29 2.080 8.3 5 ESE 7.41 6.56 2.160 7.4 6 SE 7.04 6.24 2.030 4.9 7 SSE 5.80 5.20 1.600 2.8 8 S 6.63 5.88 2.361 2.6 9 SSW 7.80 6.95 2.854 2.0 10 SW 9.40 8.45 3.430 3.5 11 WSW 10.59 9.47 3.099 13.8 12 W 10.60 9.51 3.340 25.7 13 WNW 10.40 9.29 3.024 7.4 14 NW 7.60 6.73 2.063 2.1 15 NNW 5.00 4.44 1.860 1.7 All 8.78 7.78 2.321 100.0 C-14 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 7 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Northwind 100 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 514,327 North: 6,233,422 Potential Location 4 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.40 5.68 2.480 1.9 1 NNE 6.80 6.06 2.840 2.7 2 NE 7.75 6.87 2.120 7.2 3 ENE 7.05 6.25 2.100 8.1 4 E 6.60 5.85 2.080 6.6 5 ESE 7.10 6.29 2.190 6.5 6 SE 7.10 6.29 2.080 4.8 7 SSE 6.25 5.58 1.685 3.3 8 S 7.20 6.38 2.100 3.2 9 SSW 9.10 8.11 2.890 2.6 10 SW 10.90 9.78 3.304 5.3 11 WSW 11.50 10.29 3.150 15.9 12 W 10.90 9.78 3.340 20.3 13 WNW 9.80 8.77 3.170 7.6 14 NW 8.31 7.36 2.301 2.1 15 NNW 6.40 5.68 1.880 2.0 All 9.07 8.03 2.311 100.0 C-15 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:13 PM / 8 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:30 PM/2.7.486 PARK - WTG distances Calculation:AEP - from WRA - Northwind 100 Scale 1:50,000 New WTG WTG distances Z Nearest WTG Z Horizontal distance Distance in rotor diameters [m] [m] [m] 1 39.5 4 69.0 944 45.0 2 32.2 1 39.5 1,138 54.2 3 59.1 4 69.0 1,905 90.7 4 69.0 1 39.5 944 45.0 C-16 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 1 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Main Result Calculation:AEP - from WRA - Vergnet 275 Wake Model No model Calculation Settings Air density calculation mode Individual per WTG Result for WTG at hub altitude 1.251 kg/m³ to 1.256 kg/m³ Air density relative to standard 102.1 % Hub altitude above sea level (asl) 69.2 m to 106.0 m Annual mean temperature at hub alt. 4.0 °C to 4.2 °C Pressure at WTGs 995.4 hPa to 999.9 hPa Relative humidity 0.6 % Wake Model Parameters No model parameters Wake calculation settings Angle [°] Wind speed [m/s] start end step start end step 0.5 360.0 1.0 0.5 30.5 1.0 Scale 1:50,000 New WTG Resource file(s) C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Calculated Annual Energy for Wind Farm Specific results¤) WTG combination Result Result-10.0% GROSS (no loss) Park Capacity Mean WTG Full load Mean wind speed PARK Free WTGs efficiency factor result hours @hub height [MWh/y] [MWh] [MWh/y] [%] [%] [MWh/y] [Hours/year] [m/s] Wind farm 4,142.2 3,728.0 4,142.2 100.0 38.7 932.0 3,389 8.0 ¤) Based on Result-10.0% Calculated Annual Energy for each of 4 new WTGs with total 1.1 MW rated power WTG type Power curve Annual Energy Park Terrain Valid Manufact. Type-generator Power, Rotor Hub Creator Name Result Result-10.0% Efficiency Mean rated diameter height wind speed [kW] [m] [m] [MWh] [MWh] [%] [m/s] 1 A Yes VERGNET GEV MP MODIFIED-275 275 32.0 37.0 USER 0 - official - SPM146k-32/275L - 04-2007 1,035.7 932 100.0 7.96 2 A Yes VERGNET GEV MP MODIFIED-275 275 32.0 37.0 USER 0 - official - SPM146k-32/275L - 04-2007 1,063.9 957 100.0 8.08 3 A Yes VERGNET GEV MP MODIFIED-275 275 32.0 37.0 USER 0 - official - SPM146k-32/275L - 04-2007 995.1 896 100.0 7.78 4 A Yes VERGNET GEV MP MODIFIED-275 275 32.0 37.0 USER 0 - official - SPM146k-32/275L - 04-2007 1,047.5 943 100.0 8.03 WTG siting UTM WGS84 Zone: 4 East North Z Row data/Description UTM WGS84 Zone: 4 [m] 1 New 513,897 6,234,263 39.5 Potential Location 1 2 New 512,766 6,234,395 32.2 Potential Location 2 3 New 516,138 6,234,010 59.1 Potential Location 3 4 New 514,327 6,233,422 69.0 Potential Location 4 C-17 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 2 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Production Analysis Calculation:AEP - from WRA - Vergnet 275 WTG:All new WTGs, Air density varies with WTG position 1.251 kg/m³ - 1.256 kg/m³ Directional Analysis Sector 0 N 1 NNE 2 NE 3 ENE 4 E 5 ESE 6 SE 7 SSE 8 S 9 SSW 10 SW 11 WSW 12 W 13 WNW 14 NW 15 NNW Total Roughness based energy [MWh] 25.9 37.7 154.9 203.4 164.5 205.5 151.3 72.8 82.0 86.7 219.0 760.2 1,388.6 462.4 89.9 37.5 4,142.2 Resulting energy [MWh] 25.9 37.7 154.9 203.4 164.5 205.5 151.3 72.8 82.0 86.7 219.0 760.2 1,388.6 462.4 89.9 37.5 4,142.2 Specific energy [kWh/m²]1,288 Specific energy [kWh/kW]3,766 Utilization [%] 36.3 36.6 31.7 32.5 32.7 32.0 30.4 26.9 32.6 32.3 29.0 25.1 27.2 27.3 26.5 31.8 28.1 Operational [Hours/year] 142 197 475 649 573 602 435 265 245 172 324 1,051 1,925 681 187 162 8,086 Full Load Equivalent [Hours/year] 24 34 141 185 150 187 138 66 75 79 199 691 1,262 420 82 34 3,766 C-18 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 3 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Power Curve Analysis Calculation:AEP - from WRA - Vergnet 275WTG:1 - VERGNET GEV MP MODIFIED 275 32.0 !O! 0 - official - SPM146k-32/275L - 04-2007, Hub height: 37.0 m Name:0 - official - SPM146k-32/275L - 04-2007 Source:Manufacturer with GARRAD HASSAN and AERODYN Source/Date Created by Created Edited Stop wind speed Power control CT curve type [m/s] 4/18/2007 USER 1/21/2008 7/7/2010 20.0 Pitch User defined Depends on mean wind speed on site (please consult Vergnet). Can be ajusted for noise purposes (please consult Vergnet). HP curve comparison - Note: For standard air density and weibull k parameter = 2 Vmean [m/s] 5 6 7 8 9 10 HP value [MWh] 369 591 817 1,034 1,216 1,377 VERGNET GEV MP MODIFIED 275 32.0 !O! 0 - official - SPM146k-32/275L - 04-2007 [MWh] 353 570 789 987 1,147 1,263 Check value [%] 4 4 3 5 6 9 The table shows comparison between annual energy production calculated on basis of simplified "HP-curves" which assume that all WTGs performs quite similar - only specific power loading (kW/m^2) and single/dual speed or stall/pitch decides the calculated values. Productions are without wake losses. For further details, ask at the Danish Energy Agency for project report J.nr. 51171/00-0016 or see WindPRO manual chapter 3.5.2. The method is refined in EMD report "20 Detailed Case Studies comparing Project Design Calculations and actual Energy Productions for Wind Energy Projects worldwide", jan 2003. Use the table to evaluate if the given power curve is reasonable - if the check value are lower than -5%, the power curve probably is too optimistic due to uncertainty in power curve measurement. Power curve Original data from Windcat, Air density: 1.225 kg/m³ Wind speed Power Ce Wind speed Ct curve [m/s] [kW] [m/s] 2.0 0.0 0.00 4.0 0.93 3.0 0.0 0.00 5.0 0.86 4.0 4.2 0.13 6.0 0.78 5.0 19.6 0.32 7.0 0.70 6.0 38.4 0.36 8.0 0.86 7.0 63.6 0.38 9.0 0.80 8.0 101.4 0.40 10.0 0.74 9.0 145.4 0.40 11.0 0.60 10.0 194.0 0.39 12.0 0.45 11.0 233.9 0.36 13.0 0.37 12.0 256.8 0.30 14.0 0.29 13.0 270.1 0.25 15.0 0.21 14.0 273.5 0.20 16.0 0.18 15.0 275.0 0.17 17.0 0.15 16.0 275.0 0.14 18.0 0.12 17.0 275.0 0.11 19.0 0.11 18.0 275.0 0.10 20.0 0.09 19.0 275.0 0.08 20.0 275.0 0.07 Power, Efficiency and energy vs. wind speed Data used in calculation, Air density: 1.255 kg/m³ New WindPRO method (adjusted IEC method, improved to match turbine control) <RECOMMENDED> Wind speed Power Ce Interval Energy Acc.Energy Relative [m/s] [kW] [m/s] [MWh] [MWh] [%] 1.0 0.0 0.00 0.50- 1.50 0.0 0.0 0.0 2.0 0.0 0.00 1.50- 2.50 0.0 0.0 0.0 3.0 0.1 0.01 2.50- 3.50 0.7 0.7 0.1 4.0 4.7 0.15 3.50- 4.50 5.2 5.8 0.6 5.0 20.3 0.32 4.50- 5.50 16.7 22.5 2.2 6.0 39.6 0.36 5.50- 6.50 34.6 57.1 5.5 7.0 65.6 0.38 6.50- 7.50 59.1 116.2 11.2 8.0 104.1 0.40 7.50- 8.50 89.2 205.4 19.8 9.0 149.1 0.41 8.50- 9.50 119.9 325.3 31.4 10.0 197.8 0.39 9.50-10.50 142.1 467.4 45.1 11.0 236.7 0.35 10.50-11.50 146.4 613.8 59.3 12.0 258.7 0.30 11.50-12.50 131.7 745.5 72.0 13.0 270.6 0.24 12.50-13.50 105.4 851.0 82.2 14.0 273.8 0.20 13.50-14.50 76.0 926.9 89.5 15.0 275.0 0.16 14.50-15.50 49.8 976.7 94.3 16.0 275.0 0.13 15.50-16.50 29.8 1,006.6 97.2 17.0 275.0 0.11 16.50-17.50 16.3 1,022.9 98.8 18.0 275.0 0.09 17.50-18.50 8.1 1,031.0 99.5 19.0 275.0 0.08 18.50-19.50 3.7 1,034.6 99.9 20.0 275.0 0.07 19.50-20.50 1.1 1,035.7 100.0 C-19 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 4 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vergnet 275 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 513,897 North: 6,234,263 Potential Location 1 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.70 5.08 2.866 1.7 1 NNE 5.74 5.11 2.830 2.3 2 NE 6.84 6.06 2.110 5.5 3 ENE 7.00 6.20 2.140 8.0 4 E 6.80 6.02 2.054 7.2 5 ESE 7.40 6.55 2.180 7.9 6 SE 7.40 6.56 2.064 5.6 7 SSE 6.00 5.39 1.570 3.2 8 S 6.90 6.12 2.426 3.0 9 SSW 8.60 7.69 3.100 2.0 10 SW 10.34 9.31 3.560 3.5 11 WSW 11.10 9.93 3.100 12.0 12 W 11.00 9.88 3.370 24.9 13 WNW 10.60 9.49 3.170 8.9 14 NW 8.80 7.79 2.210 2.3 15 NNW 5.80 5.15 1.870 2.0 All 8.99 7.96 2.297 100.0 C-20 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 5 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vergnet 275 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 512,766 North: 6,234,395 Potential Location 2 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.52 5.82 2.951 1.9 1 NNE 6.23 5.54 2.743 2.6 2 NE 6.90 6.11 2.110 5.6 3 ENE 6.92 6.12 2.140 7.1 4 E 6.50 5.76 2.040 6.3 5 ESE 7.50 6.64 2.190 8.0 6 SE 7.90 7.00 2.080 6.2 7 SSE 7.30 6.53 1.633 3.8 8 S 8.43 7.47 2.456 3.3 9 SSW 10.02 9.00 3.359 1.9 10 SW 10.52 9.47 3.535 3.7 11 WSW 10.69 9.56 3.080 10.4 12 W 10.79 9.69 3.380 24.3 13 WNW 11.00 9.86 3.240 9.8 14 NW 10.03 8.89 2.376 2.8 15 NNW 6.83 6.06 1.858 2.3 All 9.12 8.08 2.362 100.0 C-21 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 6 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vergnet 275 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 516,138 North: 6,234,010 Potential Location 3 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.10 4.54 2.812 1.5 1 NNE 5.51 4.91 2.841 2.1 2 NE 7.10 6.29 2.111 5.2 3 ENE 7.26 6.43 2.144 9.0 4 E 7.10 6.29 2.080 8.3 5 ESE 7.41 6.56 2.160 7.4 6 SE 7.04 6.24 2.030 4.9 7 SSE 5.80 5.20 1.600 2.8 8 S 6.63 5.88 2.361 2.6 9 SSW 7.80 6.95 2.854 2.0 10 SW 9.40 8.45 3.430 3.5 11 WSW 10.59 9.47 3.099 13.8 12 W 10.60 9.51 3.340 25.7 13 WNW 10.40 9.29 3.024 7.4 14 NW 7.60 6.73 2.063 2.1 15 NNW 5.00 4.44 1.860 1.7 All 8.78 7.78 2.321 100.0 C-22 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 7 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vergnet 275 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 514,327 North: 6,233,422 Potential Location 4 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.40 5.68 2.480 1.9 1 NNE 6.80 6.06 2.840 2.7 2 NE 7.75 6.87 2.120 7.2 3 ENE 7.05 6.25 2.100 8.1 4 E 6.60 5.85 2.080 6.6 5 ESE 7.10 6.29 2.190 6.5 6 SE 7.10 6.29 2.080 4.8 7 SSE 6.25 5.58 1.685 3.3 8 S 7.20 6.38 2.100 3.2 9 SSW 9.10 8.11 2.890 2.6 10 SW 10.90 9.78 3.304 5.3 11 WSW 11.50 10.29 3.150 15.9 12 W 10.90 9.78 3.340 20.3 13 WNW 9.80 8.77 3.170 7.6 14 NW 8.31 7.36 2.301 2.1 15 NNW 6.40 5.68 1.880 2.0 All 9.07 8.03 2.311 100.0 C-23 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:17 PM / 8 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:32 PM/2.7.486 PARK - WTG distances Calculation:AEP - from WRA - Vergnet 275 Scale 1:50,000 New WTG WTG distances Z Nearest WTG Z Horizontal distance Distance in rotor diameters [m] [m] [m] 1 39.5 4 69.0 944 29.5 2 32.2 1 39.5 1,138 35.6 3 59.1 4 69.0 1,905 59.5 4 69.0 1 39.5 944 29.5 C-24 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 1 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Main Result Calculation:AEP - from WRA - Vestas 225 Wake Model No model Calculation Settings Air density calculation mode Individual per WTG Result for WTG at hub altitude 1.251 kg/m³ to 1.256 kg/m³ Air density relative to standard 102.1 % Hub altitude above sea level (asl) 69.2 m to 106.0 m Annual mean temperature at hub alt. 4.0 °C to 4.2 °C Pressure at WTGs 995.4 hPa to 999.9 hPa Relative humidity 0.6 % Wake Model Parameters No model parameters Wake calculation settings Angle [°] Wind speed [m/s] start end step start end step 0.5 360.0 1.0 0.5 30.5 1.0 Scale 1:50,000 New WTG Resource file(s) C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Calculated Annual Energy for Wind Farm Specific results¤) WTG combination Result Result-10.0% GROSS (no loss) Park Capacity Mean WTG Full load Mean wind speed PARK Free WTGs efficiency factor result hours @hub height [MWh/y] [MWh] [MWh/y] [%] [%] [MWh/y] [Hours/year] [m/s] Wind farm 3,337.1 3,003.4 3,337.1 100.0 38.1 750.9 3,337 8.0 ¤) Based on Result-10.0% Calculated Annual Energy for each of 4 new WTGs with total 0.9 MW rated power WTG type Power curve Annual Energy Park Terrain Valid Manufact. Type-generator Power, Rotor Hub height Creator Name Result Result-10.0% Efficiency Mean wind rated diameter speed [kW] [m] [m] [MWh] [MWh] [%] [m/s] 1 A No VESTAS A27 MODIFIED-225 225 27.0 37.0 USER Vestas A27 835.0 752 100.0 7.96 2 A No VESTAS A27 MODIFIED-225 225 27.0 37.0 USER Vestas A27 857.9 772 100.0 8.08 3 A No VESTAS A27 MODIFIED-225 225 27.0 37.0 USER Vestas A27 800.1 720 100.0 7.78 4 A No VESTAS A27 MODIFIED-225 225 27.0 37.0 USER Vestas A27 844.1 760 100.0 8.03 WTG siting UTM WGS84 Zone: 4 East North Z Row data/Description UTM WGS84 Zone: 4 [m] 1 New 513,897 6,234,263 39.5 Potential Location 1 2 New 512,766 6,234,395 32.2 Potential Location 2 3 New 516,138 6,234,010 59.1 Potential Location 3 4 New 514,327 6,233,422 69.0 Potential Location 4 C-25 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 2 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Production Analysis Calculation:AEP - from WRA - Vestas 225 WTG:All new WTGs, Air density varies with WTG position 1.251 kg/m³ - 1.256 kg/m³ Directional Analysis Sector 0 N 1 NNE 2 NE 3 ENE 4 E 5 ESE 6 SE 7 SSE 8 S 9 SSW 10 SW 11 WSW 12 W 13 WNW 14 NW 15 NNW Total Roughness based energy [MWh] 20.9 30.5 124.5 163.4 132.1 165.0 121.8 59.3 65.8 69.3 175.8 615.3 1,118.0 372.4 72.9 30.2 3,337.1 Resulting energy [MWh] 20.9 30.5 124.5 163.4 132.1 165.0 121.8 59.3 65.8 69.3 175.8 615.3 1,118.0 372.4 72.9 30.2 3,337.1 Specific energy [kWh/m²]1,457 Specific energy [kWh/kW]3,708 Utilization [%] 41.2 41.5 35.7 36.7 36.9 36.1 34.4 30.7 36.8 36.3 32.7 28.6 30.7 30.9 30.1 36.0 31.8 Operational [Hours/year] 146 203 489 668 590 619 447 273 252 177 333 1,082 1,981 701 193 166 8,322 Full Load Equivalent [Hours/year] 23 34 138 182 147 183 135 66 73 77 195 684 1,242 414 81 34 3,708 C-26 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 3 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Power Curve Analysis Calculation:AEP - from WRA - Vestas 225 WTG:1 - VESTAS A27 MODIFIED 225 27.0 !O! Vestas A27, Hub height: 37.0 m Name:Vestas A27 Source: Created by Created Edited Stop wind speed Power control CT curve type [m/s] USER 7/6/2010 7/6/2010 25.0 Stall Standard stall HP curve comparison - Note: For standard air density and weibull k parameter = 2 Vmean [m/s] 5 6 7 8 9 10 HP value [MWh] 260 421 591 745 887 1,015 VESTAS A27 MODIFIED 225 27.0 !O! Vestas A27 [MWh] 286 457 633 799 945 1,068 Check value [%] -9 -8 -7 -7 -6 -5 The table shows comparison between annual energy production calculated on basis of simplified "HP-curves" which assume that all WTGs performs quite similar - only specific power loading (kW/m^2) and single/dual speed or stall/pitch decides the calculated values. Productions are without wake losses. For further details, ask at the Danish Energy Agency for project report J.nr. 51171/00-0016 or see WindPRO manual chapter 3.5.2. The method is refined in EMD report "20 Detailed Case Studies comparing Project Design Calculations and actual Energy Productions for Wind Energy Projects worldwide", jan 2003. Use the table to evaluate if the given power curve is reasonable - if the check value are lower than -5%, the power curve probably is too optimistic due to uncertainty in power curve measurement. Power curve Original data from Windcat, Air density: 1.225 kg/m³ Wind speed Power Ce Wind speed Ct curve [m/s] [kW] [m/s] 3.5 1.5 0.10 1.0 0.10 4.0 4.5 0.20 2.0 0.10 5.0 16.6 0.38 3.0 0.10 6.0 31.8 0.42 4.0 0.80 7.0 52.5 0.44 5.0 0.82 8.0 82.4 0.46 6.0 0.85 9.0 114.5 0.45 7.0 0.82 10.0 148.3 0.42 8.0 0.78 11.0 181.0 0.39 9.0 0.74 12.0 205.0 0.34 10.0 0.68 13.0 217.6 0.28 11.0 0.62 14.0 225.0 0.23 12.0 0.55 15.0 225.0 0.19 13.0 0.49 16.0 225.0 0.16 14.0 0.43 17.0 225.0 0.13 15.0 0.38 18.0 225.0 0.11 16.0 0.32 19.0 225.0 0.09 17.0 0.28 20.0 225.0 0.08 18.0 0.25 21.0 225.0 0.07 19.0 0.21 22.0 225.0 0.06 20.0 0.20 23.0 225.0 0.05 21.0 0.19 24.0 225.0 0.05 22.0 0.17 25.0 225.0 0.04 23.0 0.16 24.0 0.15 25.0 0.14 26.0 0.13 27.0 0.12 28.0 0.11 29.0 0.10 Power, Efficiency and energy vs. wind speed Data used in calculation, Air density: 1.255 kg/m³ New WindPRO method (adjusted IEC method, improved to match turbine control) <RECOMMENDED> Wind speed Power Ce Interval Energy Acc.Energy Relative [m/s] [kW] [m/s] [MWh] [MWh] [%] 1.0 0.0 0.00 0.50- 1.50 0.0 0.0 0.0 2.0 0.0 0.00 1.50- 2.50 0.0 0.0 0.0 3.0 0.0 0.00 2.50- 3.50 0.5 0.5 0.1 4.0 4.6 0.20 3.50- 4.50 4.4 4.8 0.6 5.0 17.0 0.38 4.50- 5.50 14.0 18.8 2.3 6.0 32.6 0.42 5.50- 6.50 28.7 47.5 5.7 7.0 53.8 0.44 6.50- 7.50 48.4 95.9 11.5 8.0 84.4 0.46 7.50- 8.50 71.9 167.8 20.1 9.0 117.3 0.45 8.50- 9.50 94.1 261.8 31.4 10.0 151.9 0.42 9.50-10.50 109.9 371.7 44.5 11.0 185.4 0.39 10.50-11.50 114.8 486.5 58.3 12.0 210.0 0.34 11.50-12.50 106.0 592.5 71.0 13.0 222.9 0.28 12.50-13.50 86.7 679.2 81.3 14.0 230.5 0.23 13.50-14.50 63.5 742.7 88.9 15.0 230.5 0.19 14.50-15.50 41.8 784.5 93.9 16.0 230.5 0.16 15.50-16.50 25.0 809.5 96.9 17.0 230.5 0.13 16.50-17.50 13.6 823.1 98.6 18.0 230.5 0.11 17.50-18.50 6.8 829.9 99.4 19.0 230.5 0.09 18.50-19.50 3.1 833.0 99.8 20.0 230.5 0.08 19.50-20.50 1.3 834.3 99.9 21.0 230.5 0.07 20.50-21.50 0.5 834.7 100.0 22.0 230.5 0.06 21.50-22.50 0.2 834.9 100.0 23.0 230.5 0.05 22.50-23.50 0.1 835.0 100.0 24.0 230.5 0.05 23.50-24.50 0.0 835.0 100.0 25.0 230.5 0.04 24.50-25.50 0.0 835.0 100.0 C-27 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 4 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vestas 225 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 513,897 North: 6,234,263 Potential Location 1 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.70 5.08 2.866 1.7 1 NNE 5.74 5.11 2.830 2.3 2 NE 6.84 6.06 2.110 5.5 3 ENE 7.00 6.20 2.140 8.0 4 E 6.80 6.02 2.054 7.2 5 ESE 7.40 6.55 2.180 7.9 6 SE 7.40 6.56 2.064 5.6 7 SSE 6.00 5.39 1.570 3.2 8 S 6.90 6.12 2.426 3.0 9 SSW 8.60 7.69 3.100 2.0 10 SW 10.34 9.31 3.560 3.5 11 WSW 11.10 9.93 3.100 12.0 12 W 11.00 9.88 3.370 24.9 13 WNW 10.60 9.49 3.170 8.9 14 NW 8.80 7.79 2.210 2.3 15 NNW 5.80 5.15 1.870 2.0 All 8.99 7.96 2.297 100.0 C-28 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 5 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vestas 225 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 512,766 North: 6,234,395 Potential Location 2 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.52 5.82 2.951 1.9 1 NNE 6.23 5.54 2.743 2.6 2 NE 6.90 6.11 2.110 5.6 3 ENE 6.92 6.12 2.140 7.1 4 E 6.50 5.76 2.040 6.3 5 ESE 7.50 6.64 2.190 8.0 6 SE 7.90 7.00 2.080 6.2 7 SSE 7.30 6.53 1.633 3.8 8 S 8.43 7.47 2.456 3.3 9 SSW 10.02 9.00 3.359 1.9 10 SW 10.52 9.47 3.535 3.7 11 WSW 10.69 9.56 3.080 10.4 12 W 10.79 9.69 3.380 24.3 13 WNW 11.00 9.86 3.240 9.8 14 NW 10.03 8.89 2.376 2.8 15 NNW 6.83 6.06 1.858 2.3 All 9.12 8.08 2.362 100.0 C-29 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 6 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vestas 225 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 516,138 North: 6,234,010 Potential Location 3 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 5.10 4.54 2.812 1.5 1 NNE 5.51 4.91 2.841 2.1 2 NE 7.10 6.29 2.111 5.2 3 ENE 7.26 6.43 2.144 9.0 4 E 7.10 6.29 2.080 8.3 5 ESE 7.41 6.56 2.160 7.4 6 SE 7.04 6.24 2.030 4.9 7 SSE 5.80 5.20 1.600 2.8 8 S 6.63 5.88 2.361 2.6 9 SSW 7.80 6.95 2.854 2.0 10 SW 9.40 8.45 3.430 3.5 11 WSW 10.59 9.47 3.099 13.8 12 W 10.60 9.51 3.340 25.7 13 WNW 10.40 9.29 3.024 7.4 14 NW 7.60 6.73 2.063 2.1 15 NNW 5.00 4.44 1.860 1.7 All 8.78 7.78 2.321 100.0 C-30 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 7 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - Wind Data Analysis Calculation:AEP - from WRA - Vestas 225 Wind data: A - Resource file(s); Hub height: 37.0 Site Coordinates UTM WGS 84 Zone: 4 East: 514,327 North: 6,233,422 Potential Location 4 RSF file C:\WindPro\WINDPRO_Data\PROJECTS\CHIGNIK_LAKE\ChignikLake_Res_10_Hub_37_50_0.rsf Weibull Data Sector A- parameter Wind speed k- parameter Frequency [m/s] [m/s] [%] 0 N 6.40 5.68 2.480 1.9 1 NNE 6.80 6.06 2.840 2.7 2 NE 7.75 6.87 2.120 7.2 3 ENE 7.05 6.25 2.100 8.1 4 E 6.60 5.85 2.080 6.6 5 ESE 7.10 6.29 2.190 6.5 6 SE 7.10 6.29 2.080 4.8 7 SSE 6.25 5.58 1.685 3.3 8 S 7.20 6.38 2.100 3.2 9 SSW 9.10 8.11 2.890 2.6 10 SW 10.90 9.78 3.304 5.3 11 WSW 11.50 10.29 3.150 15.9 12 W 10.90 9.78 3.340 20.3 13 WNW 9.80 8.77 3.170 7.6 14 NW 8.31 7.36 2.301 2.1 15 NNW 6.40 5.68 1.880 2.0 All 9.07 8.03 2.311 100.0 C-31 WindPRO version 2.7.486 Jan 2011 WindPRO is developed by EMD International A/S, Niels Jernesvej 10, DK-9220 Aalborg Ø, Tlf. +45 96 35 44 44, Fax +45 96 35 44 46, e-mail: windpro@emd.dk Project: ChignikLake Lake and Peninsula Borough Lamar Cotten PO BOX 495 King Salmon, AK 99613 Description: WRA for the City of Chignik Lake Printed/Page 5/5/2011 1:16 PM / 8 Licensed user: Knight Piesold Ltd 1580 Lincoln Street, Suite 1000 US-DENVER, CO 80203 +1 303 629 8788 Rick Damiani / rdamiani@knightpiesold.com Calculated: 4/12/2011 1:31 PM/2.7.486 PARK - WTG distances Calculation:AEP - from WRA - Vestas 225 Scale 1:50,000 New WTG WTG distances Z Nearest WTG Z Horizontal distance Distance in rotor diameters [m] [m] [m] 1 39.5 4 69.0 944 35.0 2 32.2 1 39.5 1,138 42.2 3 59.1 4 69.0 1,905 70.5 4 69.0 1 39.5 944 35.0 C-32 www.knightpiesold.com Appendix D Northwind 100B/21 Economics Table of Contents Site Number Height Diesel Price US$/gal Page Number 1 37 m 4.25 D-1 1 37 m 5.50 D-8 1 37 m 6.92 D-15 1 37 m 8.30 D-22 2 37 m 4.25 D-29 2 37 m 5.50 D-36 2 37 m 6.92 D-43 2 37 m 8.30 D-50 DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,595,945 Levelized cost of energy $ 0.431/kWh Operating cost $ 146,795/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,391,682 0 127,636 0 0 1,519,318 Generator 4 0 15,298 59,839 316,119 -13,864 377,392 Generator 3 0 19,666 70,744 802,497 -13,015 879,893 Generator 2 0 0 4,317 96,107 -20,590 79,834 Generator 1 0 0 131 3,802 -21,402 -17,469 Boiler 0 0 0 413,487 0 413,487 Other 0 0 343,490 0 0 343,490 System 1,391,682 34,964 606,157 1,632,012 -68,871 3,595,944 Capital Replacement O&M Fuel Salvage Total D-1 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 92,680 0 8,500 0 0 101,180 Generator 4 0 1,019 3,985 21,052 -923 25,133 Generator 3 0 1,310 4,711 53,443 -867 58,597 Generator 2 0 0 287 6,400 -1,371 5,317 Generator 1 0 0 9 253 -1,425 -1,163 Boiler 0 0 0 27,537 0 27,537 Other 0 0 22,875 0 0 22,875 System 92,680 2,328 40,367 108,685 -4,586 239,475 Component Production Fraction (kWh/yr) Wind turbine 347,056 62% Generator 4 45,771 8% Generator 3 150,506 27% Generator 2 16,822 3% Generator 1 693 0% Total 560,849 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-2 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 141,100 kWh/yr Unmet load 0.00148 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.396 Component Production Fraction (kWh/yr) Generator 4 30,622 7% Generator 3 70,186 15% Generator 2 8,670 2% Generator 1 337 0% Boiler 205,639 45% Excess electricity 141,100 31% Total 456,554 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 20,380 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 39.6 kW Capacity factor 39.6 % Total production 347,056 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 82.7 % Hours of operation 7,361 hr/yr Levelized cost 0.292 $/kWh D-3 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,188 hr/yr Number of starts 1,230 starts/yr Operational life 18.8 yr Capacity factor 11.4 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 45,771 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 30,622 kWh/yr Mean thermal output 9.61 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 18,797 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 184,959 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,769 hr/yr Number of starts 801 starts/yr Operational life 15.9 yr D-4 Generator 2 Capacity factor 21.0 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 150,506 kWh/yr Mean electrical output 39.9 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 70,186 kWh/yr Mean thermal output 18.6 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 47,717 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 469,535 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 230 hr/yr Number of starts 169 starts/yr Operational life 261 yr Capacity factor 1.70 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 16,822 kWh/yr Mean electrical output 73.1 kW Min. electrical output 61.3 kW Max. electrical output 93.1 kW Thermal production 8,670 kWh/yr Mean thermal output 37.7 kW Min. thermal output 34.9 kW Max. thermal output 42.5 kW D-5 Generator 1 Quantity Value Units Fuel consumption 5,715 L/yr Specific fuel consumption 0.340 L/kWh Fuel energy input 56,231 kWh/yr Mean electrical efficiency 29.9 % Mean total efficiency 45.3 % Quantity Value Units Hours of operation 7 hr/yr Number of starts 7 starts/yr Operational life 8,571 yr Capacity factor 0.0586 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 693 kWh/yr Mean electrical output 99.0 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 337 kWh/yr Mean thermal output 48.1 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 226 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 2,225 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % D-6 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 255,847 Carbon monoxide 471 Unburned hydocarbons 52.2 Particulate matter 35.5 Sulfur dioxide 516 Nitrogen oxides 4,202 D-7 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,076,832 Levelized cost of energy $ 0.467/kWh Operating cost $ 178,820/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,391,682 0 127,636 0 0 1,519,318 Generator 4 0 15,383 60,458 412,850 -13,701 474,989 Generator 3 0 19,791 71,739 1,055,706 -12,705 1,134,530 Generator 2 0 0 3,510 102,683 -20,909 85,283 Generator 1 0 0 131 4,922 -21,402 -16,349 Boiler 0 0 0 535,570 0 535,570 Other 0 0 343,490 0 0 343,490 System 1,391,682 35,173 606,964 2,111,731 -68,718 4,076,831 Capital Replacement O&M Fuel Salvage Total D-8 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 92,680 0 8,500 0 0 101,180 Generator 4 0 1,024 4,026 27,494 -912 31,632 Generator 3 0 1,318 4,777 70,306 -846 75,555 Generator 2 0 0 234 6,838 -1,392 5,680 Generator 1 0 0 9 328 -1,425 -1,089 Boiler 0 0 0 35,667 0 35,667 Other 0 0 22,875 0 0 22,875 System 92,680 2,342 40,421 140,632 -4,576 271,500 Component Production Fraction (kWh/yr) Wind turbine 347,056 62% Generator 4 46,148 8% Generator 3 152,976 27% Generator 2 14,007 2% Generator 1 693 0% Total 560,881 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-9 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 141,132 kWh/yr Unmet load 0.00152 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.396 Component Production Fraction (kWh/yr) Generator 4 30,896 7% Generator 3 71,309 16% Generator 2 7,128 2% Generator 1 337 0% Boiler 205,735 45% Excess electricity 141,132 31% Total 456,538 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 20,364 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 39.6 kW Capacity factor 39.6 % Total production 347,056 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 82.7 % Hours of operation 7,361 hr/yr Levelized cost 0.292 $/kWh D-10 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,221 hr/yr Number of starts 1,256 starts/yr Operational life 18.6 yr Capacity factor 11.5 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 46,148 kWh/yr Mean electrical output 14.3 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 30,896 kWh/yr Mean thermal output 9.59 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 18,961 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 186,581 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,822 hr/yr Number of starts 783 starts/yr Operational life 15.7 yr D-11 Generator 2 Capacity factor 21.3 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 152,976 kWh/yr Mean electrical output 40.0 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 71,309 kWh/yr Mean thermal output 18.7 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 48,487 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 477,108 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 187 hr/yr Number of starts 140 starts/yr Operational life 321 yr Capacity factor 1.42 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 14,007 kWh/yr Mean electrical output 74.9 kW Min. electrical output 67.4 kW Max. electrical output 93.1 kW Thermal production 7,128 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.3 kW Max. thermal output 42.5 kW D-12 Generator 1 Quantity Value Units Fuel consumption 4,716 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 46,406 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 7 hr/yr Number of starts 7 starts/yr Operational life 8,571 yr Capacity factor 0.0586 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 693 kWh/yr Mean electrical output 99.0 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 337 kWh/yr Mean thermal output 48.1 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 226 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 2,225 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % D-13 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 255,709 Carbon monoxide 471 Unburned hydocarbons 52.1 Particulate matter 35.5 Sulfur dioxide 516 Nitrogen oxides 4,199 D-14 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,630,323 Levelized cost of energy $ 0.507/kWh Operating cost $ 215,680/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,391,682 0 127,636 0 0 1,519,318 Generator 4 0 15,565 61,828 532,074 -13,341 596,126 Generator 3 0 19,989 73,372 1,372,853 -12,198 1,454,015 Generator 2 0 0 2,102 79,722 -21,467 60,358 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 676,543 0 676,543 Other 0 0 343,490 0 0 343,490 System 1,391,682 35,554 608,465 2,663,064 -68,444 4,630,321 Capital Replacement O&M Fuel Salvage Total D-15 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 92,680 0 8,500 0 0 101,180 Generator 4 0 1,037 4,117 35,434 -888 39,699 Generator 3 0 1,331 4,886 91,426 -812 96,831 Generator 2 0 0 140 5,309 -1,430 4,020 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 45,055 0 45,055 Other 0 0 22,875 0 0 22,875 System 92,680 2,368 40,521 177,349 -4,558 308,360 Component Production Fraction (kWh/yr) Wind turbine 347,056 62% Generator 4 47,102 8% Generator 3 157,782 28% Generator 2 8,751 2% Generator 1 212 0% Total 560,904 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-16 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 141,155 kWh/yr Unmet load 0.00156 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.396 Component Production Fraction (kWh/yr) Generator 4 31,555 7% Generator 3 73,441 16% Generator 2 4,355 1% Generator 1 101 0% Boiler 205,923 45% Excess electricity 141,155 31% Total 456,530 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 20,356 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 39.6 kW Capacity factor 39.6 % Total production 347,056 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 82.7 % Hours of operation 7,361 hr/yr Levelized cost 0.292 $/kWh D-17 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,294 hr/yr Number of starts 1,311 starts/yr Operational life 18.2 yr Capacity factor 11.7 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 47,102 kWh/yr Mean electrical output 14.3 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 31,555 kWh/yr Mean thermal output 9.58 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 19,363 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 190,530 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,909 hr/yr Number of starts 740 starts/yr Operational life 15.3 yr D-18 Generator 2 Capacity factor 22.0 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 157,782 kWh/yr Mean electrical output 40.4 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 73,441 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 49,960 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 491,603 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 112 hr/yr Number of starts 89 starts/yr Operational life 536 yr Capacity factor 0.884 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 8,751 kWh/yr Mean electrical output 78.1 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 4,355 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW D-19 Generator 1 Quantity Value Units Fuel consumption 2,901 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 28,548 kWh/yr Mean electrical efficiency 30.7 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % D-20 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 255,510 Carbon monoxide 470 Unburned hydocarbons 52.1 Particulate matter 35.4 Sulfur dioxide 516 Nitrogen oxides 4,193 D-21 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,154,238 Levelized cost of energy $ 0.546/kWh Operating cost $ 250,570/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,391,682 0 127,636 0 0 1,519,318 Generator 4 0 15,636 62,373 641,958 -13,198 706,769 Generator 3 0 20,067 74,029 1,662,798 -11,994 1,744,900 Generator 2 0 0 1,502 69,252 -21,705 49,049 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 809,870 0 809,870 Other 0 0 343,490 0 0 343,490 System 1,391,682 35,703 609,066 3,186,120 -68,335 5,154,236 Capital Replacement O&M Fuel Salvage Total D-22 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 92,680 0 8,500 0 0 101,180 Generator 4 0 1,041 4,154 42,752 -879 47,068 Generator 3 0 1,336 4,930 110,735 -799 116,203 Generator 2 0 0 100 4,612 -1,445 3,266 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 53,934 0 53,934 Other 0 0 22,875 0 0 22,875 System 92,680 2,378 40,561 212,182 -4,551 343,250 Component Production Fraction (kWh/yr) Wind turbine 347,056 62% Generator 4 47,479 8% Generator 3 159,758 28% Generator 2 6,410 1% Generator 1 212 0% Total 560,914 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-23 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 141,165 kWh/yr Unmet load 0.00159 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.396 Component Production Fraction (kWh/yr) Generator 4 31,816 7% Generator 3 74,315 16% Generator 2 3,149 1% Generator 1 101 0% Boiler 205,983 45% Excess electricity 141,165 31% Total 456,528 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 20,355 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 39.6 kW Capacity factor 39.6 % Total production 347,056 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 82.7 % Hours of operation 7,361 hr/yr Levelized cost 0.292 $/kWh D-24 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,323 hr/yr Number of starts 1,337 starts/yr Operational life 18.1 yr Capacity factor 11.8 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 47,479 kWh/yr Mean electrical output 14.3 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 31,816 kWh/yr Mean thermal output 9.57 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 19,521 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 192,090 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,944 hr/yr Number of starts 723 starts/yr Operational life 15.2 yr D-25 Generator 2 Capacity factor 22.3 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 159,758 kWh/yr Mean electrical output 40.5 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 74,315 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 50,564 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 497,551 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 80 hr/yr Number of starts 69 starts/yr Operational life 750 yr Capacity factor 0.648 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 6,410 kWh/yr Mean electrical output 80.1 kW Min. electrical output 74.6 kW Max. electrical output 93.1 kW Thermal production 3,149 kWh/yr Mean thermal output 39.4 kW Min. thermal output 38.0 kW Max. thermal output 42.5 kW D-26 Generator 1 Quantity Value Units Fuel consumption 2,106 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 20,722 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % D-27 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 255,444 Carbon monoxide 470 Unburned hydocarbons 52 Particulate matter 35.4 Sulfur dioxide 515 Nitrogen oxides 4,191 D-28 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,784,680 Levelized cost of energy $ 0.461/kWh Operating cost $ 144,912/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,608,682 0 127,636 0 0 1,736,318 Generator 4 0 15,280 59,707 315,418 -13,898 376,507 Generator 3 0 19,493 69,392 787,575 -13,435 863,025 Generator 2 0 0 4,054 90,396 -20,694 73,757 Generator 1 0 0 131 3,797 -21,402 -17,474 Boiler 0 0 0 409,056 0 409,056 Other 0 0 343,490 0 0 343,490 System 1,608,682 34,772 604,411 1,606,243 -69,429 3,784,679 Capital Replacement O&M Fuel Salvage Total D-29 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 107,131 0 8,500 0 0 115,631 Generator 4 0 1,018 3,976 21,006 -926 25,074 Generator 3 0 1,298 4,621 52,449 -895 57,474 Generator 2 0 0 270 6,020 -1,378 4,912 Generator 1 0 0 9 253 -1,425 -1,164 Boiler 0 0 0 27,241 0 27,241 Other 0 0 22,875 0 0 22,875 System 107,131 2,316 40,251 106,969 -4,624 252,044 Component Production Fraction (kWh/yr) Wind turbine 356,294 63% Generator 4 45,669 8% Generator 3 147,718 26% Generator 2 15,838 3% Generator 1 692 0% Total 566,211 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-30 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 146,462 kWh/yr Unmet load 0.00134 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.406 Component Production Fraction (kWh/yr) Generator 4 30,554 7% Generator 3 68,879 15% Generator 2 8,152 2% Generator 1 337 0% Boiler 203,435 44% Excess electricity 146,462 32% Total 457,818 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 21,644 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 40.7 kW Capacity factor 40.7 % Total production 356,294 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 84.9 % Hours of operation 7,390 hr/yr Levelized cost 0.325 $/kWh D-31 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,181 hr/yr Number of starts 1,242 starts/yr Operational life 18.9 yr Capacity factor 11.4 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 45,669 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 30,554 kWh/yr Mean thermal output 9.61 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 18,755 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 184,549 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,697 hr/yr Number of starts 800 starts/yr Operational life 16.2 yr D-32 Generator 2 Capacity factor 20.6 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 147,718 kWh/yr Mean electrical output 40.0 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 68,879 kWh/yr Mean thermal output 18.6 kW Min. thermal output 12.7 kW Max. thermal output 29.5 kW Quantity Value Units Fuel consumption 46,830 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 460,804 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 216 hr/yr Number of starts 159 starts/yr Operational life 278 yr Capacity factor 1.60 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 15,838 kWh/yr Mean electrical output 73.3 kW Min. electrical output 61.3 kW Max. electrical output 93.1 kW Thermal production 8,152 kWh/yr Mean thermal output 37.7 kW Min. thermal output 34.9 kW Max. thermal output 42.5 kW D-33 Generator 1 Quantity Value Units Fuel consumption 5,375 L/yr Specific fuel consumption 0.339 L/kWh Fuel energy input 52,890 kWh/yr Mean electrical efficiency 29.9 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 7 hr/yr Number of starts 7 starts/yr Operational life 8,571 yr Capacity factor 0.0585 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 692 kWh/yr Mean electrical output 98.9 kW Min. electrical output 94.1 kW Max. electrical output 109 kW Thermal production 337 kWh/yr Mean thermal output 48.1 kW Min. thermal output 46.5 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 226 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 2,222 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.3 % D-34 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 251,809 Carbon monoxide 463 Unburned hydocarbons 51.3 Particulate matter 34.9 Sulfur dioxide 508 Nitrogen oxides 4,129 D-35 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,257,954 Levelized cost of energy $ 0.495/kWh Operating cost $ 176,430/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,608,682 0 127,636 0 0 1,736,318 Generator 4 0 15,342 60,158 410,824 -13,780 472,543 Generator 3 0 19,599 70,218 1,033,174 -13,178 1,109,813 Generator 2 0 0 3,416 99,906 -20,946 82,376 Generator 1 0 0 131 4,916 -21,402 -16,355 Boiler 0 0 0 529,767 0 529,767 Other 0 0 343,490 0 0 343,490 System 1,608,682 34,941 605,049 2,078,587 -69,307 4,257,952 Capital Replacement O&M Fuel Salvage Total D-36 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 107,131 0 8,500 0 0 115,631 Generator 4 0 1,022 4,006 27,359 -918 31,469 Generator 3 0 1,305 4,676 68,805 -878 73,909 Generator 2 0 0 227 6,653 -1,395 5,486 Generator 1 0 0 9 327 -1,425 -1,089 Boiler 0 0 0 35,280 0 35,280 Other 0 0 22,875 0 0 22,875 System 107,131 2,327 40,294 138,425 -4,616 283,562 Component Production Fraction (kWh/yr) Wind turbine 356,294 63% Generator 4 45,923 8% Generator 3 149,708 26% Generator 2 13,626 2% Generator 1 692 0% Total 566,243 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-37 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 146,494 kWh/yr Unmet load 0.00135 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.406 Component Production Fraction (kWh/yr) Generator 4 30,744 7% Generator 3 69,788 15% Generator 2 6,935 2% Generator 1 337 0% Boiler 203,506 44% Excess electricity 146,494 32% Total 457,804 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 21,630 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 40.7 kW Capacity factor 40.7 % Total production 356,294 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 84.9 % Hours of operation 7,390 hr/yr Levelized cost 0.325 $/kWh D-38 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,205 hr/yr Number of starts 1,266 starts/yr Operational life 18.7 yr Capacity factor 11.4 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 45,923 kWh/yr Mean electrical output 14.3 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 30,744 kWh/yr Mean thermal output 9.59 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 18,868 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 185,665 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,741 hr/yr Number of starts 787 starts/yr Operational life 16.0 yr D-39 Generator 2 Capacity factor 20.9 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 149,708 kWh/yr Mean electrical output 40.0 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 69,788 kWh/yr Mean thermal output 18.7 kW Min. thermal output 12.7 kW Max. thermal output 29.5 kW Quantity Value Units Fuel consumption 47,452 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 466,925 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 182 hr/yr Number of starts 136 starts/yr Operational life 330 yr Capacity factor 1.38 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 13,626 kWh/yr Mean electrical output 74.9 kW Min. electrical output 67.5 kW Max. electrical output 93.1 kW Thermal production 6,935 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.4 kW Max. thermal output 42.5 kW D-40 Generator 1 Quantity Value Units Fuel consumption 4,588 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 45,151 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 7 hr/yr Number of starts 7 starts/yr Operational life 8,571 yr Capacity factor 0.0585 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 692 kWh/yr Mean electrical output 98.9 kW Min. electrical output 94.1 kW Max. electrical output 109 kW Thermal production 337 kWh/yr Mean thermal output 48.1 kW Min. thermal output 46.5 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 226 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 2,222 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.3 % D-41 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 251,698 Carbon monoxide 462 Unburned hydocarbons 51.2 Particulate matter 34.9 Sulfur dioxide 508 Nitrogen oxides 4,126 D-42 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,802,754 Levelized cost of energy $ 0.535/kWh Operating cost $ 212,712/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,608,682 0 127,636 0 0 1,736,318 Generator 4 0 15,516 61,453 528,823 -13,440 592,352 Generator 3 0 19,800 71,814 1,343,181 -12,682 1,422,113 Generator 2 0 0 2,065 78,240 -21,482 58,823 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 669,184 0 669,184 Other 0 0 343,490 0 0 343,490 System 1,608,682 35,316 606,494 2,621,302 -69,042 4,802,753 Capital Replacement O&M Fuel Salvage Total D-43 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 107,131 0 8,500 0 0 115,631 Generator 4 0 1,033 4,092 35,217 -895 39,448 Generator 3 0 1,319 4,782 89,450 -845 94,707 Generator 2 0 0 137 5,210 -1,431 3,917 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 44,565 0 44,565 Other 0 0 22,875 0 0 22,875 System 107,131 2,352 40,390 174,568 -4,598 319,843 Component Production Fraction (kWh/yr) Wind turbine 356,294 63% Generator 4 46,814 8% Generator 3 154,364 27% Generator 2 8,585 2% Generator 1 212 0% Total 566,269 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-44 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 146,520 kWh/yr Unmet load 0.00139 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.406 Component Production Fraction (kWh/yr) Generator 4 31,362 7% Generator 3 71,855 16% Generator 2 4,275 1% Generator 1 101 0% Boiler 203,683 44% Excess electricity 146,520 32% Total 457,797 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 21,623 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 40.7 kW Capacity factor 40.7 % Total production 356,294 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 84.9 % Hours of operation 7,390 hr/yr Levelized cost 0.325 $/kWh D-45 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,274 hr/yr Number of starts 1,322 starts/yr Operational life 18.3 yr Capacity factor 11.7 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 46,814 kWh/yr Mean electrical output 14.3 kW Min. electrical output 13.7 kW Max. electrical output 21.7 kW Thermal production 31,362 kWh/yr Mean thermal output 9.58 kW Min. thermal output 9.33 kW Max. thermal output 12.9 kW Quantity Value Units Fuel consumption 19,244 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 189,366 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,826 hr/yr Number of starts 742 starts/yr Operational life 15.7 yr D-46 Generator 2 Capacity factor 21.5 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 154,364 kWh/yr Mean electrical output 40.3 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 71,855 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 48,880 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 480,979 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 110 hr/yr Number of starts 88 starts/yr Operational life 545 yr Capacity factor 0.867 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 8,585 kWh/yr Mean electrical output 78.0 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 4,275 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW D-47 Generator 1 Quantity Value Units Fuel consumption 2,847 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 28,017 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % D-48 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 251,504 Carbon monoxide 462 Unburned hydocarbons 51.1 Particulate matter 34.8 Sulfur dioxide 507 Nitrogen oxides 4,120 D-49 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,318,451 Levelized cost of energy $ 0.572/kWh Operating cost $ 247,055/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 1,608,682 0 127,636 0 0 1,736,318 Generator 4 0 15,587 61,997 638,144 -13,297 702,432 Generator 3 0 19,876 72,433 1,626,396 -12,490 1,706,215 Generator 2 0 0 1,483 68,313 -21,712 48,084 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 801,070 0 801,070 Other 0 0 343,490 0 0 343,490 System 1,608,682 35,463 607,076 3,136,164 -68,937 5,318,450 Capital Replacement O&M Fuel Salvage Total D-50 Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 107,131 0 8,500 0 0 115,631 Generator 4 0 1,038 4,129 42,498 -886 46,779 Generator 3 0 1,324 4,824 108,311 -832 113,627 Generator 2 0 0 99 4,549 -1,446 3,202 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 53,348 0 53,348 Other 0 0 22,875 0 0 22,875 System 107,131 2,362 40,429 208,855 -4,591 354,186 Component Production Fraction (kWh/yr) Wind turbine 356,294 63% Generator 4 47,198 8% Generator 3 156,253 28% Generator 2 6,319 1% Generator 1 212 0% Total 566,276 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units D-51 Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 146,527 kWh/yr Unmet load 0.00141 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.406 Component Production Fraction (kWh/yr) Generator 4 31,626 7% Generator 3 72,689 16% Generator 2 3,107 1% Generator 1 101 0% Boiler 203,745 45% Excess electricity 146,527 32% Total 457,795 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 21,621 kWh/yr Variable Value Units Total rated capacity 100 kW Mean output 40.7 kW Capacity factor 40.7 % Total production 356,294 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 100 kW Wind penetration 84.9 % Hours of operation 7,390 hr/yr Levelized cost 0.325 $/kWh D-52 Generator 4 Generator 3 Quantity Value Units Hours of operation 3,303 hr/yr Number of starts 1,345 starts/yr Operational life 18.2 yr Capacity factor 11.8 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 47,198 kWh/yr Mean electrical output 14.3 kW Min. electrical output 13.7 kW Max. electrical output 21.7 kW Thermal production 31,626 kWh/yr Mean thermal output 9.57 kW Min. thermal output 9.33 kW Max. thermal output 12.9 kW Quantity Value Units Fuel consumption 19,405 L/yr Specific fuel consumption 0.411 L/kWh Fuel energy input 190,949 kWh/yr Mean electrical efficiency 24.7 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,859 hr/yr Number of starts 724 starts/yr Operational life 15.5 yr D-53 Generator 2 Capacity factor 21.8 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 156,253 kWh/yr Mean electrical output 40.5 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 72,689 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 49,457 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 486,658 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 79 hr/yr Number of starts 68 starts/yr Operational life 759 yr Capacity factor 0.638 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 6,319 kWh/yr Mean electrical output 80.0 kW Min. electrical output 74.7 kW Max. electrical output 93.1 kW Thermal production 3,107 kWh/yr Mean thermal output 39.3 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW D-54 Generator 1 Quantity Value Units Fuel consumption 2,077 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 20,441 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % D-55 Emissions Pollutant Emissions (kg/yr) Carbon dioxide 251,440 Carbon monoxide 462 Unburned hydocarbons 51.1 Particulate matter 34.8 Sulfur dioxide 507 Nitrogen oxides 4,118 D-56 www.knightpiesold.com Appendix E Enercon E33 Economics Table of Contents Site Number Height Diesel Price US$/gal Page Number 1 37 m 4.25 E-1 1 37 m 5.50 E-8 1 37 m 6.92 E-15 1 37 m 8.30 E-22 2 37 m 4.25 E-29 2 37 m 5.50 E-36 2 37 m 6.92 E-43 2 37 m 8.30 E-50 DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,566,541 Levelized cost of energy $ 0.427/kWh Operating cost $ 96,607/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,115,894 0 127,636 0 0 2,243,530 Generator 4 0 0 29,356 157,605 -7,080 179,881 Generator 3 0 0 45,536 515,172 -3,348 557,360 Generator 2 0 0 2,571 57,388 -21,281 38,679 Generator 1 0 0 113 3,223 -21,409 -18,074 Boiler 0 0 0 221,675 0 221,675 Other 0 0 343,490 0 0 343,490 System 2,115,894 0 548,702 955,063 -53,119 3,566,540 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 140,910 0 8,500 0 0 149,410 Generator 4 0 0 1,955 10,496 -471 11,979 Generator 3 0 0 3,032 34,308 -223 37,118 Generator 2 0 0 171 3,822 -1,417 2,576 Generator 1 0 0 7 215 -1,426 -1,204 Boiler 0 0 0 14,763 0 14,763 Other 0 0 22,875 0 0 22,875 System 140,910 0 36,541 63,603 -3,537 237,517 Component Production Fraction (kWh/yr) Wind turbine 1,209,569 90% Generator 4 22,940 2% Generator 3 96,584 7% Generator 2 10,060 1% Generator 1 586 0% Total 1,339,739 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 919,988 kWh/yr Unmet load 0.00105 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.798 Component Production Fraction (kWh/yr) Generator 4 15,241 1% Generator 3 45,064 4% Generator 2 5,174 0% Generator 1 286 0% Boiler 110,245 10% Excess electricity 919,988 84% Total 1,095,998 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 659,824 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 138 kW Capacity factor 41.8 % Total production 1,209,569 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 288 % Hours of operation 7,924 hr/yr Levelized cost 0.124 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,564 hr/yr Number of starts 809 starts/yr Operational life 38.4 yr Capacity factor 5.72 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 22,940 kWh/yr Mean electrical output 14.7 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 15,241 kWh/yr Mean thermal output 9.74 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,371 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 92,213 kWh/yr Mean electrical efficiency 24.9 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,426 hr/yr Number of starts 614 starts/yr Operational life 24.7 yr Generator 2 Capacity factor 13.5 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 96,584 kWh/yr Mean electrical output 39.8 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 45,064 kWh/yr Mean thermal output 18.6 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 30,632 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 301,423 kWh/yr Mean electrical efficiency 32.0 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 137 hr/yr Number of starts 101 starts/yr Operational life 438 yr Capacity factor 1.02 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 10,060 kWh/yr Mean electrical output 73.4 kW Min. electrical output 62.0 kW Max. electrical output 93.1 kW Thermal production 5,174 kWh/yr Mean thermal output 37.8 kW Min. thermal output 35.0 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,412 L/yr Specific fuel consumption 0.339 L/kWh Fuel energy input 33,577 kWh/yr Mean electrical efficiency 30.0 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0495 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 586 kWh/yr Mean electrical output 97.6 kW Min. electrical output 90.0 kW Max. electrical output 109 kW Thermal production 286 kWh/yr Mean thermal output 47.7 kW Min. thermal output 45.2 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 192 L/yr Specific fuel consumption 0.327 L/kWh Fuel energy input 1,886 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.2 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 149,708 Carbon monoxide 283 Unburned hydocarbons 31.4 Particulate matter 21.4 Sulfur dioxide 302 Nitrogen oxides 2,529 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,847,859 Levelized cost of energy $ 0.430/kWh Operating cost $ 115,342/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,115,894 0 127,636 0 0 2,243,530 Generator 4 0 0 29,675 205,950 -6,996 228,630 Generator 3 0 0 46,005 675,235 -3,203 718,038 Generator 2 0 0 2,196 64,110 -21,430 44,877 Generator 1 0 0 94 3,519 -21,417 -17,804 Boiler 0 0 0 287,098 0 287,098 Other 0 0 343,490 0 0 343,490 System 2,115,894 0 549,096 1,235,913 -53,045 3,847,858 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 140,910 0 8,500 0 0 149,410 Generator 4 0 0 1,976 13,715 -466 15,226 Generator 3 0 0 3,064 44,968 -213 47,818 Generator 2 0 0 146 4,269 -1,427 2,989 Generator 1 0 0 6 234 -1,426 -1,186 Boiler 0 0 0 19,120 0 19,120 Other 0 0 22,875 0 0 22,875 System 140,910 0 36,567 82,307 -3,533 256,251 Component Production Fraction (kWh/yr) Wind turbine 1,209,569 90% Generator 4 23,143 2% Generator 3 97,809 7% Generator 2 8,735 1% Generator 1 496 0% Total 1,339,752 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 920,001 kWh/yr Unmet load 0.00105 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.798 Component Production Fraction (kWh/yr) Generator 4 15,386 1% Generator 3 45,617 4% Generator 2 4,453 0% Generator 1 241 0% Boiler 110,287 10% Excess electricity 920,001 84% Total 1,095,984 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 659,810 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 138 kW Capacity factor 41.8 % Total production 1,209,569 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 288 % Hours of operation 7,924 hr/yr Levelized cost 0.124 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,581 hr/yr Number of starts 824 starts/yr Operational life 38.0 yr Capacity factor 5.77 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 23,143 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 15,386 kWh/yr Mean thermal output 9.73 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,459 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 93,076 kWh/yr Mean electrical efficiency 24.9 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,451 hr/yr Number of starts 610 starts/yr Operational life 24.5 yr Generator 2 Capacity factor 13.6 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 97,809 kWh/yr Mean electrical output 39.9 kW Min. electrical output 24.6 kW Max. electrical output 76.3 kW Thermal production 45,617 kWh/yr Mean thermal output 18.6 kW Min. thermal output 12.7 kW Max. thermal output 32.6 kW Quantity Value Units Fuel consumption 31,012 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 305,161 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 117 hr/yr Number of starts 89 starts/yr Operational life 513 yr Capacity factor 0.882 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 8,735 kWh/yr Mean electrical output 74.7 kW Min. electrical output 67.5 kW Max. electrical output 93.1 kW Thermal production 4,453 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.3 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,944 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 28,974 kWh/yr Mean electrical efficiency 30.1 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 5 hr/yr Number of starts 5 starts/yr Operational life 12,000 yr Capacity factor 0.0419 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 496 kWh/yr Mean electrical output 99.1 kW Min. electrical output 92.5 kW Max. electrical output 109 kW Thermal production 241 kWh/yr Mean thermal output 48.2 kW Min. thermal output 46.0 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 162 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,590 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 149,642 Carbon monoxide 283 Unburned hydocarbons 31.4 Particulate matter 21.4 Sulfur dioxide 302 Nitrogen oxides 2,527 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,171,558 Levelized cost of energy $ 0.434/kWh Operating cost $ 136,899/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,115,894 0 127,636 0 0 2,243,530 Generator 4 0 0 30,482 266,415 -6,784 290,113 Generator 3 0 0 46,962 875,911 -2,905 919,969 Generator 2 0 0 1,370 51,674 -21,757 31,287 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 362,696 0 362,696 Other 0 0 343,490 0 0 343,490 System 2,115,894 0 549,978 1,558,569 -52,884 4,171,557 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 140,910 0 8,500 0 0 149,410 Generator 4 0 0 2,030 17,742 -452 19,320 Generator 3 0 0 3,127 58,332 -193 61,266 Generator 2 0 0 91 3,441 -1,449 2,084 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 24,154 0 24,154 Other 0 0 22,875 0 0 22,875 System 140,910 0 36,626 103,794 -3,522 277,808 Component Production Fraction (kWh/yr) Wind turbine 1,209,569 90% Generator 4 23,705 2% Generator 3 100,625 8% Generator 2 5,654 0% Generator 1 212 0% Total 1,339,765 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 920,014 kWh/yr Unmet load 0.00106 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.798 Component Production Fraction (kWh/yr) Generator 4 15,773 1% Generator 3 46,866 4% Generator 2 2,827 0% Generator 1 101 0% Boiler 110,396 10% Excess electricity 920,014 84% Total 1,095,977 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 659,803 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 138 kW Capacity factor 41.8 % Total production 1,209,569 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 288 % Hours of operation 7,924 hr/yr Levelized cost 0.124 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,624 hr/yr Number of starts 859 starts/yr Operational life 36.9 yr Capacity factor 5.91 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 23,705 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 15,773 kWh/yr Mean thermal output 9.71 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,695 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 95,400 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,502 hr/yr Number of starts 579 starts/yr Operational life 24.0 yr Generator 2 Capacity factor 14.0 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 100,625 kWh/yr Mean electrical output 40.2 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 46,866 kWh/yr Mean thermal output 18.7 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 31,875 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 313,654 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 73 hr/yr Number of starts 54 starts/yr Operational life 822 yr Capacity factor 0.571 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 5,654 kWh/yr Mean electrical output 77.5 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 2,827 kWh/yr Mean thermal output 38.7 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,880 L/yr Specific fuel consumption 0.333 L/kWh Fuel energy input 18,504 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.8 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 149,523 Carbon monoxide 283 Unburned hydocarbons 31.3 Particulate matter 21.3 Sulfur dioxide 302 Nitrogen oxides 2,524 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,478,065 Levelized cost of energy $ 0.438/kWh Operating cost $ 157,311/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,115,894 0 127,636 0 0 2,243,530 Generator 4 0 0 30,933 323,025 -6,666 347,292 Generator 3 0 0 47,563 1,066,057 -2,718 1,110,902 Generator 2 0 0 845 38,906 -21,965 17,786 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 434,223 0 434,223 Other 0 0 343,490 0 0 343,490 System 2,115,894 0 550,504 1,864,452 -52,787 4,478,063 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 140,910 0 8,500 0 0 149,410 Generator 4 0 0 2,060 21,512 -444 23,128 Generator 3 0 0 3,167 70,995 -181 73,981 Generator 2 0 0 56 2,591 -1,463 1,184 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 28,917 0 28,917 Other 0 0 22,875 0 0 22,875 System 140,910 0 36,661 124,165 -3,515 298,220 Component Production Fraction (kWh/yr) Wind turbine 1,209,569 90% Generator 4 24,005 2% Generator 3 102,395 8% Generator 2 3,598 0% Generator 1 212 0% Total 1,339,779 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 920,028 kWh/yr Unmet load 0.00109 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.798 Component Production Fraction (kWh/yr) Generator 4 15,984 1% Generator 3 47,651 4% Generator 2 1,769 0% Generator 1 101 0% Boiler 110,441 10% Excess electricity 920,028 84% Total 1,095,974 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 659,800 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 138 kW Capacity factor 41.8 % Total production 1,209,569 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 288 % Hours of operation 7,924 hr/yr Levelized cost 0.124 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,648 hr/yr Number of starts 877 starts/yr Operational life 36.4 yr Capacity factor 5.98 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 24,005 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,984 kWh/yr Mean thermal output 9.70 kW Min. thermal output 9.33 kW Max. thermal output 12.6 kW Quantity Value Units Fuel consumption 9,823 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 96,657 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,534 hr/yr Number of starts 566 starts/yr Operational life 23.7 yr Generator 2 Capacity factor 14.3 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 102,395 kWh/yr Mean electrical output 40.4 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 47,651 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 32,418 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 318,991 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 45 hr/yr Number of starts 37 starts/yr Operational life 1,333 yr Capacity factor 0.364 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 3,598 kWh/yr Mean electrical output 80.0 kW Min. electrical output 74.8 kW Max. electrical output 93.1 kW Thermal production 1,769 kWh/yr Mean thermal output 39.3 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,183 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 11,642 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 149,465 Carbon monoxide 283 Unburned hydocarbons 31.3 Particulate matter 21.3 Sulfur dioxide 301 Nitrogen oxides 2,523 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,758,595 Levelized cost of energy $ 0.457/kWh Operating cost $ 94,946/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,332,894 0 127,636 0 0 2,460,530 Generator 4 0 0 28,849 154,735 -7,213 176,371 Generator 3 0 0 44,466 502,828 -3,681 543,613 Generator 2 0 0 2,496 55,887 -21,311 37,073 Generator 1 0 0 75 2,202 -21,424 -19,146 Boiler 0 0 0 216,664 0 216,664 Other 0 0 343,490 0 0 343,490 System 2,332,894 0 547,012 932,316 -53,628 3,758,594 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 155,361 0 8,500 0 0 163,861 Generator 4 0 0 1,921 10,305 -480 11,746 Generator 3 0 0 2,961 33,486 -245 36,202 Generator 2 0 0 166 3,722 -1,419 2,469 Generator 1 0 0 5 147 -1,427 -1,275 Boiler 0 0 0 14,429 0 14,429 Other 0 0 22,875 0 0 22,875 System 155,361 0 36,429 62,088 -3,571 250,307 Component Production Fraction (kWh/yr) Wind turbine 1,241,941 91% Generator 4 22,515 2% Generator 3 94,264 7% Generator 2 9,816 1% Generator 1 403 0% Total 1,368,939 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 949,184 kWh/yr Unmet load 0.000681 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.806 Component Production Fraction (kWh/yr) Generator 4 14,965 1% Generator 3 43,986 4% Generator 2 5,034 0% Generator 1 195 0% Boiler 107,753 10% Excess electricity 949,184 85% Total 1,121,117 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 684,943 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 142 kW Capacity factor 43.0 % Total production 1,241,941 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 296 % Hours of operation 7,959 hr/yr Levelized cost 0.132 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,537 hr/yr Number of starts 809 starts/yr Operational life 39.0 yr Capacity factor 5.61 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 22,515 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.4 kW Thermal production 14,965 kWh/yr Mean thermal output 9.74 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,201 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 90,534 kWh/yr Mean electrical efficiency 24.9 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,369 hr/yr Number of starts 608 starts/yr Operational life 25.3 yr Generator 2 Capacity factor 13.1 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 94,264 kWh/yr Mean electrical output 39.8 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 43,986 kWh/yr Mean thermal output 18.6 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 29,898 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 294,201 kWh/yr Mean electrical efficiency 32.0 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 133 hr/yr Number of starts 99 starts/yr Operational life 451 yr Capacity factor 0.992 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 9,816 kWh/yr Mean electrical output 73.8 kW Min. electrical output 63.1 kW Max. electrical output 93.1 kW Thermal production 5,034 kWh/yr Mean thermal output 37.9 kW Min. thermal output 35.3 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,323 L/yr Specific fuel consumption 0.339 L/kWh Fuel energy input 32,699 kWh/yr Mean electrical efficiency 30.0 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 4 hr/yr Number of starts 4 starts/yr Operational life 15,000 yr Capacity factor 0.0341 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 403 kWh/yr Mean electrical output 101 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 195 kWh/yr Mean thermal output 48.7 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 131 L/yr Specific fuel consumption 0.325 L/kWh Fuel energy input 1,289 kWh/yr Mean electrical efficiency 31.3 % Mean total efficiency 46.4 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 146,143 Carbon monoxide 277 Unburned hydocarbons 30.6 Particulate matter 20.9 Sulfur dioxide 295 Nitrogen oxides 2,468 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,033,228 Levelized cost of energy $ 0.460/kWh Operating cost $ 113,235/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,332,894 0 127,636 0 0 2,460,530 Generator 4 0 0 29,075 201,613 -7,154 223,533 Generator 3 0 0 44,841 657,387 -3,564 698,664 Generator 2 0 0 2,196 64,175 -21,430 44,941 Generator 1 0 0 75 2,851 -21,424 -18,497 Boiler 0 0 0 280,567 0 280,567 Other 0 0 343,490 0 0 343,490 System 2,332,894 0 547,313 1,206,593 -53,571 4,033,228 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 155,361 0 8,500 0 0 163,861 Generator 4 0 0 1,936 13,427 -476 14,886 Generator 3 0 0 2,986 43,779 -237 46,528 Generator 2 0 0 146 4,274 -1,427 2,993 Generator 1 0 0 5 190 -1,427 -1,232 Boiler 0 0 0 18,685 0 18,685 Other 0 0 22,875 0 0 22,875 System 155,361 0 36,449 80,354 -3,568 268,596 Component Production Fraction (kWh/yr) Wind turbine 1,241,941 91% Generator 4 22,650 2% Generator 3 95,209 7% Generator 2 8,749 1% Generator 1 403 0% Total 1,368,952 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 949,197 kWh/yr Unmet load 0.000704 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.806 Component Production Fraction (kWh/yr) Generator 4 15,063 1% Generator 3 44,415 4% Generator 2 4,456 0% Generator 1 195 0% Boiler 107,778 10% Excess electricity 949,197 85% Total 1,121,104 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 684,930 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 142 kW Capacity factor 43.0 % Total production 1,241,941 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 296 % Hours of operation 7,959 hr/yr Levelized cost 0.132 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,549 hr/yr Number of starts 820 starts/yr Operational life 38.7 yr Capacity factor 5.65 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 22,650 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 15,063 kWh/yr Mean thermal output 9.72 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,260 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 91,115 kWh/yr Mean electrical efficiency 24.9 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,389 hr/yr Number of starts 602 starts/yr Operational life 25.1 yr Generator 2 Capacity factor 13.3 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 95,209 kWh/yr Mean electrical output 39.9 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 44,415 kWh/yr Mean thermal output 18.6 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 30,193 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 297,095 kWh/yr Mean electrical efficiency 32.0 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 117 hr/yr Number of starts 89 starts/yr Operational life 513 yr Capacity factor 0.884 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 8,749 kWh/yr Mean electrical output 74.8 kW Min. electrical output 67.7 kW Max. electrical output 93.1 kW Thermal production 4,456 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,947 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 29,003 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 4 hr/yr Number of starts 4 starts/yr Operational life 15,000 yr Capacity factor 0.0341 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 403 kWh/yr Mean electrical output 101 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 195 kWh/yr Mean thermal output 48.7 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 131 L/yr Specific fuel consumption 0.325 L/kWh Fuel energy input 1,289 kWh/yr Mean electrical efficiency 31.3 % Mean total efficiency 46.4 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 146,092 Carbon monoxide 276 Unburned hydocarbons 30.6 Particulate matter 20.8 Sulfur dioxide 295 Nitrogen oxides 2,467 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,349,244 Levelized cost of energy $ 0.463/kWh Operating cost $ 134,280/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,332,894 0 127,636 0 0 2,460,530 Generator 4 0 0 29,863 260,783 -6,947 283,700 Generator 3 0 0 45,780 852,666 -3,273 895,173 Generator 2 0 0 1,370 51,812 -21,757 31,426 Generator 1 0 0 38 1,872 -21,438 -19,529 Boiler 0 0 0 354,454 0 354,454 Other 0 0 343,490 0 0 343,490 System 2,332,894 0 548,176 1,521,587 -53,414 4,349,244 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 155,361 0 8,500 0 0 163,861 Generator 4 0 0 1,989 17,367 -463 18,893 Generator 3 0 0 3,049 56,784 -218 59,615 Generator 2 0 0 91 3,450 -1,449 2,093 Generator 1 0 0 2 125 -1,428 -1,301 Boiler 0 0 0 23,605 0 23,605 Other 0 0 22,875 0 0 22,875 System 155,361 0 36,506 101,331 -3,557 289,641 Component Production Fraction (kWh/yr) Wind turbine 1,241,941 91% Generator 4 23,197 2% Generator 3 97,936 7% Generator 2 5,678 0% Generator 1 212 0% Total 1,368,965 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 949,211 kWh/yr Unmet load 0.000750 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.806 Component Production Fraction (kWh/yr) Generator 4 15,441 1% Generator 3 45,626 4% Generator 2 2,833 0% Generator 1 101 0% Boiler 107,887 10% Excess electricity 949,211 85% Total 1,121,099 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 684,925 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 142 kW Capacity factor 43.0 % Total production 1,241,941 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 296 % Hours of operation 7,959 hr/yr Levelized cost 0.132 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,591 hr/yr Number of starts 858 starts/yr Operational life 37.7 yr Capacity factor 5.78 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 23,197 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 15,441 kWh/yr Mean thermal output 9.71 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,490 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 93,384 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,439 hr/yr Number of starts 573 starts/yr Operational life 24.6 yr Generator 2 Capacity factor 13.7 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 97,936 kWh/yr Mean electrical output 40.2 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 45,626 kWh/yr Mean thermal output 18.7 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 31,030 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 305,330 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 73 hr/yr Number of starts 54 starts/yr Operational life 822 yr Capacity factor 0.574 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 5,678 kWh/yr Mean electrical output 77.8 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 2,833 kWh/yr Mean thermal output 38.8 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,886 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 18,553 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.3 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.1 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 670 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 145,975 Carbon monoxide 276 Unburned hydocarbons 30.6 Particulate matter 20.8 Sulfur dioxide 294 Nitrogen oxides 2,463 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Enercon E33 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,648,473 Levelized cost of energy $ 0.465/kWh Operating cost $ 154,208/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Enercon E33 2,332,894 0 127,636 0 0 2,460,530 Generator 4 0 0 30,370 317,070 -6,814 340,626 Generator 3 0 0 46,362 1,038,479 -3,092 1,081,749 Generator 2 0 0 845 39,079 -21,965 17,959 Generator 1 0 0 19 1,148 -21,445 -20,278 Boiler 0 0 0 424,396 0 424,396 Other 0 0 343,490 0 0 343,490 System 2,332,894 0 548,721 1,820,173 -53,315 4,648,472 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Enercon E33 155,361 0 8,500 0 0 163,861 Generator 4 0 0 2,022 21,116 -454 22,684 Generator 3 0 0 3,087 69,158 -206 72,040 Generator 2 0 0 56 2,603 -1,463 1,196 Generator 1 0 0 1 76 -1,428 -1,350 Boiler 0 0 0 28,263 0 28,263 Other 0 0 22,875 0 0 22,875 System 155,361 0 36,542 121,216 -3,551 309,569 Component Production Fraction (kWh/yr) Wind turbine 1,241,941 91% Generator 4 23,561 2% Generator 3 99,737 7% Generator 2 3,623 0% Generator 1 109 0% Total 1,368,972 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Enercon E33 Excess electricity 949,218 kWh/yr Unmet load 0.000765 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.806 Component Production Fraction (kWh/yr) Generator 4 15,690 1% Generator 3 46,420 4% Generator 2 1,775 0% Generator 1 52 0% Boiler 107,941 10% Excess electricity 949,218 85% Total 1,121,096 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 684,922 kWh/yr Variable Value Units Total rated capacity 330 kW Mean output 142 kW Capacity factor 43.0 % Total production 1,241,941 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 334 kW Wind penetration 296 % Hours of operation 7,959 hr/yr Levelized cost 0.132 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,618 hr/yr Number of starts 879 starts/yr Operational life 37.1 yr Capacity factor 5.87 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 23,561 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,690 kWh/yr Mean thermal output 9.70 kW Min. thermal output 9.33 kW Max. thermal output 12.6 kW Quantity Value Units Fuel consumption 9,642 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 94,875 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,470 hr/yr Number of starts 559 starts/yr Operational life 24.3 yr Generator 2 Capacity factor 13.9 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 99,737 kWh/yr Mean electrical output 40.4 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 46,420 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 31,579 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 310,739 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 45 hr/yr Number of starts 39 starts/yr Operational life 1,333 yr Capacity factor 0.366 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 3,623 kWh/yr Mean electrical output 80.5 kW Min. electrical output 74.9 kW Max. electrical output 93.1 kW Thermal production 1,775 kWh/yr Mean thermal output 39.5 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,188 L/yr Specific fuel consumption 0.328 L/kWh Fuel energy input 11,694 kWh/yr Mean electrical efficiency 31.0 % Mean total efficiency 46.2 % Quantity Value Units Hours of operation 1 hr/yr Number of starts 1 starts/yr Operational life 60,000 yr Capacity factor 0.00925 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 109 kWh/yr Mean electrical output 109 kW Min. electrical output 109 kW Max. electrical output 109 kW Thermal production 51.5 kWh/yr Mean thermal output 51.5 kW Min. thermal output 51.5 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 34.9 L/yr Specific fuel consumption 0.319 L/kWh Fuel energy input 344 kWh/yr Mean electrical efficiency 31.8 % Mean total efficiency 46.8 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 145,916 Carbon monoxide 276 Unburned hydocarbons 30.6 Particulate matter 20.8 Sulfur dioxide 294 Nitrogen oxides 2,462 www.knightpiesold.com Appendix F Vergnet GEV-MP-C Economics Table of Contents Site Number Height Diesel Price US$/gal Page Number 1 37 m 4.25 F-1 1 37 m 5.50 F-8 1 37 m 6.92 F-15 1 37 m 8.30 F-22 2 37 m 4.25 F-29 2 37 m 5.50 F-36 2 37 m 6.92 F-43 2 37 m 8.30 F-50 DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,574,787 Levelized cost of energy $ 0.428/kWh Operating cost $ 110,359/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 1,917,642 0 127,636 0 0 2,045,278 Generator 4 0 0 28,380 151,482 -7,336 172,526 Generator 3 0 0 56,178 654,739 -41 710,876 Generator 2 0 0 3,754 84,412 -20,813 67,353 Generator 1 0 0 113 3,277 -21,409 -18,020 Boiler 0 0 0 253,284 0 253,284 Other 0 0 343,490 0 0 343,490 System 1,917,642 0 559,551 1,147,193 -49,599 3,574,787 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 127,707 0 8,500 0 0 136,207 Generator 4 0 0 1,890 10,088 -489 11,490 Generator 3 0 0 3,741 43,603 -3 47,341 Generator 2 0 0 250 5,621 -1,386 4,485 Generator 1 0 0 7 218 -1,426 -1,200 Boiler 0 0 0 16,868 0 16,868 Other 0 0 22,875 0 0 22,875 System 127,707 0 37,264 76,398 -3,303 238,066 Component Production Fraction (kWh/yr) Wind turbine 932,631 85% Generator 4 22,007 2% Generator 3 123,240 11% Generator 2 14,864 1% Generator 1 598 0% Total 1,093,341 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 673,596 kWh/yr Unmet load 0.00103 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.718 Component Production Fraction (kWh/yr) Generator 4 14,658 2% Generator 3 57,165 7% Generator 2 7,595 1% Generator 1 290 0% Boiler 125,965 14% Excess electricity 673,596 77% Total 879,269 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 443,095 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 106 kW Capacity factor 38.7 % Total production 932,631 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 222 % Hours of operation 7,275 hr/yr Levelized cost 0.146 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,512 hr/yr Number of starts 797 starts/yr Operational life 39.7 yr Capacity factor 5.49 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 22,007 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.4 kW Thermal production 14,658 kWh/yr Mean thermal output 9.69 kW Min. thermal output 9.33 kW Max. thermal output 12.8 kW Quantity Value Units Fuel consumption 9,007 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 88,631 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,993 hr/yr Number of starts 693 starts/yr Operational life 20.0 yr Generator 2 Capacity factor 17.2 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 123,240 kWh/yr Mean electrical output 41.2 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 57,165 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 38,931 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 383,082 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 200 hr/yr Number of starts 150 starts/yr Operational life 300 yr Capacity factor 1.50 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 14,864 kWh/yr Mean electrical output 74.3 kW Min. electrical output 62.0 kW Max. electrical output 93.1 kW Thermal production 7,595 kWh/yr Mean thermal output 38.0 kW Min. thermal output 35.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 5,019 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 49,389 kWh/yr Mean electrical efficiency 30.1 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0506 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 598 kWh/yr Mean electrical output 99.7 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 290 kWh/yr Mean thermal output 48.4 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 195 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,917 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 179,815 Carbon monoxide 345 Unburned hydocarbons 38.3 Particulate matter 26 Sulfur dioxide 363 Nitrogen oxides 3,083 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,912,785 Levelized cost of energy $ 0.441/kWh Operating cost $ 132,868/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 1,917,642 0 127,636 0 0 2,045,278 Generator 4 0 0 28,605 197,146 -7,277 218,474 Generator 3 0 17,577 56,742 856,632 -17,366 913,584 Generator 2 0 0 3,360 98,631 -20,969 81,022 Generator 1 0 0 113 4,242 -21,409 -17,054 Boiler 0 0 0 327,990 0 327,990 Other 0 0 343,490 0 0 343,490 System 1,917,642 17,577 559,945 1,484,642 -67,022 3,912,785 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 127,707 0 8,500 0 0 136,207 Generator 4 0 0 1,905 13,129 -485 14,549 Generator 3 0 1,171 3,779 57,048 -1,157 60,841 Generator 2 0 0 224 6,568 -1,396 5,396 Generator 1 0 0 7 283 -1,426 -1,136 Boiler 0 0 0 21,843 0 21,843 Other 0 0 22,875 0 0 22,875 System 127,707 1,171 37,290 98,871 -4,463 260,575 Component Production Fraction (kWh/yr) Wind turbine 932,631 85% Generator 4 22,104 2% Generator 3 124,555 11% Generator 2 13,482 1% Generator 1 598 0% Total 1,093,370 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 673,625 kWh/yr Unmet load 0.00104 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.718 Component Production Fraction (kWh/yr) Generator 4 14,739 2% Generator 3 57,769 7% Generator 2 6,840 1% Generator 1 290 0% Boiler 125,995 14% Excess electricity 673,625 77% Total 879,258 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 443,084 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 106 kW Capacity factor 38.7 % Total production 932,631 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 222 % Hours of operation 7,275 hr/yr Levelized cost 0.146 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,524 hr/yr Number of starts 810 starts/yr Operational life 39.4 yr Capacity factor 5.51 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 22,104 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 14,739 kWh/yr Mean thermal output 9.67 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,055 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 89,097 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,023 hr/yr Number of starts 675 starts/yr Operational life 19.8 yr Generator 2 Capacity factor 17.4 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 124,555 kWh/yr Mean electrical output 41.2 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 57,769 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 39,344 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 387,141 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 179 hr/yr Number of starts 131 starts/yr Operational life 335 yr Capacity factor 1.36 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 13,482 kWh/yr Mean electrical output 75.3 kW Min. electrical output 67.4 kW Max. electrical output 93.1 kW Thermal production 6,840 kWh/yr Mean thermal output 38.2 kW Min. thermal output 36.3 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,530 L/yr Specific fuel consumption 0.336 L/kWh Fuel energy input 44,575 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.6 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0506 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 598 kWh/yr Mean electrical output 99.7 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 290 kWh/yr Mean thermal output 48.4 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 195 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,917 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 179,747 Carbon monoxide 345 Unburned hydocarbons 38.2 Particulate matter 26 Sulfur dioxide 362 Nitrogen oxides 3,081 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,301,831 Levelized cost of energy $ 0.455/kWh Operating cost $ 158,777/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 1,917,642 0 127,636 0 0 2,045,278 Generator 4 0 0 29,938 259,916 -6,927 282,927 Generator 3 0 17,814 58,112 1,116,292 -16,941 1,175,276 Generator 2 0 0 2,083 79,229 -21,474 59,838 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 414,548 0 414,548 Other 0 0 343,490 0 0 343,490 System 1,917,642 17,814 561,296 1,871,858 -66,780 4,301,830 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 127,707 0 8,500 0 0 136,207 Generator 4 0 0 1,994 17,309 -461 18,842 Generator 3 0 1,186 3,870 74,340 -1,128 78,268 Generator 2 0 0 139 5,276 -1,430 3,985 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 27,607 0 27,607 Other 0 0 22,875 0 0 22,875 System 127,707 1,186 37,380 124,658 -4,447 286,484 Component Production Fraction (kWh/yr) Wind turbine 932,631 85% Generator 4 23,076 2% Generator 3 128,743 12% Generator 2 8,711 1% Generator 1 212 0% Total 1,093,374 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 673,628 kWh/yr Unmet load 0.00113 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.718 Component Production Fraction (kWh/yr) Generator 4 15,400 2% Generator 3 59,617 7% Generator 2 4,325 0% Generator 1 101 0% Boiler 126,178 14% Excess electricity 673,628 77% Total 879,250 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 443,076 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 106 kW Capacity factor 38.7 % Total production 932,631 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 222 % Hours of operation 7,275 hr/yr Levelized cost 0.146 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,595 hr/yr Number of starts 867 starts/yr Operational life 37.6 yr Capacity factor 5.75 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 23,076 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 15,400 kWh/yr Mean thermal output 9.65 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,459 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 93,073 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,096 hr/yr Number of starts 644 starts/yr Operational life 19.4 yr Generator 2 Capacity factor 17.9 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 128,743 kWh/yr Mean electrical output 41.6 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 59,617 kWh/yr Mean thermal output 19.3 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 40,623 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 399,732 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 111 hr/yr Number of starts 85 starts/yr Operational life 541 yr Capacity factor 0.880 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 8,711 kWh/yr Mean electrical output 78.5 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 4,325 kWh/yr Mean thermal output 39.0 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,883 L/yr Specific fuel consumption 0.331 L/kWh Fuel energy input 28,371 kWh/yr Mean electrical efficiency 30.7 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 179,569 Carbon monoxide 345 Unburned hydocarbons 38.2 Particulate matter 26 Sulfur dioxide 362 Nitrogen oxides 3,076 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,670,060 Levelized cost of energy $ 0.469/kWh Operating cost $ 183,299/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 1,917,642 0 127,636 0 0 2,045,278 Generator 4 0 0 30,389 315,324 -6,809 338,904 Generator 3 0 17,909 58,675 1,352,784 -16,766 1,412,602 Generator 2 0 0 1,577 72,752 -21,675 52,654 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 496,291 0 496,291 Other 0 0 343,490 0 0 343,490 System 1,917,642 17,909 561,803 2,239,393 -66,687 4,670,059 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 127,707 0 8,500 0 0 136,207 Generator 4 0 0 2,024 20,999 -453 22,570 Generator 3 0 1,193 3,907 90,090 -1,117 94,073 Generator 2 0 0 105 4,845 -1,443 3,507 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 33,051 0 33,051 Other 0 0 22,875 0 0 22,875 System 127,707 1,193 37,414 149,134 -4,441 311,006 Component Production Fraction (kWh/yr) Wind turbine 932,631 85% Generator 4 23,384 2% Generator 3 130,421 12% Generator 2 6,736 1% Generator 1 212 0% Total 1,093,384 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 673,638 kWh/yr Unmet load 0.00113 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.718 Component Production Fraction (kWh/yr) Generator 4 15,614 2% Generator 3 60,360 7% Generator 2 3,307 0% Generator 1 101 0% Boiler 126,227 14% Excess electricity 673,638 77% Total 879,248 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 443,074 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 106 kW Capacity factor 38.7 % Total production 932,631 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 222 % Hours of operation 7,275 hr/yr Levelized cost 0.146 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,619 hr/yr Number of starts 886 starts/yr Operational life 37.1 yr Capacity factor 5.83 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 23,384 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,614 kWh/yr Mean thermal output 9.64 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,589 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 94,353 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,126 hr/yr Number of starts 635 starts/yr Operational life 19.2 yr Generator 2 Capacity factor 18.2 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 130,421 kWh/yr Mean electrical output 41.7 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 60,360 kWh/yr Mean thermal output 19.3 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 41,137 L/yr Specific fuel consumption 0.315 L/kWh Fuel energy input 404,787 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 84 hr/yr Number of starts 69 starts/yr Operational life 714 yr Capacity factor 0.680 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 6,736 kWh/yr Mean electrical output 80.2 kW Min. electrical output 74.7 kW Max. electrical output 93.1 kW Thermal production 3,307 kWh/yr Mean thermal output 39.4 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,212 L/yr Specific fuel consumption 0.328 L/kWh Fuel energy input 21,769 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 179,513 Carbon monoxide 345 Unburned hydocarbons 38.2 Particulate matter 26 Sulfur dioxide 362 Nitrogen oxides 3,074 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,771,259 Levelized cost of energy $ 0.459/kWh Operating cost $ 108,992/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 2,134,642 0 127,636 0 0 2,262,278 Generator 4 0 0 28,099 150,393 -7,410 171,082 Generator 3 0 0 54,921 641,669 -432 696,158 Generator 2 0 0 3,716 83,612 -20,827 66,501 Generator 1 0 0 113 3,276 -21,409 -18,021 Boiler 0 0 0 249,771 0 249,771 Other 0 0 343,490 0 0 343,490 System 2,134,642 0 557,974 1,128,721 -50,079 3,771,258 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 142,158 0 8,500 0 0 150,658 Generator 4 0 0 1,871 10,016 -493 11,393 Generator 3 0 0 3,657 42,732 -29 46,361 Generator 2 0 0 247 5,568 -1,387 4,429 Generator 1 0 0 7 218 -1,426 -1,200 Boiler 0 0 0 16,634 0 16,634 Other 0 0 22,875 0 0 22,875 System 142,158 0 37,159 75,168 -3,335 251,150 Component Production Fraction (kWh/yr) Wind turbine 956,482 86% Generator 4 21,869 2% Generator 3 120,819 11% Generator 2 14,728 1% Generator 1 598 0% Total 1,114,497 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 694,752 kWh/yr Unmet load 0.000965 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.726 Component Production Fraction (kWh/yr) Generator 4 14,548 2% Generator 3 56,015 6% Generator 2 7,522 1% Generator 1 290 0% Boiler 124,218 14% Excess electricity 694,752 77% Total 897,346 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 461,172 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 109 kW Capacity factor 39.7 % Total production 956,482 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 228 % Hours of operation 7,295 hr/yr Levelized cost 0.158 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,497 hr/yr Number of starts 809 starts/yr Operational life 40.1 yr Capacity factor 5.45 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 21,869 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 14,548 kWh/yr Mean thermal output 9.72 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 8,942 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 87,994 kWh/yr Mean electrical efficiency 24.9 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,926 hr/yr Number of starts 700 starts/yr Operational life 20.5 yr Generator 2 Capacity factor 16.8 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 120,819 kWh/yr Mean electrical output 41.3 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 56,015 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 38,154 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 375,435 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 198 hr/yr Number of starts 148 starts/yr Operational life 303 yr Capacity factor 1.49 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 14,728 kWh/yr Mean electrical output 74.4 kW Min. electrical output 61.5 kW Max. electrical output 93.1 kW Thermal production 7,522 kWh/yr Mean thermal output 38.0 kW Min. thermal output 34.9 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,972 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 48,921 kWh/yr Mean electrical efficiency 30.1 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0506 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 598 kWh/yr Mean electrical output 99.7 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 290 kWh/yr Mean thermal output 48.3 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 195 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,917 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 176,921 Carbon monoxide 340 Unburned hydocarbons 37.6 Particulate matter 25.6 Sulfur dioxide 357 Nitrogen oxides 3,031 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,103,746 Levelized cost of energy $ 0.471/kWh Operating cost $ 131,134/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 2,134,642 0 127,636 0 0 2,262,278 Generator 4 0 0 28,343 196,112 -7,346 217,108 Generator 3 0 0 55,315 837,365 -309 892,371 Generator 2 0 0 3,397 99,654 -20,954 82,097 Generator 1 0 0 113 4,241 -21,409 -17,056 Boiler 0 0 0 323,456 0 323,456 Other 0 0 343,490 0 0 343,490 System 2,134,642 0 558,293 1,460,828 -50,019 4,103,744 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 142,158 0 8,500 0 0 150,658 Generator 4 0 0 1,887 13,060 -489 14,458 Generator 3 0 0 3,684 55,765 -21 59,428 Generator 2 0 0 226 6,637 -1,395 5,467 Generator 1 0 0 7 282 -1,426 -1,136 Boiler 0 0 0 21,541 0 21,541 Other 0 0 22,875 0 0 22,875 System 142,158 0 37,180 97,285 -3,331 273,292 Component Production Fraction (kWh/yr) Wind turbine 956,482 86% Generator 4 22,016 2% Generator 3 121,797 11% Generator 2 13,615 1% Generator 1 598 0% Total 1,114,509 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 694,765 kWh/yr Unmet load 0.000963 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.726 Component Production Fraction (kWh/yr) Generator 4 14,655 2% Generator 3 56,460 6% Generator 2 6,913 1% Generator 1 290 0% Boiler 124,254 14% Excess electricity 694,765 77% Total 897,336 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 461,162 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 109 kW Capacity factor 39.7 % Total production 956,482 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 228 % Hours of operation 7,295 hr/yr Levelized cost 0.158 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,510 hr/yr Number of starts 821 starts/yr Operational life 39.7 yr Capacity factor 5.49 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 22,016 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 14,655 kWh/yr Mean thermal output 9.71 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 9,007 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 88,629 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 2,947 hr/yr Number of starts 689 starts/yr Operational life 20.4 yr Generator 2 Capacity factor 17.0 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 121,797 kWh/yr Mean electrical output 41.3 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 56,460 kWh/yr Mean thermal output 19.2 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 38,459 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 378,433 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 181 hr/yr Number of starts 133 starts/yr Operational life 331 yr Capacity factor 1.38 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 13,615 kWh/yr Mean electrical output 75.2 kW Min. electrical output 67.7 kW Max. electrical output 93.1 kW Thermal production 6,913 kWh/yr Mean thermal output 38.2 kW Min. thermal output 36.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,577 L/yr Specific fuel consumption 0.336 L/kWh Fuel energy input 45,037 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.6 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0506 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 598 kWh/yr Mean electrical output 99.7 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 290 kWh/yr Mean thermal output 48.3 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 195 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,917 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 176,865 Carbon monoxide 340 Unburned hydocarbons 37.6 Particulate matter 25.6 Sulfur dioxide 357 Nitrogen oxides 3,030 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,486,374 Levelized cost of energy $ 0.484/kWh Operating cost $ 156,615/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 2,134,642 0 127,636 0 0 2,262,278 Generator 4 0 0 29,600 257,855 -7,016 280,439 Generator 3 0 17,567 56,685 1,091,420 -17,384 1,148,288 Generator 2 0 0 2,159 81,901 -21,444 62,615 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 408,790 0 408,790 Other 0 0 343,490 0 0 343,490 System 2,134,642 17,567 559,607 1,841,839 -67,282 4,486,372 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 142,158 0 8,500 0 0 150,658 Generator 4 0 0 1,971 17,172 -467 18,676 Generator 3 0 1,170 3,775 72,684 -1,158 76,471 Generator 2 0 0 144 5,454 -1,428 4,170 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 27,224 0 27,224 Other 0 0 22,875 0 0 22,875 System 142,158 1,170 37,267 122,659 -4,481 298,774 Component Production Fraction (kWh/yr) Wind turbine 956,482 86% Generator 4 22,919 2% Generator 3 125,913 11% Generator 2 8,993 1% Generator 1 212 0% Total 1,114,519 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 694,775 kWh/yr Unmet load 0.00100 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.726 Component Production Fraction (kWh/yr) Generator 4 15,272 2% Generator 3 58,281 6% Generator 2 4,474 0% Generator 1 101 0% Boiler 124,426 14% Excess electricity 694,775 77% Total 897,328 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 461,154 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 109 kW Capacity factor 39.7 % Total production 956,482 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 228 % Hours of operation 7,295 hr/yr Levelized cost 0.158 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,577 hr/yr Number of starts 875 starts/yr Operational life 38.0 yr Capacity factor 5.71 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 22,919 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 15,272 kWh/yr Mean thermal output 9.68 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 9,384 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 92,335 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,020 hr/yr Number of starts 661 starts/yr Operational life 19.9 yr Generator 2 Capacity factor 17.6 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 125,913 kWh/yr Mean electrical output 41.7 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 58,281 kWh/yr Mean thermal output 19.3 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 39,718 L/yr Specific fuel consumption 0.315 L/kWh Fuel energy input 390,826 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 115 hr/yr Number of starts 89 starts/yr Operational life 522 yr Capacity factor 0.908 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 8,993 kWh/yr Mean electrical output 78.2 kW Min. electrical output 71.8 kW Max. electrical output 93.1 kW Thermal production 4,474 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,980 L/yr Specific fuel consumption 0.331 L/kWh Fuel energy input 29,328 kWh/yr Mean electrical efficiency 30.7 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 176,690 Carbon monoxide 339 Unburned hydocarbons 37.5 Particulate matter 25.6 Sulfur dioxide 356 Nitrogen oxides 3,025 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vergnet 275kW GEV MP C Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,848,705 Levelized cost of energy $ 0.497/kWh Operating cost $ 180,745/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vergnet 275kW GEV MP C 2,134,642 0 127,636 0 0 2,262,278 Generator 4 0 0 30,107 313,260 -6,883 336,485 Generator 3 0 17,688 57,380 1,326,535 -17,168 1,384,435 Generator 2 0 0 1,558 71,872 -21,682 51,748 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 489,427 0 489,427 Other 0 0 343,490 0 0 343,490 System 2,134,642 17,688 560,208 2,203,336 -67,171 4,848,703 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vergnet 275kW GEV MP C 142,158 0 8,500 0 0 150,658 Generator 4 0 0 2,005 20,862 -458 22,408 Generator 3 0 1,178 3,821 88,342 -1,143 92,198 Generator 2 0 0 104 4,786 -1,444 3,446 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 32,594 0 32,594 Other 0 0 22,875 0 0 22,875 System 142,158 1,178 37,307 146,733 -4,473 322,903 Component Production Fraction (kWh/yr) Wind turbine 956,482 86% Generator 4 23,252 2% Generator 3 127,936 11% Generator 2 6,653 1% Generator 1 212 0% Total 1,114,535 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vergnet 275kW GEV MP C Quantity Value Units Excess electricity 694,791 kWh/yr Unmet load 0.00101 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.726 Component Production Fraction (kWh/yr) Generator 4 15,507 2% Generator 3 59,179 7% Generator 2 3,268 0% Generator 1 101 0% Boiler 124,481 14% Excess electricity 694,791 77% Total 897,327 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 461,153 kWh/yr Variable Value Units Total rated capacity 275 kW Mean output 109 kW Capacity factor 39.7 % Total production 956,482 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 274 kW Wind penetration 228 % Hours of operation 7,295 hr/yr Levelized cost 0.158 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,604 hr/yr Number of starts 892 starts/yr Operational life 37.4 yr Capacity factor 5.80 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 23,252 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,507 kWh/yr Mean thermal output 9.67 kW Min. thermal output 9.33 kW Max. thermal output 12.6 kW Quantity Value Units Fuel consumption 9,526 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 93,735 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,057 hr/yr Number of starts 647 starts/yr Operational life 19.6 yr Generator 2 Capacity factor 17.8 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 127,936 kWh/yr Mean electrical output 41.9 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 59,179 kWh/yr Mean thermal output 19.4 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 40,339 L/yr Specific fuel consumption 0.315 L/kWh Fuel energy input 396,933 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 83 hr/yr Number of starts 69 starts/yr Operational life 723 yr Capacity factor 0.672 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 6,653 kWh/yr Mean electrical output 80.2 kW Min. electrical output 74.6 kW Max. electrical output 93.1 kW Thermal production 3,268 kWh/yr Mean thermal output 39.4 kW Min. thermal output 38.0 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,186 L/yr Specific fuel consumption 0.328 L/kWh Fuel energy input 21,506 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 176,623 Carbon monoxide 339 Unburned hydocarbons 37.5 Particulate matter 25.5 Sulfur dioxide 356 Nitrogen oxides 3,023 www.knightpiesold.com Appendix G Vestas A-27 Economics Table of Contents Site Number Height Diesel Price US$/gal Page Number 1 37 m 4.25 G-1 1 37 m 5.50 G-8 1 37 m 6.92 G-15 1 37 m 8.30 G-22 2 37 m 4.25 G-29 2 37 m 5.50 G-36 2 37 m 6.92 G-43 2 37 m 8.30 G-50 DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,465,555 Levelized cost of energy $ 0.411/kWh Operating cost $ 113,455/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,761,912 0 127,636 0 0 1,889,548 Generator 4 0 0 32,190 171,990 -6,335 197,845 Generator 3 0 17,762 57,811 665,544 -17,034 724,084 Generator 2 0 0 3,491 78,292 -20,917 60,867 Generator 1 0 0 131 3,768 -21,402 -17,503 Boiler 0 0 0 267,224 0 267,224 Other 0 0 343,490 0 0 343,490 System 1,761,912 17,762 564,750 1,186,818 -65,688 3,465,554 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 117,336 0 8,500 0 0 125,836 Generator 4 0 0 2,144 11,454 -422 13,176 Generator 3 0 1,183 3,850 44,322 -1,134 48,221 Generator 2 0 0 232 5,214 -1,393 4,053 Generator 1 0 0 9 251 -1,425 -1,166 Boiler 0 0 0 17,796 0 17,796 Other 0 0 22,875 0 0 22,875 System 117,336 1,183 37,610 79,037 -4,375 230,791 Component Production Fraction (kWh/yr) Wind turbine 752,065 82% Generator 4 24,995 3% Generator 3 125,070 14% Generator 2 13,764 2% Generator 1 685 0% Total 916,579 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 496,837 kWh/yr Unmet load 0.00144 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.665 Component Production Fraction (kWh/yr) Generator 4 16,640 2% Generator 3 58,153 8% Generator 2 7,050 1% Generator 1 334 0% Boiler 132,898 19% Excess electricity 496,837 70% Total 711,912 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 275,738 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 85.9 kW Capacity factor 38.2 % Total production 752,065 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 179 % Hours of operation 7,924 hr/yr Levelized cost 0.167 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,715 hr/yr Number of starts 862 starts/yr Operational life 35.0 yr Capacity factor 6.23 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 24,995 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 16,640 kWh/yr Mean thermal output 9.70 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,227 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 100,630 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,080 hr/yr Number of starts 689 starts/yr Operational life 19.5 yr Generator 2 Capacity factor 17.4 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 125,070 kWh/yr Mean electrical output 40.6 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 58,153 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 39,574 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 389,405 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 186 hr/yr Number of starts 139 starts/yr Operational life 323 yr Capacity factor 1.39 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 13,764 kWh/yr Mean electrical output 74.0 kW Min. electrical output 61.8 kW Max. electrical output 93.1 kW Thermal production 7,050 kWh/yr Mean thermal output 37.9 kW Min. thermal output 35.0 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,655 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 45,808 kWh/yr Mean electrical efficiency 30.0 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 7 hr/yr Number of starts 7 starts/yr Operational life 8,571 yr Capacity factor 0.0579 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 685 kWh/yr Mean electrical output 97.9 kW Min. electrical output 87.8 kW Max. electrical output 109 kW Thermal production 334 kWh/yr Mean thermal output 47.7 kW Min. thermal output 44.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 224 L/yr Specific fuel consumption 0.327 L/kWh Fuel energy input 2,204 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.2 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 186,030 Carbon monoxide 355 Unburned hydocarbons 39.4 Particulate matter 26.8 Sulfur dioxide 375 Nitrogen oxides 3,171 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,815,238 Levelized cost of energy $ 0.425/kWh Operating cost $ 136,743/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,761,912 0 127,636 0 0 1,889,548 Generator 4 0 0 32,510 224,573 -6,252 250,831 Generator 3 0 17,842 58,281 869,903 -16,888 929,138 Generator 2 0 0 3,116 91,170 -21,065 73,221 Generator 1 0 0 113 4,237 -21,409 -17,060 Boiler 0 0 0 346,070 0 346,070 Other 0 0 343,490 0 0 343,490 System 1,761,912 17,842 565,144 1,535,953 -65,615 3,815,238 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 117,336 0 8,500 0 0 125,836 Generator 4 0 0 2,165 14,956 -416 16,704 Generator 3 0 1,188 3,881 57,932 -1,125 61,877 Generator 2 0 0 207 6,072 -1,403 4,876 Generator 1 0 0 7 282 -1,426 -1,136 Boiler 0 0 0 23,047 0 23,047 Other 0 0 22,875 0 0 22,875 System 117,336 1,188 37,636 102,288 -4,370 254,079 Component Production Fraction (kWh/yr) Wind turbine 752,065 82% Generator 4 25,198 3% Generator 3 126,293 14% Generator 2 12,438 1% Generator 1 597 0% Total 916,592 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 496,850 kWh/yr Unmet load 0.00146 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.665 Component Production Fraction (kWh/yr) Generator 4 16,785 2% Generator 3 58,706 8% Generator 2 6,328 1% Generator 1 290 0% Boiler 132,940 19% Excess electricity 496,850 70% Total 711,899 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 275,725 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 85.9 kW Capacity factor 38.2 % Total production 752,065 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 179 % Hours of operation 7,924 hr/yr Levelized cost 0.167 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,732 hr/yr Number of starts 882 starts/yr Operational life 34.6 yr Capacity factor 6.28 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 25,198 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 16,785 kWh/yr Mean thermal output 9.69 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,314 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 101,492 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,105 hr/yr Number of starts 672 starts/yr Operational life 19.3 yr Generator 2 Capacity factor 17.6 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 126,293 kWh/yr Mean electrical output 40.7 kW Min. electrical output 24.6 kW Max. electrical output 74.0 kW Thermal production 58,706 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 31.7 kW Quantity Value Units Fuel consumption 39,953 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 393,138 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 166 hr/yr Number of starts 122 starts/yr Operational life 361 yr Capacity factor 1.26 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 12,438 kWh/yr Mean electrical output 74.9 kW Min. electrical output 67.5 kW Max. electrical output 93.1 kW Thermal production 6,328 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,187 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 41,203 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0505 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 597 kWh/yr Mean electrical output 99.6 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 290 kWh/yr Mean thermal output 48.3 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 195 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,915 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 185,964 Carbon monoxide 355 Unburned hydocarbons 39.3 Particulate matter 26.8 Sulfur dioxide 375 Nitrogen oxides 3,170 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,217,709 Levelized cost of energy $ 0.442/kWh Operating cost $ 163,546/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,761,912 0 127,636 0 0 1,889,548 Generator 4 0 0 33,730 293,455 -5,931 321,253 Generator 3 0 18,064 59,613 1,131,460 -16,474 1,192,663 Generator 2 0 0 1,915 72,583 -21,541 52,956 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 437,325 0 437,325 Other 0 0 343,490 0 0 343,490 System 1,761,912 18,064 566,421 1,936,695 -65,384 4,217,707 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 117,336 0 8,500 0 0 125,836 Generator 4 0 0 2,246 19,543 -395 21,394 Generator 3 0 1,203 3,970 75,350 -1,097 79,426 Generator 2 0 0 127 4,834 -1,435 3,527 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 29,124 0 29,124 Other 0 0 22,875 0 0 22,875 System 117,336 1,203 37,721 128,976 -4,354 280,882 Component Production Fraction (kWh/yr) Wind turbine 752,065 82% Generator 4 26,072 3% Generator 3 130,287 14% Generator 2 7,966 1% Generator 1 212 0% Total 916,603 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 496,860 kWh/yr Unmet load 0.00150 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.665 Component Production Fraction (kWh/yr) Generator 4 17,383 2% Generator 3 60,473 8% Generator 2 3,965 1% Generator 1 101 0% Boiler 133,111 19% Excess electricity 496,860 70% Total 711,893 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 275,719 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 85.9 kW Capacity factor 38.2 % Total production 752,065 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 179 % Hours of operation 7,924 hr/yr Levelized cost 0.167 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,797 hr/yr Number of starts 933 starts/yr Operational life 33.4 yr Capacity factor 6.50 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 26,072 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 17,383 kWh/yr Mean thermal output 9.67 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,679 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 105,083 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,176 hr/yr Number of starts 641 starts/yr Operational life 18.9 yr Generator 2 Capacity factor 18.2 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 130,287 kWh/yr Mean electrical output 41.0 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 60,473 kWh/yr Mean thermal output 19.0 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 41,175 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 405,163 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 102 hr/yr Number of starts 79 starts/yr Operational life 588 yr Capacity factor 0.805 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 7,966 kWh/yr Mean electrical output 78.1 kW Min. electrical output 71.8 kW Max. electrical output 93.1 kW Thermal production 3,965 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,641 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 25,991 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 185,793 Carbon monoxide 355 Unburned hydocarbons 39.3 Particulate matter 26.7 Sulfur dioxide 375 Nitrogen oxides 3,165 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,598,689 Levelized cost of energy $ 0.458/kWh Operating cost $ 188,917/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,761,912 0 127,636 0 0 1,889,548 Generator 4 0 0 34,236 356,024 -5,798 384,462 Generator 3 0 18,165 60,233 1,372,726 -16,281 1,434,842 Generator 2 0 0 1,351 62,343 -21,764 41,931 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 523,574 0 523,574 Other 0 0 343,490 0 0 343,490 System 1,761,912 18,165 566,984 2,316,909 -65,282 4,598,687 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 117,336 0 8,500 0 0 125,836 Generator 4 0 0 2,280 23,710 -386 25,604 Generator 3 0 1,210 4,011 91,418 -1,084 95,554 Generator 2 0 0 90 4,152 -1,449 2,792 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 34,868 0 34,868 Other 0 0 22,875 0 0 22,875 System 117,336 1,210 37,759 154,296 -4,347 306,253 Component Production Fraction (kWh/yr) Wind turbine 752,065 82% Generator 4 26,421 3% Generator 3 132,143 14% Generator 2 5,771 1% Generator 1 212 0% Total 916,613 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 496,870 kWh/yr Unmet load 0.00151 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.665 Component Production Fraction (kWh/yr) Generator 4 17,625 2% Generator 3 61,294 9% Generator 2 2,834 0% Generator 1 101 0% Boiler 133,167 19% Excess electricity 496,870 70% Total 711,891 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 275,717 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 85.9 kW Capacity factor 38.2 % Total production 752,065 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 179 % Hours of operation 7,924 hr/yr Levelized cost 0.167 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,824 hr/yr Number of starts 957 starts/yr Operational life 32.9 yr Capacity factor 6.59 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 26,421 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 22.0 kW Thermal production 17,625 kWh/yr Mean thermal output 9.66 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,826 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 106,531 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 3,209 hr/yr Number of starts 626 starts/yr Operational life 18.7 yr Generator 2 Capacity factor 18.4 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 132,143 kWh/yr Mean electrical output 41.2 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 61,294 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 41,743 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 410,754 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 72 hr/yr Number of starts 61 starts/yr Operational life 833 yr Capacity factor 0.583 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 5,771 kWh/yr Mean electrical output 80.2 kW Min. electrical output 74.7 kW Max. electrical output 93.1 kW Thermal production 2,834 kWh/yr Mean thermal output 39.4 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,896 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 18,655 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 185,731 Carbon monoxide 354 Unburned hydocarbons 39.3 Particulate matter 26.7 Sulfur dioxide 375 Nitrogen oxides 3,163 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,653,432 Levelized cost of energy $ 0.440/kWh Operating cost $ 111,516/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,978,912 0 127,636 0 0 2,106,548 Generator 4 0 0 31,721 169,858 -6,459 195,120 Generator 3 0 17,514 56,385 649,797 -17,477 706,218 Generator 2 0 0 3,341 75,045 -20,976 57,410 Generator 1 0 0 131 3,759 -21,402 -17,512 Boiler 0 0 0 262,157 0 262,157 Other 0 0 343,490 0 0 343,490 System 1,978,912 17,514 562,704 1,160,615 -66,314 3,653,431 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 131,787 0 8,500 0 0 140,287 Generator 4 0 0 2,112 11,312 -430 12,994 Generator 3 0 1,166 3,755 43,274 -1,164 47,031 Generator 2 0 0 222 4,998 -1,397 3,823 Generator 1 0 0 9 250 -1,425 -1,166 Boiler 0 0 0 17,459 0 17,459 Other 0 0 22,875 0 0 22,875 System 131,787 1,166 37,474 77,292 -4,416 243,303 Component Production Fraction (kWh/yr) Wind turbine 772,496 83% Generator 4 24,703 3% Generator 3 122,127 13% Generator 2 13,206 1% Generator 1 683 0% Total 933,215 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 513,470 kWh/yr Unmet load 0.00147 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.675 Component Production Fraction (kWh/yr) Generator 4 16,430 2% Generator 3 56,774 8% Generator 2 6,754 1% Generator 1 334 0% Boiler 130,378 18% Excess electricity 513,470 71% Total 724,140 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 287,966 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 88.2 kW Capacity factor 39.2 % Total production 772,496 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 184 % Hours of operation 7,948 hr/yr Levelized cost 0.182 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,690 hr/yr Number of starts 843 starts/yr Operational life 35.5 yr Capacity factor 6.16 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 24,703 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.9 kW Thermal production 16,430 kWh/yr Mean thermal output 9.72 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,100 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 99,383 kWh/yr Mean electrical efficiency 24.9 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,004 hr/yr Number of starts 672 starts/yr Operational life 20.0 yr Generator 2 Capacity factor 17.0 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 122,127 kWh/yr Mean electrical output 40.7 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 56,774 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 38,637 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 380,191 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 178 hr/yr Number of starts 133 starts/yr Operational life 337 yr Capacity factor 1.33 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 13,206 kWh/yr Mean electrical output 74.2 kW Min. electrical output 63.5 kW Max. electrical output 93.1 kW Thermal production 6,754 kWh/yr Mean thermal output 37.9 kW Min. thermal output 35.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,462 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 43,908 kWh/yr Mean electrical efficiency 30.1 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 7 hr/yr Number of starts 7 starts/yr Operational life 8,571 yr Capacity factor 0.0578 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 683 kWh/yr Mean electrical output 97.6 kW Min. electrical output 86.3 kW Max. electrical output 109 kW Thermal production 334 kWh/yr Mean thermal output 47.7 kW Min. thermal output 43.9 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 224 L/yr Specific fuel consumption 0.327 L/kWh Fuel energy input 2,199 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.2 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 181,924 Carbon monoxide 347 Unburned hydocarbons 38.5 Particulate matter 26.2 Sulfur dioxide 367 Nitrogen oxides 3,099 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 3,995,407 Levelized cost of energy $ 0.454/kWh Operating cost $ 134,290/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,978,912 0 127,636 0 0 2,106,548 Generator 4 0 0 32,003 221,564 -6,385 247,182 Generator 3 0 17,590 56,817 848,873 -17,343 905,937 Generator 2 0 0 3,003 87,931 -21,110 69,824 Generator 1 0 0 113 4,234 -21,409 -17,063 Boiler 0 0 0 339,488 0 339,488 Other 0 0 343,490 0 0 343,490 System 1,978,912 17,590 563,061 1,502,090 -66,247 3,995,406 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 131,787 0 8,500 0 0 140,287 Generator 4 0 0 2,131 14,755 -425 16,461 Generator 3 0 1,171 3,784 56,531 -1,155 60,332 Generator 2 0 0 200 5,856 -1,406 4,650 Generator 1 0 0 7 282 -1,426 -1,136 Boiler 0 0 0 22,608 0 22,608 Other 0 0 22,875 0 0 22,875 System 131,787 1,171 37,497 100,033 -4,412 266,077 Component Production Fraction (kWh/yr) Wind turbine 772,496 83% Generator 4 24,878 3% Generator 3 123,256 13% Generator 2 12,001 1% Generator 1 597 0% Total 933,228 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 513,483 kWh/yr Unmet load 0.00148 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.675 Component Production Fraction (kWh/yr) Generator 4 16,556 2% Generator 3 57,283 8% Generator 2 6,102 1% Generator 1 290 0% Boiler 130,412 18% Excess electricity 513,483 71% Total 724,127 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 287,953 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 88.2 kW Capacity factor 39.2 % Total production 772,496 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 184 % Hours of operation 7,948 hr/yr Levelized cost 0.182 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,705 hr/yr Number of starts 859 starts/yr Operational life 35.2 yr Capacity factor 6.20 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 24,878 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.9 kW Thermal production 16,556 kWh/yr Mean thermal output 9.71 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,176 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 100,132 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,027 hr/yr Number of starts 658 starts/yr Operational life 19.8 yr Generator 2 Capacity factor 17.2 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 123,256 kWh/yr Mean electrical output 40.7 kW Min. electrical output 24.6 kW Max. electrical output 72.5 kW Thermal production 57,283 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 31.1 kW Quantity Value Units Fuel consumption 38,987 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 383,634 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 160 hr/yr Number of starts 117 starts/yr Operational life 375 yr Capacity factor 1.21 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 12,001 kWh/yr Mean electrical output 75.0 kW Min. electrical output 67.5 kW Max. electrical output 93.1 kW Thermal production 6,102 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.3 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,039 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 39,739 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.6 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0505 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 597 kWh/yr Mean electrical output 99.5 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 290 kWh/yr Mean thermal output 48.3 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,913 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 181,864 Carbon monoxide 347 Unburned hydocarbons 38.4 Particulate matter 26.2 Sulfur dioxide 367 Nitrogen oxides 3,097 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,389,019 Levelized cost of energy $ 0.469/kWh Operating cost $ 160,503/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,978,912 0 127,636 0 0 2,106,548 Generator 4 0 0 33,185 289,339 -6,074 316,450 Generator 3 0 17,814 58,112 1,104,016 -16,941 1,163,001 Generator 2 0 0 1,839 69,791 -21,571 50,060 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 428,997 0 428,997 Other 0 0 343,490 0 0 343,490 System 1,978,912 17,814 564,300 1,894,016 -66,024 4,389,017 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 131,787 0 8,500 0 0 140,287 Generator 4 0 0 2,210 19,269 -405 21,074 Generator 3 0 1,186 3,870 73,523 -1,128 77,451 Generator 2 0 0 122 4,648 -1,437 3,334 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 28,569 0 28,569 Other 0 0 22,875 0 0 22,875 System 131,787 1,186 37,580 126,134 -4,397 292,290 Component Production Fraction (kWh/yr) Wind turbine 772,496 83% Generator 4 25,724 3% Generator 3 127,143 14% Generator 2 7,663 1% Generator 1 212 0% Total 933,238 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 513,493 kWh/yr Unmet load 0.00157 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.675 Component Production Fraction (kWh/yr) Generator 4 17,135 2% Generator 3 59,002 8% Generator 2 3,812 1% Generator 1 101 0% Boiler 130,576 18% Excess electricity 513,493 71% Total 724,120 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 287,946 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 88.2 kW Capacity factor 39.2 % Total production 772,496 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 184 % Hours of operation 7,948 hr/yr Levelized cost 0.182 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,768 hr/yr Number of starts 913 starts/yr Operational life 33.9 yr Capacity factor 6.41 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 25,724 kWh/yr Mean electrical output 14.6 kW Min. electrical output 13.7 kW Max. electrical output 21.9 kW Thermal production 17,135 kWh/yr Mean thermal output 9.69 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,529 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 103,609 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,096 hr/yr Number of starts 629 starts/yr Operational life 19.4 yr Generator 2 Capacity factor 17.7 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 127,143 kWh/yr Mean electrical output 41.1 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 59,002 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 40,176 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 395,336 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 98 hr/yr Number of starts 76 starts/yr Operational life 612 yr Capacity factor 0.774 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 7,663 kWh/yr Mean electrical output 78.2 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 3,812 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,540 L/yr Specific fuel consumption 0.331 L/kWh Fuel energy input 24,991 kWh/yr Mean electrical efficiency 30.7 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.3 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 181,699 Carbon monoxide 347 Unburned hydocarbons 38.4 Particulate matter 26.1 Sulfur dioxide 366 Nitrogen oxides 3,092 System Report - ChikLake_WIND_Vestas_Vergnet.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Thermal Load 1 Scaled Average: 1,195 kWh/d Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine1 Vestas V-27 (A-27) Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,761,618 Levelized cost of energy $ 0.483/kWh Operating cost $ 185,316/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Vestas V-27 (A-27) 1,978,912 0 127,636 0 0 2,106,548 Generator 4 0 0 33,730 351,621 -5,931 379,419 Generator 3 0 17,918 58,731 1,340,473 -16,748 1,400,373 Generator 2 0 0 1,276 58,955 -21,794 38,438 Generator 1 0 0 19 1,148 -21,445 -20,278 Boiler 0 0 0 513,627 0 513,627 Other 0 0 343,490 0 0 343,490 System 1,978,912 17,918 564,882 2,265,823 -65,918 4,761,616 Electrical Component Capital Replacement O&M Fuel Salvage Total ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Vestas V-27 (A-27) 131,787 0 8,500 0 0 140,287 Generator 4 0 0 2,246 23,416 -395 25,268 Generator 3 0 1,193 3,911 89,270 -1,115 93,259 Generator 2 0 0 85 3,926 -1,451 2,560 Generator 1 0 0 1 76 -1,428 -1,350 Boiler 0 0 0 34,205 0 34,205 Other 0 0 22,875 0 0 22,875 System 131,787 1,193 37,619 150,894 -4,390 317,104 Component Production Fraction (kWh/yr) Wind turbine 772,496 83% Generator 4 26,115 3% Generator 3 129,063 14% Generator 2 5,461 1% Generator 1 109 0% Total 933,245 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Thermal AC Wind Turbine: Vestas V-27 (A-27) Quantity Value Units Excess electricity 513,500 kWh/yr Unmet load 0.00158 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.675 Component Production Fraction (kWh/yr) Generator 4 17,402 2% Generator 3 59,849 8% Generator 2 2,680 0% Generator 1 52 0% Boiler 130,636 18% Excess electricity 513,500 71% Total 724,118 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 287,945 kWh/yr Variable Value Units Total rated capacity 225 kW Mean output 88.2 kW Capacity factor 39.2 % Total production 772,496 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 224 kW Wind penetration 184 % Hours of operation 7,948 hr/yr Levelized cost 0.182 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,797 hr/yr Number of starts 933 starts/yr Operational life 33.4 yr Capacity factor 6.51 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 26,115 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.9 kW Thermal production 17,402 kWh/yr Mean thermal output 9.68 kW Min. thermal output 9.33 kW Max. thermal output 13.0 kW Quantity Value Units Fuel consumption 10,692 L/yr Specific fuel consumption 0.409 L/kWh Fuel energy input 105,214 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.4 % Quantity Value Units Hours of operation 3,129 hr/yr Number of starts 612 starts/yr Operational life 19.2 yr Generator 2 Capacity factor 18.0 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 129,063 kWh/yr Mean electrical output 41.2 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 59,849 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 40,762 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 401,103 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 68 hr/yr Number of starts 58 starts/yr Operational life 882 yr Capacity factor 0.552 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 5,461 kWh/yr Mean electrical output 80.3 kW Min. electrical output 74.7 kW Max. electrical output 93.1 kW Thermal production 2,680 kWh/yr Mean thermal output 39.4 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,793 L/yr Specific fuel consumption 0.328 L/kWh Fuel energy input 17,641 kWh/yr Mean electrical efficiency 31.0 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 1 hr/yr Number of starts 1 starts/yr Operational life 60,000 yr Capacity factor 0.00925 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 109 kWh/yr Mean electrical output 109 kW Min. electrical output 109 kW Max. electrical output 109 kW Thermal production 51.5 kWh/yr Mean thermal output 51.5 kW Min. thermal output 51.5 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 34.9 L/yr Specific fuel consumption 0.319 L/kWh Fuel energy input 344 kWh/yr Mean electrical efficiency 31.8 % Mean total efficiency 46.8 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 181,636 Carbon monoxide 346 Unburned hydocarbons 38.4 Particulate matter 26.1 Sulfur dioxide 366 Nitrogen oxides 3,090 www.knightpiesold.com Appendix H Multiple Northwind 100B/21 (37 m Hub Height) Economics Table of Contents Site Number Number of Turbines Diesel Price US$/gal Page Number 1 2 4.25 H-1 1 2 5.50 H-8 1 2 6.92 H-15 1 2 8.30 H-22 2 2 4.25 H-29 2 2 5.50 H-36 2 2 6.92 H-43 2 2 8.30 H-50 1 3 4.25 H-57 1 3 5.50 H-64 1 3 6.92 H-71 1 3 8.30 H-78 2 3 4.25 H-85 2 3 5.50 H-92 2 3 6.92 H-99 2 3 8.30 H-106 DV103.00240.01 Chignik Lake Wind Resource Assessment Final Report System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,031,698 Levelized cost of energy $ 0.501/kWh Operating cost $ 119,431/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,238,325 0 255,271 0 0 2,493,596 Generator 4 0 0 35,963 191,001 -5,344 221,620 Generator 3 0 0 53,757 615,411 -793 668,375 Generator 2 0 0 3,247 72,781 -21,013 55,015 Generator 1 0 0 113 3,266 -21,409 -18,031 Boiler 0 0 0 267,632 0 267,632 Other 0 0 343,490 0 0 343,490 System 2,238,325 0 691,841 1,150,091 -48,561 4,031,697 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 149,063 0 17,000 0 0 166,063 Generator 4 0 0 2,395 12,720 -356 14,759 Generator 3 0 0 3,580 40,984 -53 44,511 Generator 2 0 0 216 4,847 -1,399 3,664 Generator 1 0 0 7 217 -1,426 -1,201 Boiler 0 0 0 17,823 0 17,823 Other 0 0 22,875 0 0 22,875 System 149,063 0 46,074 76,591 -3,234 268,494 Component Production Fraction (kWh/yr) Wind turbines 694,112 82% Generator 4 27,704 3% Generator 3 115,562 14% Generator 2 12,791 2% Generator 1 596 0% Total 850,765 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 431,015 kWh/yr Unmet load 0.00105 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.653 Component Production Fraction (kWh/yr) Generator 4 18,491 3% Generator 3 53,792 8% Generator 2 6,554 1% Generator 1 289 0% Boiler 133,101 21% Excess electricity 431,015 67% Total 643,243 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 207,069 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 79.2 kW Capacity factor 39.6 % Total production 694,112 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 165 % Hours of operation 7,361 hr/yr Levelized cost 0.239 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,916 hr/yr Number of starts 917 starts/yr Operational life 31.3 yr Capacity factor 6.91 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 27,704 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.8 kW Thermal production 18,491 kWh/yr Mean thermal output 9.65 kW Min. thermal output 9.33 kW Max. thermal output 12.9 kW Quantity Value Units Fuel consumption 11,357 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 111,753 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,864 hr/yr Number of starts 671 starts/yr Operational life 20.9 yr Generator 2 Capacity factor 16.1 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 115,562 kWh/yr Mean electrical output 40.3 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 53,792 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 36,593 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 360,072 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 173 hr/yr Number of starts 128 starts/yr Operational life 347 yr Capacity factor 1.29 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 12,791 kWh/yr Mean electrical output 73.9 kW Min. electrical output 61.3 kW Max. electrical output 93.1 kW Thermal production 6,554 kWh/yr Mean thermal output 37.9 kW Min. thermal output 34.9 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,328 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 42,583 kWh/yr Mean electrical efficiency 30.0 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0504 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 596 kWh/yr Mean electrical output 99.3 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 289 kWh/yr Mean thermal output 48.2 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,911 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 180,280 Carbon monoxide 341 Unburned hydocarbons 37.8 Particulate matter 25.7 Sulfur dioxide 364 Nitrogen oxides 3,043 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,370,469 Levelized cost of energy $ 0.513/kWh Operating cost $ 141,992/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,238,325 0 255,271 0 0 2,493,596 Generator 4 0 0 36,207 248,535 -5,280 279,462 Generator 3 0 0 54,264 805,042 -636 858,670 Generator 2 0 0 2,872 84,051 -21,162 65,761 Generator 1 0 0 113 4,228 -21,409 -17,069 Boiler 0 0 0 346,558 0 346,558 Other 0 0 343,490 0 0 343,490 System 2,238,325 0 692,217 1,488,414 -48,488 4,370,468 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 149,063 0 17,000 0 0 166,063 Generator 4 0 0 2,411 16,551 -352 18,611 Generator 3 0 0 3,614 53,612 -42 57,184 Generator 2 0 0 191 5,597 -1,409 4,379 Generator 1 0 0 7 282 -1,426 -1,137 Boiler 0 0 0 23,079 0 23,079 Other 0 0 22,875 0 0 22,875 System 149,063 0 46,099 99,122 -3,229 291,055 Component Production Fraction (kWh/yr) Wind turbines 694,112 82% Generator 4 27,829 3% Generator 3 116,782 14% Generator 2 11,469 1% Generator 1 596 0% Total 850,788 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 431,037 kWh/yr Unmet load 0.00107 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.653 Component Production Fraction (kWh/yr) Generator 4 18,589 3% Generator 3 54,349 8% Generator 2 5,834 1% Generator 1 289 0% Boiler 133,128 21% Excess electricity 431,037 67% Total 643,226 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 207,053 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 79.2 kW Capacity factor 39.6 % Total production 694,112 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 165 % Hours of operation 7,361 hr/yr Levelized cost 0.239 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,929 hr/yr Number of starts 931 starts/yr Operational life 31.1 yr Capacity factor 6.94 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 27,829 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.8 kW Thermal production 18,589 kWh/yr Mean thermal output 9.64 kW Min. thermal output 9.33 kW Max. thermal output 12.9 kW Quantity Value Units Fuel consumption 11,415 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 112,321 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,891 hr/yr Number of starts 661 starts/yr Operational life 20.8 yr Generator 2 Capacity factor 16.3 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 116,782 kWh/yr Mean electrical output 40.4 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 54,349 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 36,974 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 363,825 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 153 hr/yr Number of starts 112 starts/yr Operational life 392 yr Capacity factor 1.16 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 11,469 kWh/yr Mean electrical output 75.0 kW Min. electrical output 67.4 kW Max. electrical output 93.1 kW Thermal production 5,834 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.3 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,860 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 37,985 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0504 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 596 kWh/yr Mean electrical output 99.3 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 289 kWh/yr Mean thermal output 48.2 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,911 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 180,214 Carbon monoxide 341 Unburned hydocarbons 37.8 Particulate matter 25.7 Sulfur dioxide 363 Nitrogen oxides 3,042 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,760,282 Levelized cost of energy $ 0.528/kWh Operating cost $ 167,952/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,238,325 0 255,271 0 0 2,493,596 Generator 4 0 0 37,315 322,677 -4,989 355,002 Generator 3 0 0 55,521 1,047,545 -245 1,102,821 Generator 2 0 0 1,764 66,860 -21,600 47,024 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 437,874 0 437,874 Other 0 0 343,490 0 0 343,490 System 2,238,325 0 693,399 1,876,829 -48,273 4,760,280 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 149,063 0 17,000 0 0 166,063 Generator 4 0 0 2,485 21,489 -332 23,642 Generator 3 0 0 3,697 69,762 -16 73,443 Generator 2 0 0 117 4,453 -1,439 3,132 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 29,161 0 29,161 Other 0 0 22,875 0 0 22,875 System 149,063 0 46,177 124,989 -3,215 317,015 Component Production Fraction (kWh/yr) Wind turbines 694,112 82% Generator 4 28,612 3% Generator 3 120,529 14% Generator 2 7,336 1% Generator 1 212 0% Total 850,801 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 431,051 kWh/yr Unmet load 0.00110 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.653 Component Production Fraction (kWh/yr) Generator 4 19,126 3% Generator 3 56,009 9% Generator 2 3,653 1% Generator 1 101 0% Boiler 133,278 21% Excess electricity 431,051 67% Total 643,218 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 207,044 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 79.2 kW Capacity factor 39.6 % Total production 694,112 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 165 % Hours of operation 7,361 hr/yr Levelized cost 0.239 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,988 hr/yr Number of starts 975 starts/yr Operational life 30.2 yr Capacity factor 7.13 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 28,612 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.8 kW Thermal production 19,126 kWh/yr Mean thermal output 9.62 kW Min. thermal output 9.33 kW Max. thermal output 12.9 kW Quantity Value Units Fuel consumption 11,743 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 115,547 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,958 hr/yr Number of starts 633 starts/yr Operational life 20.3 yr Generator 2 Capacity factor 16.8 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 120,529 kWh/yr Mean electrical output 40.7 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 56,009 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 38,121 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 375,114 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 94 hr/yr Number of starts 73 starts/yr Operational life 638 yr Capacity factor 0.741 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 7,336 kWh/yr Mean electrical output 78.0 kW Min. electrical output 71.8 kW Max. electrical output 93.1 kW Thermal production 3,653 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,433 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 23,942 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 180,056 Carbon monoxide 340 Unburned hydocarbons 37.7 Particulate matter 25.7 Sulfur dioxide 363 Nitrogen oxides 3,037 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,129,392 Levelized cost of energy $ 0.542/kWh Operating cost $ 192,533/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,238,325 0 255,271 0 0 2,493,596 Generator 4 0 0 37,803 390,957 -4,861 423,899 Generator 3 0 0 56,047 1,269,906 -82 1,325,872 Generator 2 0 0 1,258 57,993 -21,801 37,450 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 524,243 0 524,243 Other 0 0 343,490 0 0 343,490 System 2,238,325 0 693,906 2,245,341 -48,182 5,129,390 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 149,063 0 17,000 0 0 166,063 Generator 4 0 0 2,517 26,036 -324 28,230 Generator 3 0 0 3,732 84,570 -5 88,297 Generator 2 0 0 84 3,862 -1,452 2,494 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 34,912 0 34,912 Other 0 0 22,875 0 0 22,875 System 149,063 0 46,211 149,530 -3,209 341,596 Component Production Fraction (kWh/yr) Wind turbines 694,112 82% Generator 4 28,962 3% Generator 3 122,151 14% Generator 2 5,367 1% Generator 1 212 0% Total 850,804 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 431,054 kWh/yr Unmet load 0.00113 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.653 Component Production Fraction (kWh/yr) Generator 4 19,366 3% Generator 3 56,724 9% Generator 2 2,637 0% Generator 1 101 0% Boiler 133,337 21% Excess electricity 431,054 67% Total 643,218 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 207,044 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 79.2 kW Capacity factor 39.6 % Total production 694,112 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 165 % Hours of operation 7,361 hr/yr Levelized cost 0.239 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 2,014 hr/yr Number of starts 991 starts/yr Operational life 29.8 yr Capacity factor 7.22 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 28,962 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.8 kW Thermal production 19,366 kWh/yr Mean thermal output 9.62 kW Min. thermal output 9.33 kW Max. thermal output 12.9 kW Quantity Value Units Fuel consumption 11,889 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 116,984 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,986 hr/yr Number of starts 618 starts/yr Operational life 20.1 yr Generator 2 Capacity factor 17.0 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 122,151 kWh/yr Mean electrical output 40.9 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 56,724 kWh/yr Mean thermal output 19.0 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 38,617 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 379,988 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 67 hr/yr Number of starts 57 starts/yr Operational life 896 yr Capacity factor 0.542 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 5,367 kWh/yr Mean electrical output 80.1 kW Min. electrical output 74.7 kW Max. electrical output 93.1 kW Thermal production 2,637 kWh/yr Mean thermal output 39.4 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,764 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 17,353 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 180,000 Carbon monoxide 340 Unburned hydocarbons 37.7 Particulate matter 25.6 Sulfur dioxide 363 Nitrogen oxides 3,036 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,436,688 Levelized cost of energy $ 0.565/kWh Operating cost $ 117,499/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,672,325 0 255,271 0 0 2,927,596 Generator 4 0 0 35,438 188,265 -5,482 218,221 Generator 3 0 0 52,387 599,333 -1,219 650,500 Generator 2 0 0 3,153 70,637 -21,050 52,740 Generator 1 0 0 113 3,263 -21,409 -18,034 Boiler 0 0 0 262,173 0 262,173 Other 0 0 343,490 0 0 343,490 System 2,672,325 0 689,852 1,123,672 -49,162 4,436,687 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 177,966 0 17,000 0 0 194,966 Generator 4 0 0 2,360 12,538 -365 14,533 Generator 3 0 0 3,489 39,913 -81 43,321 Generator 2 0 0 210 4,704 -1,402 3,512 Generator 1 0 0 7 217 -1,426 -1,201 Boiler 0 0 0 17,460 0 17,460 Other 0 0 22,875 0 0 22,875 System 177,966 0 45,941 74,832 -3,274 295,465 Component Production Fraction (kWh/yr) Wind turbines 712,588 82% Generator 4 27,310 3% Generator 3 112,533 13% Generator 2 12,410 1% Generator 1 595 0% Total 865,436 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 445,685 kWh/yr Unmet load 0.000942 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.664 Component Production Fraction (kWh/yr) Generator 4 18,226 3% Generator 3 52,389 8% Generator 2 6,362 1% Generator 1 289 0% Boiler 130,386 20% Excess electricity 445,685 68% Total 653,337 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 217,164 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 81.3 kW Capacity factor 40.7 % Total production 712,588 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 170 % Hours of operation 7,390 hr/yr Levelized cost 0.274 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,888 hr/yr Number of starts 919 starts/yr Operational life 31.8 yr Capacity factor 6.81 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 27,310 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 18,226 kWh/yr Mean thermal output 9.65 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 11,194 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 110,153 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,791 hr/yr Number of starts 671 starts/yr Operational life 21.5 yr Generator 2 Capacity factor 15.7 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 112,533 kWh/yr Mean electrical output 40.3 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 52,389 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 35,637 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 350,665 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 168 hr/yr Number of starts 124 starts/yr Operational life 357 yr Capacity factor 1.25 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 12,410 kWh/yr Mean electrical output 73.9 kW Min. electrical output 61.6 kW Max. electrical output 93.1 kW Thermal production 6,362 kWh/yr Mean thermal output 37.9 kW Min. thermal output 34.9 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 4,200 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 41,329 kWh/yr Mean electrical efficiency 30.0 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0503 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 595 kWh/yr Mean electrical output 99.2 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 289 kWh/yr Mean thermal output 48.2 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,909 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 176,139 Carbon monoxide 333 Unburned hydocarbons 36.9 Particulate matter 25.1 Sulfur dioxide 355 Nitrogen oxides 2,971 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,767,677 Levelized cost of energy $ 0.576/kWh Operating cost $ 139,542/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,672,325 0 255,271 0 0 2,927,596 Generator 4 0 0 35,757 245,695 -5,399 276,053 Generator 3 0 0 52,819 783,454 -1,085 835,188 Generator 2 0 0 2,778 81,308 -21,199 62,887 Generator 1 0 0 113 4,225 -21,409 -17,072 Boiler 0 0 0 339,534 0 339,534 Other 0 0 343,490 0 0 343,490 System 2,672,325 0 690,227 1,454,216 -49,092 4,767,676 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 177,966 0 17,000 0 0 194,966 Generator 4 0 0 2,381 16,362 -360 18,384 Generator 3 0 0 3,517 52,175 -72 55,620 Generator 2 0 0 185 5,415 -1,412 4,188 Generator 1 0 0 7 281 -1,426 -1,137 Boiler 0 0 0 22,612 0 22,612 Other 0 0 22,875 0 0 22,875 System 177,966 0 45,966 96,845 -3,269 317,507 Component Production Fraction (kWh/yr) Wind turbines 712,588 82% Generator 4 27,521 3% Generator 3 113,647 13% Generator 2 11,095 1% Generator 1 595 0% Total 865,446 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 445,695 kWh/yr Unmet load 0.000969 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.664 Component Production Fraction (kWh/yr) Generator 4 18,374 3% Generator 3 52,893 8% Generator 2 5,643 1% Generator 1 289 0% Boiler 130,430 20% Excess electricity 445,695 68% Total 653,324 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 217,150 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 81.3 kW Capacity factor 40.7 % Total production 712,588 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 170 % Hours of operation 7,390 hr/yr Levelized cost 0.274 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,905 hr/yr Number of starts 932 starts/yr Operational life 31.5 yr Capacity factor 6.86 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 27,521 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 18,374 kWh/yr Mean thermal output 9.65 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 11,284 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 111,038 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,814 hr/yr Number of starts 658 starts/yr Operational life 21.3 yr Generator 2 Capacity factor 15.8 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 113,647 kWh/yr Mean electrical output 40.4 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 52,893 kWh/yr Mean thermal output 18.8 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 35,983 L/yr Specific fuel consumption 0.317 L/kWh Fuel energy input 354,069 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.0 % Quantity Value Units Hours of operation 148 hr/yr Number of starts 108 starts/yr Operational life 405 yr Capacity factor 1.12 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 11,095 kWh/yr Mean electrical output 75.0 kW Min. electrical output 67.4 kW Max. electrical output 93.1 kW Thermal production 5,643 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.3 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,734 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 36,746 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.6 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0503 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 595 kWh/yr Mean electrical output 99.2 kW Min. electrical output 95.0 kW Max. electrical output 109 kW Thermal production 289 kWh/yr Mean thermal output 48.2 kW Min. thermal output 46.8 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,909 kWh/yr Mean electrical efficiency 31.2 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 176,074 Carbon monoxide 333 Unburned hydocarbons 36.9 Particulate matter 25.1 Sulfur dioxide 355 Nitrogen oxides 2,969 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,148,533 Levelized cost of energy $ 0.589/kWh Operating cost $ 164,905/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,672,325 0 255,271 0 0 2,927,596 Generator 4 0 0 36,827 318,716 -5,118 350,425 Generator 3 0 0 54,076 1,020,069 -694 1,073,451 Generator 2 0 0 1,689 64,051 -21,630 44,110 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 428,987 0 428,987 Other 0 0 343,490 0 0 343,490 System 2,672,325 0 691,391 1,833,696 -48,880 5,148,531 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 177,966 0 17,000 0 0 194,966 Generator 4 0 0 2,452 21,225 -341 23,337 Generator 3 0 0 3,601 67,932 -46 71,487 Generator 2 0 0 112 4,266 -1,440 2,938 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 28,569 0 28,569 Other 0 0 22,875 0 0 22,875 System 177,966 0 46,044 122,116 -3,255 342,871 Component Production Fraction (kWh/yr) Wind turbines 712,588 82% Generator 4 28,268 3% Generator 3 117,364 14% Generator 2 7,030 1% Generator 1 212 0% Total 865,462 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 445,712 kWh/yr Unmet load 0.000992 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.664 Component Production Fraction (kWh/yr) Generator 4 18,890 3% Generator 3 54,540 8% Generator 2 3,499 1% Generator 1 101 0% Boiler 130,573 20% Excess electricity 445,712 68% Total 653,315 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 217,142 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 81.3 kW Capacity factor 40.7 % Total production 712,588 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 170 % Hours of operation 7,390 hr/yr Levelized cost 0.274 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,962 hr/yr Number of starts 970 starts/yr Operational life 30.6 yr Capacity factor 7.05 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 28,268 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 18,890 kWh/yr Mean thermal output 9.63 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 11,598 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 114,129 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,881 hr/yr Number of starts 631 starts/yr Operational life 20.8 yr Generator 2 Capacity factor 16.4 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 117,364 kWh/yr Mean electrical output 40.7 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 54,540 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 37,121 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 365,275 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 90 hr/yr Number of starts 70 starts/yr Operational life 667 yr Capacity factor 0.710 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 7,030 kWh/yr Mean electrical output 78.1 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 3,499 kWh/yr Mean thermal output 38.9 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,331 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 22,936 kWh/yr Mean electrical efficiency 30.7 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 175,919 Carbon monoxide 332 Unburned hydocarbons 36.8 Particulate matter 25 Sulfur dioxide 355 Nitrogen oxides 2,965 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine2 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,509,172 Levelized cost of energy $ 0.602/kWh Operating cost $ 188,922/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 2,672,325 0 255,271 0 0 2,927,596 Generator 4 0 0 37,296 386,105 -4,994 418,406 Generator 3 0 0 54,545 1,235,595 -548 1,289,592 Generator 2 0 0 1,220 56,239 -21,816 35,643 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 513,602 0 513,602 Other 0 0 343,490 0 0 343,490 System 2,672,325 0 691,860 2,193,782 -48,797 5,509,170 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 177,966 0 17,000 0 0 194,966 Generator 4 0 0 2,484 25,713 -333 27,864 Generator 3 0 0 3,632 82,285 -37 85,881 Generator 2 0 0 81 3,745 -1,453 2,374 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 34,204 0 34,204 Other 0 0 22,875 0 0 22,875 System 177,966 0 46,075 146,097 -3,250 366,888 Component Production Fraction (kWh/yr) Wind turbines 712,588 82% Generator 4 28,612 3% Generator 3 118,847 14% Generator 2 5,204 1% Generator 1 212 0% Total 865,462 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 445,712 kWh/yr Unmet load 0.00101 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.664 Component Production Fraction (kWh/yr) Generator 4 19,123 3% Generator 3 55,192 8% Generator 2 2,557 0% Generator 1 101 0% Boiler 130,630 20% Excess electricity 445,712 68% Total 653,315 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 217,142 kWh/yr Variable Value Units Total rated capacity 200 kW Mean output 81.3 kW Capacity factor 40.7 % Total production 712,588 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 201 kW Wind penetration 170 % Hours of operation 7,390 hr/yr Levelized cost 0.274 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,987 hr/yr Number of starts 989 starts/yr Operational life 30.2 yr Capacity factor 7.13 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 28,612 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 19,123 kWh/yr Mean thermal output 9.62 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 11,741 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 115,532 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,906 hr/yr Number of starts 617 starts/yr Operational life 20.6 yr Generator 2 Capacity factor 16.6 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 118,847 kWh/yr Mean electrical output 40.9 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 55,192 kWh/yr Mean thermal output 19.0 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 37,573 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 369,721 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 65 hr/yr Number of starts 55 starts/yr Operational life 923 yr Capacity factor 0.526 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 5,204 kWh/yr Mean electrical output 80.1 kW Min. electrical output 74.9 kW Max. electrical output 93.1 kW Thermal production 2,557 kWh/yr Mean thermal output 39.3 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,710 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 16,828 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 175,867 Carbon monoxide 332 Unburned hydocarbons 36.8 Particulate matter 25 Sulfur dioxide 355 Nitrogen oxides 2,963 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 4,761,648 Levelized cost of energy $ 0.616/kWh Operating cost $ 114,940/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,035,716 0 382,907 0 0 3,418,623 Generator 4 0 0 28,887 153,691 -7,203 175,375 Generator 3 0 0 46,174 531,296 -3,150 574,320 Generator 2 0 0 2,909 65,329 -21,147 47,092 Generator 1 0 0 113 3,255 -21,409 -18,042 Boiler 0 0 0 220,789 0 220,789 Other 0 0 343,490 0 0 343,490 System 3,035,716 0 804,480 974,361 -52,910 4,761,647 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 202,166 0 25,500 0 0 227,666 Generator 4 0 0 1,924 10,235 -480 11,679 Generator 3 0 0 3,075 35,382 -210 38,247 Generator 2 0 0 194 4,351 -1,408 3,136 Generator 1 0 0 7 217 -1,426 -1,202 Boiler 0 0 0 14,704 0 14,704 Other 0 0 22,875 0 0 22,875 System 202,166 0 53,575 64,888 -3,524 317,106 Component Production Fraction (kWh/yr) Wind turbines 1,041,166 89% Generator 4 22,305 2% Generator 3 99,835 8% Generator 2 11,495 1% Generator 1 593 0% Total 1,175,394 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 755,645 kWh/yr Unmet load 0.000746 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.770 Component Production Fraction (kWh/yr) Generator 4 14,876 2% Generator 3 46,425 5% Generator 2 5,880 1% Generator 1 288 0% Boiler 109,805 12% Excess electricity 755,645 81% Total 932,920 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 496,746 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 119 kW Capacity factor 39.6 % Total production 1,041,166 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 248 % Hours of operation 7,361 hr/yr Levelized cost 0.219 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,539 hr/yr Number of starts 823 starts/yr Operational life 39.0 yr Capacity factor 5.56 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 22,305 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.4 kW Thermal production 14,876 kWh/yr Mean thermal output 9.67 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,139 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 89,923 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,460 hr/yr Number of starts 607 starts/yr Operational life 24.4 yr Generator 2 Capacity factor 13.9 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 99,835 kWh/yr Mean electrical output 40.6 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 46,425 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 31,591 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 310,857 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 155 hr/yr Number of starts 113 starts/yr Operational life 387 yr Capacity factor 1.16 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 11,495 kWh/yr Mean electrical output 74.2 kW Min. electrical output 63.7 kW Max. electrical output 93.1 kW Thermal production 5,880 kWh/yr Mean thermal output 37.9 kW Min. thermal output 35.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,885 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 38,224 kWh/yr Mean electrical efficiency 30.1 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0502 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 593 kWh/yr Mean electrical output 98.9 kW Min. electrical output 93.3 kW Max. electrical output 109 kW Thermal production 288 kWh/yr Mean thermal output 48.1 kW Min. thermal output 46.2 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,905 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 152,729 Carbon monoxide 291 Unburned hydocarbons 32.3 Particulate matter 22 Sulfur dioxide 308 Nitrogen oxides 2,599 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,048,665 Levelized cost of energy $ 0.621/kWh Operating cost $ 134,054/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,035,716 0 382,907 0 0 3,418,623 Generator 4 0 0 29,112 200,211 -7,144 222,179 Generator 3 0 0 46,587 694,849 -3,022 738,414 Generator 2 0 0 2,590 75,835 -21,273 57,152 Generator 1 0 0 113 4,214 -21,409 -17,083 Boiler 0 0 0 285,888 0 285,888 Other 0 0 343,490 0 0 343,490 System 3,035,716 0 804,799 1,260,998 -52,849 5,048,663 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 202,166 0 25,500 0 0 227,666 Generator 4 0 0 1,939 13,333 -476 14,796 Generator 3 0 0 3,102 46,274 -201 49,175 Generator 2 0 0 172 5,050 -1,417 3,806 Generator 1 0 0 7 281 -1,426 -1,138 Boiler 0 0 0 19,039 0 19,039 Other 0 0 22,875 0 0 22,875 System 202,166 0 53,596 83,977 -3,520 336,220 Component Production Fraction (kWh/yr) Wind turbines 1,041,166 89% Generator 4 22,432 2% Generator 3 100,869 9% Generator 2 10,350 1% Generator 1 593 0% Total 1,175,410 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 755,661 kWh/yr Unmet load 0.000753 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.770 Component Production Fraction (kWh/yr) Generator 4 14,971 2% Generator 3 46,894 5% Generator 2 5,263 1% Generator 1 288 0% Boiler 109,822 12% Excess electricity 755,661 81% Total 932,900 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 496,727 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 119 kW Capacity factor 39.6 % Total production 1,041,166 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 248 % Hours of operation 7,361 hr/yr Levelized cost 0.219 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,551 hr/yr Number of starts 835 starts/yr Operational life 38.7 yr Capacity factor 5.59 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 22,432 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 14,971 kWh/yr Mean thermal output 9.65 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,195 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 90,482 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,482 hr/yr Number of starts 599 starts/yr Operational life 24.2 yr Generator 2 Capacity factor 14.1 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 100,869 kWh/yr Mean electrical output 40.6 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 46,894 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 31,913 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 314,025 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 138 hr/yr Number of starts 100 starts/yr Operational life 435 yr Capacity factor 1.05 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 10,350 kWh/yr Mean electrical output 75.0 kW Min. electrical output 67.7 kW Max. electrical output 93.1 kW Thermal production 5,263 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,483 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 34,273 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.6 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0502 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 593 kWh/yr Mean electrical output 98.9 kW Min. electrical output 93.3 kW Max. electrical output 109 kW Thermal production 288 kWh/yr Mean thermal output 48.1 kW Min. thermal output 46.2 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 194 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,905 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 152,675 Carbon monoxide 291 Unburned hydocarbons 32.2 Particulate matter 21.9 Sulfur dioxide 308 Nitrogen oxides 2,598 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,378,919 Levelized cost of energy $ 0.626/kWh Operating cost $ 156,047/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,035,716 0 382,907 0 0 3,418,623 Generator 4 0 0 30,107 260,875 -6,883 284,100 Generator 3 0 0 47,657 904,235 -2,689 949,203 Generator 2 0 0 1,633 61,789 -21,653 41,769 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 361,260 0 361,260 Other 0 0 343,490 0 0 343,490 System 3,035,716 0 805,831 1,590,033 -52,663 5,378,918 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 202,166 0 25,500 0 0 227,666 Generator 4 0 0 2,005 17,373 -458 18,920 Generator 3 0 0 3,174 60,218 -179 63,213 Generator 2 0 0 109 4,115 -1,442 2,782 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 24,058 0 24,058 Other 0 0 22,875 0 0 22,875 System 202,166 0 53,665 105,890 -3,507 358,213 Component Production Fraction (kWh/yr) Wind turbines 1,041,166 89% Generator 4 23,147 2% Generator 3 104,117 9% Generator 2 6,774 1% Generator 1 212 0% Total 1,175,417 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 755,668 kWh/yr Unmet load 0.000792 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.770 Component Production Fraction (kWh/yr) Generator 4 15,460 2% Generator 3 48,329 5% Generator 2 3,377 0% Generator 1 101 0% Boiler 109,959 12% Excess electricity 755,668 81% Total 932,894 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 496,720 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 119 kW Capacity factor 39.6 % Total production 1,041,166 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 248 % Hours of operation 7,361 hr/yr Levelized cost 0.219 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,604 hr/yr Number of starts 870 starts/yr Operational life 37.4 yr Capacity factor 5.77 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 23,147 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.2 kW Thermal production 15,460 kWh/yr Mean thermal output 9.64 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,494 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 93,417 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,539 hr/yr Number of starts 580 starts/yr Operational life 23.6 yr Generator 2 Capacity factor 14.5 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 104,117 kWh/yr Mean electrical output 41.0 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 48,329 kWh/yr Mean thermal output 19.0 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 32,906 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 323,797 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 87 hr/yr Number of starts 67 starts/yr Operational life 690 yr Capacity factor 0.684 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 6,774 kWh/yr Mean electrical output 77.9 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 3,377 kWh/yr Mean thermal output 38.8 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,249 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 22,126 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 152,538 Carbon monoxide 291 Unburned hydocarbons 32.2 Particulate matter 21.9 Sulfur dioxide 308 Nitrogen oxides 2,594 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,691,620 Levelized cost of energy $ 0.631/kWh Operating cost $ 176,872/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,035,716 0 382,907 0 0 3,418,623 Generator 4 0 0 30,539 316,284 -6,769 340,054 Generator 3 0 0 48,201 1,098,399 -2,520 1,144,080 Generator 2 0 0 1,145 52,712 -21,846 32,011 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 432,519 0 432,519 Other 0 0 343,490 0 0 343,490 System 3,035,716 0 806,319 1,902,156 -52,573 5,691,618 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 202,166 0 25,500 0 0 227,666 Generator 4 0 0 2,034 21,063 -451 22,646 Generator 3 0 0 3,210 73,149 -168 76,191 Generator 2 0 0 76 3,510 -1,455 2,132 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 28,804 0 28,804 Other 0 0 22,875 0 0 22,875 System 202,166 0 53,697 126,676 -3,501 379,038 Component Production Fraction (kWh/yr) Wind turbines 1,041,166 89% Generator 4 23,441 2% Generator 3 105,734 9% Generator 2 4,874 0% Generator 1 212 0% Total 1,175,427 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 755,678 kWh/yr Unmet load 0.000814 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.770 Component Production Fraction (kWh/yr) Generator 4 15,664 2% Generator 3 49,045 5% Generator 2 2,398 0% Generator 1 101 0% Boiler 110,008 12% Excess electricity 755,678 81% Total 932,894 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 496,720 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 119 kW Capacity factor 39.6 % Total production 1,041,166 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 248 % Hours of operation 7,361 hr/yr Levelized cost 0.219 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,627 hr/yr Number of starts 888 starts/yr Operational life 36.9 yr Capacity factor 5.84 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 23,441 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,664 kWh/yr Mean thermal output 9.63 kW Min. thermal output 9.33 kW Max. thermal output 12.6 kW Quantity Value Units Fuel consumption 9,618 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 94,640 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,568 hr/yr Number of starts 562 starts/yr Operational life 23.4 yr Generator 2 Capacity factor 14.7 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 105,734 kWh/yr Mean electrical output 41.2 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 49,045 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 33,401 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 328,669 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 61 hr/yr Number of starts 51 starts/yr Operational life 984 yr Capacity factor 0.492 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 4,874 kWh/yr Mean electrical output 79.9 kW Min. electrical output 74.6 kW Max. electrical output 93.1 kW Thermal production 2,398 kWh/yr Mean thermal output 39.3 kW Min. thermal output 38.0 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,603 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 15,773 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 152,484 Carbon monoxide 290 Unburned hydocarbons 32.2 Particulate matter 21.9 Sulfur dioxide 308 Nitrogen oxides 2,592 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.12 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,387,405 Levelized cost of energy $ 0.716/kWh Operating cost $ 113,259/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,686,716 0 382,907 0 0 4,069,623 Generator 4 0 0 28,587 152,092 -7,282 173,396 Generator 3 0 0 44,935 516,995 -3,535 558,395 Generator 2 0 0 2,815 63,179 -21,184 44,810 Generator 1 0 0 113 3,252 -21,409 -18,045 Boiler 0 0 0 215,735 0 215,735 Other 0 0 343,490 0 0 343,490 System 3,686,716 0 802,847 951,252 -53,411 5,387,404 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 245,520 0 25,500 0 0 271,020 Generator 4 0 0 1,904 10,129 -485 11,547 Generator 3 0 0 2,992 34,430 -235 37,187 Generator 2 0 0 187 4,207 -1,411 2,984 Generator 1 0 0 7 217 -1,426 -1,202 Boiler 0 0 0 14,367 0 14,367 Other 0 0 22,875 0 0 22,875 System 245,520 0 53,466 63,349 -3,557 358,778 Component Production Fraction (kWh/yr) Wind turbines 1,068,879 89% Generator 4 22,073 2% Generator 3 97,146 8% Generator 2 11,112 1% Generator 1 592 0% Total 1,199,802 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 780,054 kWh/yr Unmet load 0.000723 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.779 Component Production Fraction (kWh/yr) Generator 4 14,722 2% Generator 3 45,175 5% Generator 2 5,688 1% Generator 1 288 0% Boiler 107,291 11% Excess electricity 780,054 82% Total 953,218 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 517,044 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 122 kW Capacity factor 40.7 % Total production 1,068,879 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 255 % Hours of operation 7,390 hr/yr Levelized cost 0.254 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,523 hr/yr Number of starts 825 starts/yr Operational life 39.4 yr Capacity factor 5.50 % Fixed generation cost 3.32 $/hr Marginal generation cost 0.346 $/kWhyr Quantity Value Units Electrical production 22,073 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.5 kW Thermal production 14,722 kWh/yr Mean thermal output 9.67 kW Min. thermal output 9.33 kW Max. thermal output 12.8 kW Quantity Value Units Fuel consumption 9,043 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 88,988 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,394 hr/yr Number of starts 606 starts/yr Operational life 25.1 yr Generator 2 Capacity factor 13.5 % Fixed generation cost 3.46 $/hr Marginal generation cost 0.313 $/kWhyr Quantity Value Units Electrical production 97,146 kWh/yr Mean electrical output 40.6 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 45,175 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 30,741 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 302,490 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 150 hr/yr Number of starts 109 starts/yr Operational life 400 yr Capacity factor 1.12 % Fixed generation cost 12.4 $/hr Marginal generation cost 0.237 $/kWhyr Quantity Value Units Electrical production 11,112 kWh/yr Mean electrical output 74.1 kW Min. electrical output 62.0 kW Max. electrical output 93.1 kW Thermal production 5,688 kWh/yr Mean thermal output 37.9 kW Min. thermal output 35.0 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,757 L/yr Specific fuel consumption 0.338 L/kWh Fuel energy input 36,965 kWh/yr Mean electrical efficiency 30.1 % Mean total efficiency 45.4 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0501 % Fixed generation cost 9.90 $/hr Marginal generation cost 0.284 $/kWhyr Quantity Value Units Electrical production 592 kWh/yr Mean electrical output 98.7 kW Min. electrical output 92.5 kW Max. electrical output 109 kW Thermal production 288 kWh/yr Mean thermal output 48.0 kW Min. thermal output 46.0 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 193 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,903 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 149,107 Carbon monoxide 284 Unburned hydocarbons 31.5 Particulate matter 21.4 Sulfur dioxide 301 Nitrogen oxides 2,537 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.45 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,667,614 Levelized cost of energy $ 0.719/kWh Operating cost $ 131,919/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,686,716 0 382,907 0 0 4,069,623 Generator 4 0 0 28,774 197,940 -7,233 219,482 Generator 3 0 0 45,273 675,016 -3,430 716,859 Generator 2 0 0 2,553 74,640 -21,288 55,904 Generator 1 0 0 113 4,210 -21,409 -17,087 Boiler 0 0 0 279,342 0 279,342 Other 0 0 343,490 0 0 343,490 System 3,686,716 0 803,110 1,231,147 -53,361 5,667,613 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 245,520 0 25,500 0 0 271,020 Generator 4 0 0 1,916 13,182 -482 14,617 Generator 3 0 0 3,015 44,953 -228 47,740 Generator 2 0 0 170 4,971 -1,418 3,723 Generator 1 0 0 7 280 -1,426 -1,138 Boiler 0 0 0 18,603 0 18,603 Other 0 0 22,875 0 0 22,875 System 245,520 0 53,484 81,989 -3,554 377,439 Component Production Fraction (kWh/yr) Wind turbines 1,068,879 89% Generator 4 22,180 2% Generator 3 97,985 8% Generator 2 10,179 1% Generator 1 592 0% Total 1,199,814 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 780,066 kWh/yr Unmet load 0.000723 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.779 Component Production Fraction (kWh/yr) Generator 4 14,801 2% Generator 3 45,557 5% Generator 2 5,182 1% Generator 1 288 0% Boiler 107,307 11% Excess electricity 780,066 82% Total 953,201 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 517,027 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 122 kW Capacity factor 40.7 % Total production 1,068,879 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 255 % Hours of operation 7,390 hr/yr Levelized cost 0.254 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,533 hr/yr Number of starts 835 starts/yr Operational life 39.1 yr Capacity factor 5.53 % Fixed generation cost 3.80 $/hr Marginal generation cost 0.448 $/kWhyr Quantity Value Units Electrical production 22,180 kWh/yr Mean electrical output 14.5 kW Min. electrical output 13.7 kW Max. electrical output 21.3 kW Thermal production 14,801 kWh/yr Mean thermal output 9.66 kW Min. thermal output 9.33 kW Max. thermal output 12.7 kW Quantity Value Units Fuel consumption 9,091 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 89,456 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,412 hr/yr Number of starts 602 starts/yr Operational life 24.9 yr Generator 2 Capacity factor 13.7 % Fixed generation cost 3.96 $/hr Marginal generation cost 0.405 $/kWhyr Quantity Value Units Electrical production 97,985 kWh/yr Mean electrical output 40.6 kW Min. electrical output 24.6 kW Max. electrical output 68.1 kW Thermal production 45,557 kWh/yr Mean thermal output 18.9 kW Min. thermal output 12.7 kW Max. thermal output 29.4 kW Quantity Value Units Fuel consumption 31,002 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 305,062 kWh/yr Mean electrical efficiency 32.1 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 136 hr/yr Number of starts 99 starts/yr Operational life 441 yr Capacity factor 1.03 % Fixed generation cost 15.5 $/hr Marginal generation cost 0.307 $/kWhyr Quantity Value Units Electrical production 10,179 kWh/yr Mean electrical output 74.8 kW Min. electrical output 67.6 kW Max. electrical output 93.1 kW Thermal production 5,182 kWh/yr Mean thermal output 38.1 kW Min. thermal output 36.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 3,428 L/yr Specific fuel consumption 0.337 L/kWh Fuel energy input 33,732 kWh/yr Mean electrical efficiency 30.2 % Mean total efficiency 45.5 % Quantity Value Units Hours of operation 6 hr/yr Number of starts 6 starts/yr Operational life 10,000 yr Capacity factor 0.0501 % Fixed generation cost 12.3 $/hr Marginal generation cost 0.368 $/kWhyr Quantity Value Units Electrical production 592 kWh/yr Mean electrical output 98.7 kW Min. electrical output 92.5 kW Max. electrical output 109 kW Thermal production 288 kWh/yr Mean thermal output 48.0 kW Min. thermal output 46.0 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 193 L/yr Specific fuel consumption 0.326 L/kWh Fuel energy input 1,903 kWh/yr Mean electrical efficiency 31.1 % Mean total efficiency 46.3 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 149,061 Carbon monoxide 284 Unburned hydocarbons 31.5 Particulate matter 21.4 Sulfur dioxide 301 Nitrogen oxides 2,535 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 1.83 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 5,990,035 Levelized cost of energy $ 0.723/kWh Operating cost $ 153,391/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,686,716 0 382,907 0 0 4,069,623 Generator 4 0 0 29,694 257,192 -6,991 279,895 Generator 3 0 0 46,381 879,352 -3,086 922,646 Generator 2 0 0 1,614 60,992 -21,660 40,947 Generator 1 0 0 38 1,873 -21,438 -19,528 Boiler 0 0 0 352,960 0 352,960 Other 0 0 343,490 0 0 343,490 System 3,686,716 0 804,123 1,552,369 -53,175 5,990,033 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 245,520 0 25,500 0 0 271,020 Generator 4 0 0 1,977 17,128 -466 18,640 Generator 3 0 0 3,089 58,561 -206 61,444 Generator 2 0 0 107 4,062 -1,442 2,727 Generator 1 0 0 2 125 -1,428 -1,300 Boiler 0 0 0 23,506 0 23,506 Other 0 0 22,875 0 0 22,875 System 245,520 0 53,551 103,381 -3,541 398,911 Component Production Fraction (kWh/yr) Wind turbines 1,068,879 89% Generator 4 22,817 2% Generator 3 101,242 8% Generator 2 6,681 1% Generator 1 212 0% Total 1,199,831 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 780,083 kWh/yr Unmet load 0.000769 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.779 Component Production Fraction (kWh/yr) Generator 4 15,242 2% Generator 3 47,002 5% Generator 2 3,335 0% Generator 1 101 0% Boiler 107,432 11% Excess electricity 780,083 82% Total 953,195 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 517,021 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 122 kW Capacity factor 40.7 % Total production 1,068,879 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 255 % Hours of operation 7,390 hr/yr Levelized cost 0.254 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,582 hr/yr Number of starts 871 starts/yr Operational life 37.9 yr Capacity factor 5.69 % Fixed generation cost 4.36 $/hr Marginal generation cost 0.566 $/kWhyr Quantity Value Units Electrical production 22,817 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,242 kWh/yr Mean thermal output 9.63 kW Min. thermal output 9.33 kW Max. thermal output 12.6 kW Quantity Value Units Fuel consumption 9,360 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 92,098 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,471 hr/yr Number of starts 583 starts/yr Operational life 24.3 yr Generator 2 Capacity factor 14.1 % Fixed generation cost 4.54 $/hr Marginal generation cost 0.511 $/kWhyr Quantity Value Units Electrical production 101,242 kWh/yr Mean electrical output 41.0 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 47,002 kWh/yr Mean thermal output 19.0 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 32,001 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 314,886 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 86 hr/yr Number of starts 66 starts/yr Operational life 698 yr Capacity factor 0.675 % Fixed generation cost 19.0 $/hr Marginal generation cost 0.387 $/kWhyr Quantity Value Units Electrical production 6,681 kWh/yr Mean electrical output 77.7 kW Min. electrical output 71.9 kW Max. electrical output 93.1 kW Thermal production 3,335 kWh/yr Mean thermal output 38.8 kW Min. thermal output 37.4 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 2,220 L/yr Specific fuel consumption 0.332 L/kWh Fuel energy input 21,841 kWh/yr Mean electrical efficiency 30.6 % Mean total efficiency 45.9 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 15.0 $/hr Marginal generation cost 0.465 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 148,924 Carbon monoxide 284 Unburned hydocarbons 31.4 Particulate matter 21.4 Sulfur dioxide 300 Nitrogen oxides 2,532 System Report - ChikLake_WIND_NW_E33.hmr Sensitivity case System architecture Cost summary Net Present Costs Annualized Costs Diesel Price: 2.19 $/L Generator 4 O&M Cost Multiplier: 1.25 Generator 3 O&M Cost Multiplier: 1.25 Generator 2 O&M Cost Multiplier: 1.25 Generator 1 O&M Cost Multiplier: 1.25 Wind turbine3 Northwind 100B/21 Generator 4 45.8 kW Generator 3 81.9 kW Generator 2 113 kW Generator 1 135 kW Total net present cost $ 6,295,314 Levelized cost of energy $ 0.727/kWh Operating cost $ 173,722/yr Component Capital Replacement O&M Fuel Salvage Total ($) ($) ($) ($) ($) ($) Northwind 100B/21 3,686,716 0 382,907 0 0 4,069,623 Generator 4 0 0 30,182 312,440 -6,863 335,759 Generator 3 0 0 46,981 1,070,397 -2,899 1,114,479 Generator 2 0 0 1,070 49,314 -21,876 28,508 Generator 1 0 0 38 2,241 -21,438 -19,159 Boiler 0 0 0 422,613 0 422,613 Other 0 0 343,490 0 0 343,490 System 3,686,716 0 804,668 1,857,005 -53,076 6,295,313 Capital Replacement O&M Fuel Salvage Total Electrical Component ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) ($/yr) Northwind 100B/21 245,520 0 25,500 0 0 271,020 Generator 4 0 0 2,010 20,807 -457 22,360 Generator 3 0 0 3,129 71,284 -193 74,220 Generator 2 0 0 71 3,284 -1,457 1,899 Generator 1 0 0 2 149 -1,428 -1,276 Boiler 0 0 0 28,144 0 28,144 Other 0 0 22,875 0 0 22,875 System 245,520 0 53,587 123,669 -3,535 419,241 Component Production Fraction (kWh/yr) Wind turbines 1,068,879 89% Generator 4 23,152 2% Generator 3 103,036 9% Generator 2 4,563 0% Generator 1 212 0% Total 1,199,842 100% Load Consumption Fraction (kWh/yr) AC primary load 419,749 100% Total 419,749 100% Quantity Value Units Thermal AC Wind Turbine: Northwind 100B/21 Excess electricity 780,093 kWh/yr Unmet load 0.000792 kWh/yr Capacity shortage 0.00 kWh/yr Renewable fraction 0.779 Component Production Fraction (kWh/yr) Generator 4 15,475 2% Generator 3 47,796 5% Generator 2 2,242 0% Generator 1 101 0% Boiler 107,488 11% Excess electricity 780,093 82% Total 953,195 100% Load Consumption Fraction (kWh/yr) Thermal load 436,174 100% Total 436,174 100% Quantity Value Units Excess thermal energy 517,021 kWh/yr Variable Value Units Total rated capacity 300 kW Mean output 122 kW Capacity factor 40.7 % Total production 1,068,879 kWh/yr Variable Value Units Minimum output 0.00 kW Maximum output 301 kW Wind penetration 255 % Hours of operation 7,390 hr/yr Levelized cost 0.254 $/kWh Generator 4 Generator 3 Quantity Value Units Hours of operation 1,608 hr/yr Number of starts 891 starts/yr Operational life 37.3 yr Capacity factor 5.77 % Fixed generation cost 4.88 $/hr Marginal generation cost 0.677 $/kWhyr Quantity Value Units Electrical production 23,152 kWh/yr Mean electrical output 14.4 kW Min. electrical output 13.7 kW Max. electrical output 21.1 kW Thermal production 15,475 kWh/yr Mean thermal output 9.62 kW Min. thermal output 9.33 kW Max. thermal output 12.6 kW Quantity Value Units Fuel consumption 9,501 L/yr Specific fuel consumption 0.410 L/kWh Fuel energy input 93,490 kWh/yr Mean electrical efficiency 24.8 % Mean total efficiency 41.3 % Quantity Value Units Hours of operation 2,503 hr/yr Number of starts 565 starts/yr Operational life 24.0 yr Generator 2 Capacity factor 14.4 % Fixed generation cost 5.08 $/hr Marginal generation cost 0.611 $/kWhyr Quantity Value Units Electrical production 103,036 kWh/yr Mean electrical output 41.2 kW Min. electrical output 24.6 kW Max. electrical output 81.9 kW Thermal production 47,796 kWh/yr Mean thermal output 19.1 kW Min. thermal output 12.7 kW Max. thermal output 34.7 kW Quantity Value Units Fuel consumption 32,550 L/yr Specific fuel consumption 0.316 L/kWh Fuel energy input 320,290 kWh/yr Mean electrical efficiency 32.2 % Mean total efficiency 47.1 % Quantity Value Units Hours of operation 57 hr/yr Number of starts 47 starts/yr Operational life 1,053 yr Capacity factor 0.461 % Fixed generation cost 22.4 $/hr Marginal generation cost 0.464 $/kWhyr Quantity Value Units Electrical production 4,563 kWh/yr Mean electrical output 80.0 kW Min. electrical output 74.7 kW Max. electrical output 93.1 kW Thermal production 2,242 kWh/yr Mean thermal output 39.3 kW Min. thermal output 38.1 kW Max. thermal output 42.5 kW Generator 1 Quantity Value Units Fuel consumption 1,500 L/yr Specific fuel consumption 0.329 L/kWh Fuel energy input 14,756 kWh/yr Mean electrical efficiency 30.9 % Mean total efficiency 46.1 % Quantity Value Units Hours of operation 2 hr/yr Number of starts 2 starts/yr Operational life 30,000 yr Capacity factor 0.0179 % Fixed generation cost 17.6 $/hr Marginal generation cost 0.556 $/kWhyr Quantity Value Units Electrical production 212 kWh/yr Mean electrical output 106 kW Min. electrical output 103 kW Max. electrical output 109 kW Thermal production 101 kWh/yr Mean thermal output 50.4 kW Min. thermal output 49.4 kW Max. thermal output 51.5 kW Quantity Value Units Fuel consumption 68.2 L/yr Specific fuel consumption 0.321 L/kWh Fuel energy input 671 kWh/yr Mean electrical efficiency 31.6 % Mean total efficiency 46.7 % Emissions Pollutant Emissions (kg/yr) Carbon dioxide 148,865 Carbon monoxide 284 Unburned hydocarbons 31.4 Particulate matter 21.4 Sulfur dioxide 300 Nitrogen oxides 2,530