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• 1. [Image] New Geothermal Site Identification and Qualification. Consultant Report

  	This study identifies remaining undeveloped geothermal resources in California and western Nevada, and it estimates the Development costs of each. It has relied on public-domain information and such additional ...
  	Citation × Citation Citation Abstract Copy Title: New Geothermal Site Identification and Qualification. Consultant Report Author: Klein, C.W. Year: 2004 This study identifies remaining undeveloped geothermal resources in California and western Nevada, and it estimates the Development costs of each. It has relied on public-domain information and such additional data as geothermal developers have chosen to make available. Reserve estimation has been performed by volumetric analysis with a probabilistic approach to uncertain input parameters. Incremental geothermal reserves in the California/Nevada study area have a minimum value of 2,800 gross MW and a most-likely value of 4,300 gross MW. For the state of California alone, these values are 2,000 and 3,000 gross MW, respectively. These estimates may be conservative to the extent that they do not take into account resources about which little or no public-domain information is available. The average capital cost of incremental generation capacity is estimated to average $3,100/kW for the California/Nevada study area, and $2,950/kW for the state of California alone. These cost estimates include exploration, confirmation Drilling, Development Drilling, plant construction, and transmission-line costs. For the purposes of this study, a capital cost of $2,400/kW is considered competitive with other renewable resources. The amount of incremental geothermal capacity available at or below $2,400/kW is about 1,700 gross MW for the California/Nevada study area, and the same amount (within 50-MW rounding) for the state of California alone. The capital cost estimates are only approximate, because each developer would bring its own experience, bias, and opportunities to the Development process. Nonetheless, the overall costs per project estimated in this study are believed to be reasonable Title: New Geothermal Site Identification and Qualification. Consultant Report Author: Klein, C.W. Year: 2004 This study identifies remaining undeveloped geothermal resources in California and western Nevada, and it estimates the Development costs of each. It has relied on public-domain information and such additional data as geothermal developers have chosen to make available. Reserve estimation has been performed by volumetric analysis with a probabilistic approach to uncertain input parameters. Incremental geothermal reserves in the California/Nevada study area have a minimum value of 2,800 gross MW and a most-likely value of 4,300 gross MW. For the state of California alone, these values are 2,000 and 3,000 gross MW, respectively. These estimates may be conservative to the extent that they do not take into account resources about which little or no public-domain information is available. The average capital cost of incremental generation capacity is estimated to average $3,100/kW for the California/Nevada study area, and $2,950/kW for the state of California alone. These cost estimates include exploration, confirmation Drilling, Development Drilling, plant construction, and transmission-line costs. For the purposes of this study, a capital cost of $2,400/kW is considered competitive with other renewable resources. The amount of incremental geothermal capacity available at or below $2,400/kW is about 1,700 gross MW for the California/Nevada study area, and the same amount (within 50-MW rounding) for the state of California alone. The capital cost estimates are only approximate, because each developer would bring its own experience, bias, and opportunities to the Development process. Nonetheless, the overall costs per project estimated in this study are believed to be reasonable Close

• 2. [Image] Downhole Heat Exchanger for Shallow Geothermal Systems: Performance, Economics and Applicability

  	Heat exchangers located within the wellbore of shallow geothermal resources are presently being used at several locations in the U.S. These heat exchangers are referred to as downhole heat exchangers. ...
  	Citation × Citation Citation Abstract Copy Title: Downhole Heat Exchanger for Shallow Geothermal Systems: Performance, Economics and Applicability Author: Reistad, G. M. Heat exchangers located within the wellbore of shallow geothermal resources are presently being used at several locations in the U.S. These heat exchangers are referred to as downhole heat exchangers. Such installations can have thermal energy output capacities as high as 1 MW for space heating with source water temperature of 90 to 100°C. This work reports on the performance and economics of downhole heat exchangers relative to the alternative geothermal system which pumps the fluid out of the ground and uses heat exchangers located at the earth's surface. Results indicate that the downhole heat exchange systems for capacity requirements less than about 500 to 100 kW are in general more desirable than the surface heat exchange systems for low capacity (less than about 500 to 1000 kW) requirements and shallow geothermal resources. For higher capacities the surface heat exchange systems become more economical. Furthermore, for large depths, the high capacities available from the surface systems are required in order to make the geothermal energy competitive with other sources Title: Downhole Heat Exchanger for Shallow Geothermal Systems: Performance, Economics and Applicability Author: Reistad, G. M. Heat exchangers located within the wellbore of shallow geothermal resources are presently being used at several locations in the U.S. These heat exchangers are referred to as downhole heat exchangers. Such installations can have thermal energy output capacities as high as 1 MW for space heating with source water temperature of 90 to 100°C. This work reports on the performance and economics of downhole heat exchangers relative to the alternative geothermal system which pumps the fluid out of the ground and uses heat exchangers located at the earth's surface. Results indicate that the downhole heat exchange systems for capacity requirements less than about 500 to 100 kW are in general more desirable than the surface heat exchange systems for low capacity (less than about 500 to 1000 kW) requirements and shallow geothermal resources. For higher capacities the surface heat exchange systems become more economical. Furthermore, for large depths, the high capacities available from the surface systems are required in order to make the geothermal energy competitive with other sources Close

• 3. [Image] Issue Alert: Selling South: BPA Seeks Ways of Marketing Surplus Power to the Pacific Northwest

  	As the Federal wholesaler of electric energy in the Pacific Northwest, SPA currently finds itself with an embarrassment of riches: more power than the Northwest can use. In fact, for at least the next ...
  	Citation × Citation Citation Abstract Copy Title: Issue Alert: Selling South: BPA Seeks Ways of Marketing Surplus Power to the Pacific Northwest Author: Bonneville Power Administration Year: 1985 As the Federal wholesaler of electric energy in the Pacific Northwest, SPA currently finds itself with an embarrassment of riches: more power than the Northwest can use. In fact, for at least the next five years, SPA expects to have enough guaranteed or "firm" surplus energy to serve the entire needs of another Seattle, with energy to spare. SPA also expects to have a surplus of "capacity" (to serve loads in peak periods) for a longer period probably for at least 20 years Title: Issue Alert: Selling South: BPA Seeks Ways of Marketing Surplus Power to the Pacific Northwest Author: Bonneville Power Administration Year: 1985 As the Federal wholesaler of electric energy in the Pacific Northwest, SPA currently finds itself with an embarrassment of riches: more power than the Northwest can use. In fact, for at least the next five years, SPA expects to have enough guaranteed or "firm" surplus energy to serve the entire needs of another Seattle, with energy to spare. SPA also expects to have a surplus of "capacity" (to serve loads in peak periods) for a longer period probably for at least 20 years Close

• 4. [Image] Geothermal Progress Monitor: Report No. 14, December 1992

  	This issue of the Geothermal Progress Monitor, the 14th since its inception in 1980, highlights the anticipated rapid growth in the use of geothermal heat pumps and documents the continued growth in the ...
  	Citation × Citation Citation Abstract Copy Title: Geothermal Progress Monitor: Report No. 14, December 1992 Author: Assistant Secretary for Conservation and Renewable Energy, Geothermal Division Year: 1992 This issue of the Geothermal Progress Monitor, the 14th since its inception in 1980, highlights the anticipated rapid growth in the use of geothermal heat pumps and documents the continued growth in the use of geothermal energy for power generation, both in this country and abroad. In countries with a relatively large demand for new generation capacity, geothermal, if available, is being called on as a preferable alternative to the use of domestic or imported oil. On the other hand, in this country where current demand for new capacity is less, geothermal energy is commonly being put to Use in small power generation units operating on the hot water resource Title: Geothermal Progress Monitor: Report No. 14, December 1992 Author: Assistant Secretary for Conservation and Renewable Energy, Geothermal Division Year: 1992 This issue of the Geothermal Progress Monitor, the 14th since its inception in 1980, highlights the anticipated rapid growth in the use of geothermal heat pumps and documents the continued growth in the use of geothermal energy for power generation, both in this country and abroad. In countries with a relatively large demand for new generation capacity, geothermal, if available, is being called on as a preferable alternative to the use of domestic or imported oil. On the other hand, in this country where current demand for new capacity is less, geothermal energy is commonly being put to Use in small power generation units operating on the hot water resource Close

• 5. [Image] USDA's 2002 Ethanol Cost-of-Production Survey

  	In 2003, the U.S. Department of Agriculture surveyed 21 dry-mill ethanol plants to estimate their 2002 production costs, including both variable (feed stock and plant operation) and capital expenses. These ...
  	Citation × Citation Citation Abstract Copy Title: USDA's 2002 Ethanol Cost-of-Production Survey Author: Shapouri, H. Year: 2005 In 2003, the U.S. Department of Agriculture surveyed 21 dry-mill ethanol plants to estimate their 2002 production costs, including both variable (feed stock and plant operation) and capital expenses. These plants produced about 550 million gallons of ethanol in 2002. Net feedstock costs for the surveyed plants ranged from 39 to 68 cents per gallon in 2002. For cash operating expenses, the average energy expenditure was 17.29 cents per gallon. Labor costs ranged from 3 lo 11 cents per gallon, maintenance costs from 1 lo 7 cents, and administrative costs from 1 to 18 cents. For capital expenditures, new plant construction costs from $1.05 to $3.00 per gallon of ethanol. Average investment to expand existing ethanol production capacity was 50 cents per gallon; hence, expansion tends to cost less than new capacity. Comparison with a 1998 survey of ethanol producers showed that total operating costs in 2002 had changed very little from 1998. It also showed that the average cost of building new plants had dropped, possibly due to designs that emphasize economies of scale Title: USDA's 2002 Ethanol Cost-of-Production Survey Author: Shapouri, H. Year: 2005 In 2003, the U.S. Department of Agriculture surveyed 21 dry-mill ethanol plants to estimate their 2002 production costs, including both variable (feed stock and plant operation) and capital expenses. These plants produced about 550 million gallons of ethanol in 2002. Net feedstock costs for the surveyed plants ranged from 39 to 68 cents per gallon in 2002. For cash operating expenses, the average energy expenditure was 17.29 cents per gallon. Labor costs ranged from 3 lo 11 cents per gallon, maintenance costs from 1 lo 7 cents, and administrative costs from 1 to 18 cents. For capital expenditures, new plant construction costs from $1.05 to $3.00 per gallon of ethanol. Average investment to expand existing ethanol production capacity was 50 cents per gallon; hence, expansion tends to cost less than new capacity. Comparison with a 1998 survey of ethanol producers showed that total operating costs in 2002 had changed very little from 1998. It also showed that the average cost of building new plants had dropped, possibly due to designs that emphasize economies of scale Close

• 6. [Image] Preparation of a Handbook on the Economics of Geothermal Energy Developments; Working Paper No. 6.5 Case Studies of Low Enthalpy Geothermal Energy Developments in France

  	The use of medium and low temperature brines from deep aquifers is well established technology in France. Agence Francaise Pour La Maitrisse de L'Energy (AFME) (1983) report that since 1978 twenty geothermal ...
  	Citation × Citation Citation Abstract Copy Title: Preparation of a Handbook on the Economics of Geothermal Energy Developments; Working Paper No. 6.5 Case Studies of Low Enthalpy Geothermal Energy Developments in France Author: Harrison, R. Year: 1984 The use of medium and low temperature brines from deep aquifers is well established technology in France. Agence Francaise Pour La Maitrisse de L'Energy (AFME) (1983) report that since 1978 twenty geothermal schemes have been put into operation every year and it is foreseen that France will have an installed geothermal heating capacity equivalent to an annual saving of 106 TOE* similar developments. Thus Ungemach (1982) reports that three schemes are under completion in the Po Valley in Italy and that several demonstration projects; e.g. Southampton in the U.K. + and in Denmark and Holland are under examination for the near future. It is estimated that the European Economic Community could have a geothermal heating capacity equivalent to 2 x 106 TOE by the late 1990's, Ungemach (1983) Title: Preparation of a Handbook on the Economics of Geothermal Energy Developments; Working Paper No. 6.5 Case Studies of Low Enthalpy Geothermal Energy Developments in France Author: Harrison, R. Year: 1984 The use of medium and low temperature brines from deep aquifers is well established technology in France. Agence Francaise Pour La Maitrisse de L'Energy (AFME) (1983) report that since 1978 twenty geothermal schemes have been put into operation every year and it is foreseen that France will have an installed geothermal heating capacity equivalent to an annual saving of 106 TOE* similar developments. Thus Ungemach (1982) reports that three schemes are under completion in the Po Valley in Italy and that several demonstration projects; e.g. Southampton in the U.K. + and in Denmark and Holland are under examination for the near future. It is estimated that the European Economic Community could have a geothermal heating capacity equivalent to 2 x 106 TOE by the late 1990's, Ungemach (1983) Close

• 7. [Image] Long-Term Supply Curves for Geothermal Energy - The Impacts of Technology

  	Near-term and long-term supply curves are presented for electric applications of geothermal energy. The GEOCOST model was used to determine the present and future energy production costs for the high-temperature ...
  	Citation × Citation Citation Abstract Copy Title: Long-Term Supply Curves for Geothermal Energy - The Impacts of Technology Author: Fassbender, L.L. Year: 1980 Near-term and long-term supply curves are presented for electric applications of geothermal energy. The GEOCOST model was used to determine the present and future energy production costs for the high-temperature and intermediate-temperature hydrothermal resources identified by the USGS The long-term supply curves illustrate the potential shifts in the near-term supply curve which would result from certain technology improvements currently being pursued. Programs with the most significant potential impacts are those which result in large reductions in drilling cost, those which lead to development of commercial high capacity downhole pumps, and those which lead to large increases in the plant capacity factor. Curves were drawn to show the impacts of individual technology improvements and also to show the cumulative impacts of combinations of technological advances expected to be achieved by 1982 and 1985. Successful completion of all the programs evaluated would result in a cumulative cost reduction of $90 billion (not discounted) in electrical generating costs from the identified hydrothermal resources Title: Long-Term Supply Curves for Geothermal Energy - The Impacts of Technology Author: Fassbender, L.L. Year: 1980 Near-term and long-term supply curves are presented for electric applications of geothermal energy. The GEOCOST model was used to determine the present and future energy production costs for the high-temperature and intermediate-temperature hydrothermal resources identified by the USGS The long-term supply curves illustrate the potential shifts in the near-term supply curve which would result from certain technology improvements currently being pursued. Programs with the most significant potential impacts are those which result in large reductions in drilling cost, those which lead to development of commercial high capacity downhole pumps, and those which lead to large increases in the plant capacity factor. Curves were drawn to show the impacts of individual technology improvements and also to show the cumulative impacts of combinations of technological advances expected to be achieved by 1982 and 1985. Successful completion of all the programs evaluated would result in a cumulative cost reduction of $90 billion (not discounted) in electrical generating costs from the identified hydrothermal resources Close

• 8. [Image] Klamath River - View looking downstream at right abutment of Keno Regulating Dam

  	P12-200-2777A Klamath River - Klamath Project--Oregon. View looking downstream at right abutment of Keno Regulating Dam, which controls level of 18 miles of river and Lake Ewauna- Keno to Klamath Falls. ...
  	Citation × Citation Citation Abstract Copy Title: Klamath River - View looking downstream at right abutment of Keno Regulating Dam Author: United States. Bureau of Reclamation, Lawrence, C.D. Year: 1965, 2008, 2006 P12-200-2777A Klamath River - Klamath Project--Oregon. View looking downstream at right abutment of Keno Regulating Dam, which controls level of 18 miles of river and Lake Ewauna- Keno to Klamath Falls. Dam is opened to full capacity. Flow is about 8200 cfs.; January 26, 1965; Bureau of Reclamation photo by C. D. Lawrence Title: Klamath River - View looking downstream at right abutment of Keno Regulating Dam Author: United States. Bureau of Reclamation, Lawrence, C.D. Year: 1965, 2008, 2006 P12-200-2777A Klamath River - Klamath Project--Oregon. View looking downstream at right abutment of Keno Regulating Dam, which controls level of 18 miles of river and Lake Ewauna- Keno to Klamath Falls. Dam is opened to full capacity. Flow is about 8200 cfs.; January 26, 1965; Bureau of Reclamation photo by C. D. Lawrence Close

• 9. [Image] Klamath River - Construction of Keno By-Pass Channel near Keno, Oregon

  	P12-200-2791A Klamath River - Klamath Project--Oregon. Employees of M-K Co., under contract with PP&L Co., drilling rock and placing explosive for excavation of 100' X 12' X 3500' channel through Keno ...
  	Citation × Citation Citation Abstract Copy Title: Klamath River - Construction of Keno By-Pass Channel near Keno, Oregon Author: United States. Bureau of Reclamation, Lawrence, C.D. Year: 1965, 2008, 2006 P12-200-2791A Klamath River - Klamath Project--Oregon. Employees of M-K Co., under contract with PP&L Co., drilling rock and placing explosive for excavation of 100' X 12' X 3500' channel through Keno reef area to increase capacity of river. Channel will facilitate emergency drainage of flooded lands upstream and later be part of power development; March 3, 1965; Bureau of Reclamation photo by C. D. Lawrence Title: Klamath River - Construction of Keno By-Pass Channel near Keno, Oregon Author: United States. Bureau of Reclamation, Lawrence, C.D. Year: 1965, 2008, 2006 P12-200-2791A Klamath River - Klamath Project--Oregon. Employees of M-K Co., under contract with PP&L Co., drilling rock and placing explosive for excavation of 100' X 12' X 3500' channel through Keno reef area to increase capacity of river. Channel will facilitate emergency drainage of flooded lands upstream and later be part of power development; March 3, 1965; Bureau of Reclamation photo by C. D. Lawrence Close

• 10. [Image] PUMPING PLANT 9, Tule Lake Sump 2

  	KP-2545-R2-Klamath Project - PUMPING PLANT 9, Tule Lake Sump 2. View of pumping units taken from bridge deck. Units are 25 cfs capacity at 15 feet head; December 26, 1959; Photo by K.J. Greene
  	Citation × Citation Citation Abstract Copy Title: PUMPING PLANT 9, Tule Lake Sump 2 Author: United States. Bureau of Reclamation, Greene, K.J. Year: 1959, 2008, 2006 KP-2545-R2-Klamath Project - PUMPING PLANT 9, Tule Lake Sump 2. View of pumping units taken from bridge deck. Units are 25 cfs capacity at 15 feet head; December 26, 1959; Photo by K.J. Greene Title: PUMPING PLANT 9, Tule Lake Sump 2 Author: United States. Bureau of Reclamation, Greene, K.J. Year: 1959, 2008, 2006 KP-2545-R2-Klamath Project - PUMPING PLANT 9, Tule Lake Sump 2. View of pumping units taken from bridge deck. Units are 25 cfs capacity at 15 feet head; December 26, 1959; Photo by K.J. Greene Close