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Sample records for wellhead reservoir temp

  1. Property:USGSMeanReservoirTemp | Open Energy Information

    Open Energy Info (EERE)

    to: navigation, search Property Name USGSMeanReservoirTemp Property Type Temperature Description Mean estimated reservoir temperature at location based on the USGS 2008 Geothermal...

  2. Dixie Meadows Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    of Geofluid: Sanyal Classification (Wellhead): Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification (Reservoir): Depth to Top of Reservoir:...

  3. Drum Mountain Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    of Geofluid: Sanyal Classification (Wellhead): Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification (Reservoir): Depth to Top of Reservoir:...

  4. Blackfoot Reservoir Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  5. Blackfoot Reservoir Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  6. Hot Pot Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    of Replacement Wells: Average Temperature of Geofluid: Sanyal Classification (Wellhead): Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification...

  7. Tungsten Mountain Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    of Replacement Wells: Average Temperature of Geofluid: Sanyal Classification (Wellhead): Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification...

  8. McGuinness Hills Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    of Replacement Wells: Average Temperature of Geofluid: Sanyal Classification (Wellhead): Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification...

  9. Jersey Valley Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    of Replacement Wells: Average Temperature of Geofluid: Sanyal Classification (Wellhead): Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification...

  10. Mudline subsea wellhead system

    SciTech Connect (OSTI)

    Milberger, L.J.; Thames, E.E.

    1993-08-31

    In a subsea wellhead system, an improved means is described for allowing the well to be drilled with a mudline suspension system and completed with a subsea pressure control system, comprising in combination: an outer wellhead housing for location on a subsea floor, having a lower end adapted to be secured to a conductor pipe extending into the well; conductor connector means for releasably securing a string of conductor riser to the outer wellhead housing to extend to the surface; a cement return port extending through the outer wellhead housing; an inner wellhead housing having a lower end adapted to be secured to a string of outer casing, the inner wellhead housing having a bore containing an internal landing shoulder; outer casing connector means for connecting the inner wellhead housing to outer casing riser and for lowering the outer casing riser and inner wellhead housing through the conductor riser with the inner wellhead housing landing in the outer wellhead housing; seal means for sealing the inner wellhead housing to the outer wellhead housing above the cement return port; a first casing hanger having an internal mudline latch profile; intermediate casing connector means; a second casing hanger having an external latch that latches into the internal mudline latch profile in the first casing hanger; inner casing connector means; and the conductor riser, outer casing riser, intermediate casing riser, and inner casing riser allowing the well to be drilled with a mudline suspension system and pressure control equipment at the surface, the inner casing connector means, intermediate casing connector means, outer casing connector means, and conductor connector means being subsequently releasable to remove the inner casing riser, intermediate casing riser, outer casing riser and conductor riser for subsea pressure control completion.

  11. Simplified subsea production wellhead

    SciTech Connect (OSTI)

    Lewis, H.R.

    1980-10-28

    A simplified subsea production wellhead which permits (1) pumpdown tool operations for routine well maintenance and (2) vertical entry to the wellbore for major workover operations. The wellhead can be lowered by the production pipeline to a wellhead site on the sea floor. The production wellhead includes a diverter spool for releasably attaching to a subsea well. Pumpdown tools can be used with the diverter spool. If vertical entry of the subsea well is required, the diverter spool can be released, raised and moved horizontally to one side of the subsea well, giving vertical entry. After workover operations, the diverter spool is again moved over the subsea well and reattached.

  12. Subsea wellhead seal assembly

    SciTech Connect (OSTI)

    Gullion, S.D.

    1988-07-26

    An annular subsea wellhead seal assembly is described for sealing against the walls in a subsea wellhead annulus above a landing seat at the lower end of the annulus comprising: an annular body having an outwardly and downwardly flaring outer skirt and an inwardly and downwardly flaring inner skirt extending from it slower surface, a landing ring having lower landing surface for landing on a landing seat at the lower end of the subsea wellhead annulus in which the assembly is to seal, and an upper flat reaction surface which is positioned immediately under and engagable with the lower ends of the skirts; and means connecting the body and the landing ring for relative movement toward each other; downward movement of the body with respect to the landing ring spreading the skirts outward and inward, respectively, into a substantially horizontal digging engagement set position with the walls of the annulus to be sealed.

  13. Natural Gas Wellhead Price

    Gasoline and Diesel Fuel Update (EIA)

    Quantity of Production Imputed Wellhead Value Wellhead Price Marketed Production Period: Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By: Data Series Area 2010 2011 2012 2013 2014 2015 View History U.S. 4.48 3.95 2.66 NA NA NA 1922-2015 Alabama 4.46 1967-2010 Alaska 3.17 1967-2010 Arizona 4.11 1967-2010 Arkansas 3.84 1967-2010 California 4.87 1967-2010 Colorado 3.96 1967-2010 Florida NA 1967-2010

  14. Natural Gas Wellhead Price

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price Marketed Production Period: Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By: Data Series Area Jul-15 Aug-15 Sep-15 Oct-15 Nov-15 Dec-15 View History U.S. NA NA NA NA NA NA 1973-2015

  15. Property:SanyalTempWellhead | Open Energy Information

    Open Energy Info (EERE)

    Area + Moderate Temperature + Blue Mountain Geothermal Area + Moderate Temperature + Brady Hot Springs Geothermal Area + Low Temperature + C Chena Geothermal Area + Extremely...

  16. Wellhead with non-ferromagnetic materials

    DOE Patents [OSTI]

    Hinson, Richard A [Houston, TX; Vinegar, Harold J [Bellaire, TX

    2009-05-19

    Wellheads for coupling to a heater located in a wellbore in a subsurface formation are described herein. At least one wellhead may include a heater located in a wellbore in a subsurface formation; and a wellhead coupled to the heater. The wellhead may be configured to electrically couple the heater to one or more surface electrical components. The wellhead may include at least one non-ferromagnetic material such that ferromagnetic effects are inhibited in the wellhead. Systems and methods for using such wellheads for treating a subsurface formation are described herein.

  17. Nevada Natural Gas Wellhead (Million Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 2/29/2016 Next Release Date: 3/31/2016 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value Nevada Natural Gas Wellhead Value and Marketed Production

  18. Non intrusive sensors -- An answer to annulus pressure monitoring in subsea wellhead equipment

    SciTech Connect (OSTI)

    Adamek, F.C.; Jennings, C.; Aarskog, A.

    1995-12-01

    On offshore platform and jackup surface wellhead completions, there is the potential for leakage from the high pressure production tubing and casing strings into the low pressure outer casing string, or from poor cementing jobs. Historically, these completions maintain the capability of regularly monitoring wellhead annulus pressure so that appropriate action can be taken should a leak be detected. In the past, subsea completions have been oil producers, however, gas production, extreme reservoir pressures, and deeper waters are becoming common place. Although subsea wellhead technology and reliability have significantly improved with the introduction of the metal-to-metal sealing system, the potential for annulus pressure buildup still exists. Up to the present, the ability to monitor pressure beyond the first casing string has been virtually non-existent. This paper describes the design, development, testing, and application of non intrusive sensor technology for pressure measurement in subsea wellheads and production trees. The data and test results define and describe the phenomenon of ``inverse magnetostriction``. This phenomenon allows magnetic sensors to non intrusively penetrate three to four inches of steel in a subsea wellhead housing and measure annulus pressure from less than 30 psi to more than 15,000 psi. In addition, test data, charts, and graphs illustrate the sensor`s capability of differentiating between pressure, tension, compression, and bending stress imposed on the wellhead. The electronic interface description details how the data is obtained from the sensors, stored, and later transmitted to existing control systems or to the user interface at the surface via an ROV.

  19. Kalex Advanced Low Temp Geothemal Power Cycle

    Broader source: Energy.gov [DOE]

    Kalex Advanced Low Temp Geothemal Power Cycle presentation at the April 2013 peer review meeting held in Denver, Colorado.

  20. Independent load support in an 18 3/4-in. , 15,000-psi subsea wellhead

    SciTech Connect (OSTI)

    Cowan, W.S.

    1993-03-01

    Previous-generation subsea wellhead equipment was conceived as an extension of well-known surface wellhead equipment. Contemporary performance criteria for subsea wellhead equipment require new technology from the designer/manufacturer. This paper describes the role of a single design concept, independent load support, in addressing these criteria and illustrates the resulting configuration of a severe-service subsea wellhead system.

  1. Standardized wellheads proven economical for subsea operations

    SciTech Connect (OSTI)

    Moreira, C.C.; Silva Paulo, C.A. )

    1994-05-02

    A standardization program for subsea wellheads and completion equipment has made development of Brazil's offshore fields more economical and efficient. The resulting operational flexibility associated with the use of field-proven equipment and procedures saves rig time and can reduce production loss during workovers. Additionally, investments can be rationalized economically by installing part of the completion equipment at the end of the drilling job and then delaying purchase and installation of the christmas tree and the flow lines until installation of the production platform. Savings are also realized from the reduction in the number of spare parts and tools. Moreover, the savings related to improved operations exceed considerably those from equipment acquisition and storage. Thus, the greatest benefit is the operational flexibility. The paper discusses initial standards, the subsea programs, philosophy, implementation, diver-assisted trees, diverless trees, and economics.

  2. Hybrid Rotor Compression for Multiphase and Liquids-Rich Wellhead

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    but also allows for compression of wet gas, or gas that contains liquid content. At many natural gas wellheads, liquids-typically heavier hydrocarbons and water-are present in the...

  3. Nevada Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's -- NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 2/29/2016 Next Release Date: 3/31/2016 Referring Pages: Natural Gas Wellhead Price Nevada Natural Gas Prices Natural Gas Wellhead Price

  4. Property:MeanReservoirTemp | Open Energy Information

    Open Energy Info (EERE)

    1,010.07 R + Amatitlan Geothermal Area + 513.15 K240 C 464 F 923.67 R + B Bac-Man Laguna Geothermal Area + 543.15 K270 C 518 F 977.67 R + Bad Blumau Geothermal...

  5. Property:GeochemReservoirTemp | Open Energy Information

    Open Energy Info (EERE)

    pages using this property. C Chena Geothermal Area + 383.15 K110 C 230 F 689.67 R + F Fenton Hill HDR Geothermal Area + 505.15 K232 C 449.6 F 909.27 R + L Lightning...

  6. Property:SanyalTempReservoir | Open Energy Information

    Open Energy Info (EERE)

    Area + High Temperature + C Chena Geothermal Area + Very Low Temperature + D Desert Peak Geothermal Area + Moderate Temperature + F Fenton Hill HDR Geothermal Area + High...

  7. Arizona Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Arizona Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 26 10 0 0 0 0 1,360 1990's 2,125 1,225 730 548 691 500 405 401 411 439 2000's 332 266 243 426 306 211 588 634 503 695 2010's 165 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid

  8. Imputed Wellhead Value of Natural Gas Marketed Production

    Gasoline and Diesel Fuel Update (EIA)

    Thousand Dollars) Data Series: Quantity of Production Imputed Wellhead Value Wellhead Price Marketed Production Period: Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By: Data Series Area 2008 2009 2010 2011 2012 2013 View History U.S. 1989-2006 Alabama 2,489,704 1,020,599 994,688 0 0 0 1989-2013 Alaska 2,944,546 1,163,554 1,185,249 0 0 0 1989-2013 Arizona 3,710 2,269 753 0 0 0 1989-2013 Arkansas 3,891,921

  9. Maryland Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Maryland Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 31 60 39 20 44 29 34 1990's 22 29 33 28 26 22 0 118 63 18 2000's 34 32 22 48 34 46 NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual

  10. Missouri Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Missouri Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 4 4 4 4 4 4 1990's 7 19 27 14 8 16 25 5 0 2000's 0 0 0 0 0 0 2010's 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date:

  11. Illinois Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Illinois Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 1,030 1,530 1,324 1,887 1,371 1,338 1,477 1990's 677 466 346 250 333 0 0 0 0 0 2000's 0 0 NA 0 NA NA NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid

  12. Indiana Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Indiana Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 135 394 367 365 217 412 416 1990's 399 232 174 192 107 249 360 526 615 855 2000's 899 1,064 1,309 1,464 3,401 3,135 2,921 3,606 4,701 4,927 2010's 6,802 - = No Data Reported; -- = Not Applicable; NA = Not Available;

  13. Using geographic information systems in the delineation of wellhead protection areas

    SciTech Connect (OSTI)

    Shafer, J.M. . Earth Sciences and Resources Inst.); Horton, C.A. . Dept. of Civil Engineering)

    1994-03-01

    The 1986 amendments to the Safe Drinking Water Act established the nationwide wellhead protection program to be administered by the US Environmental Protection Agency. Although individual states have the responsibility to implement wellhead protection, the US EPA provides technical guidance, and approves each wellhead protection plan prepared by the states. A major aspect of wellhead protection strategies is the delineation of wellhead protection areas. These are zones around municipal water supply wells that receive special land use considerations intended to minimize the threat of contamination of the wells. The US EPA has recommended several technical approaches to delineating wellhead protection areas, ranging in sophistication from simple concentric circles around wells to irregular areas determined from groundwater flow and transport analyses. Regardless of the wellhead protection area delineation technique, the resulting area surrounding the municipal well must be accurately mapped. A geographic information system (GIS) approach to mapping the results of wellhead protection area delineation is demonstrated. Using hypothetical groundwater flow regimes, each EPA recommended approach to wellhead protection area delineation is presented in a GIS format. A visual comparison of delineation techniques in terms of area and configuration of the resulting wellhead protection areas is made. Finally, the advantages of using a GIS for representing wellhead protection areas is provided.

  14. Tempe Transportation Division: LNG Turbine Hybrid Electric Buses

    SciTech Connect (OSTI)

    Not Available

    2002-02-01

    Fact sheet describes the performance of liquefied natural gas (LNG) turbine hybrid electric buses used in Tempe's Transportation Division.

  15. Missouri Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Missouri Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.25 0.29 0.13 1970's 0.24 0.23 0.22 0.24 0.30 0.33 0.34 0.40 1980's 3.75 3.50 3.75 3.75 3.75 3.50 1990's 1.57 1.32 1.56 1.57 1.49 1.70 1.56 1.70 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 2/29/2016

  16. Florida Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Florida Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.15 0.15 0.16 1970's 0.30 0.32 0.34 0.54 0.97 0.98 1.09 1.39 1.57 1980's 1.73 2.71 2.46 2.33 2.57 2.43 1.20 1.68 1.53 2.05 1990's 2.25 2.46 2.51 2.17 1.28 1.24 2000's NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual

  17. Illinois Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Illinois Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.12 0.13 0.14 1970's 0.16 0.18 0.28 0.35 0.40 0.70 0.99 1.20 1.29 1.86 1980's 1.90 2.47 2.62 2.84 2.78 2.77 2.57 2.24 2.19 2.15 1990's 2.11 2.17 2.15 2.30 2.40 2000's NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual

  18. Alabama Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Alabama Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Alabama Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 59,051 56,685 42,925 34,164 35,674 45,488 41,614 1990's 37,229 35,972 51,219 75,474 70,489 54,964 493,069 583,370 560,414 544,020 2000's 521,215 376,241 370,753 348,722 304,212 285,237 274,176 259,062

  19. Alaska Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Alaska Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Alaska Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 211,569 211,579 222,637 304,841 271,120 228,284 192,760 1990's 191,798 200,557 206,259 224,786 201,891 227,797 193,278 191,017 192,982 186,727 2000's 189,896 197,735 200,871 199,616 413,667 502,887 494,323

  20. Arkansas Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Arkansas Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 78,097 75,575 86,552 68,206 42,688 102,046 42,226 1990's 99,456 83,864 85,177 122,596 24,326 180,117 76,671 71,449 61,012 54,382 2000's 55,057 16,901 161,871 166,329 183,299 190,533 193,491 269,886 446,551 680,613

  1. Michigan Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Michigan Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 138,910 144,537 131,855 127,287 146,996 146,145 155,988 1990's 106,193 189,497 190,637 199,746 216,268 238,203 245,740 305,950 278,076 277,364 2000's 296,556 275,036 274,476 236,987 259,681 261,112 NA NA 153,130

  2. Mississippi Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Mississippi Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 211,116 206,871 178,426 197,217 195,299 196,912 148,167 1990's 149,012 126,637 129,340 131,450 105,646 95,349 88,805 98,075 88,723 83,232 2000's 70,965 76,986 112,979 133,901 145,692 52,923 60,531 73,460 96,641

  3. Montana Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Montana Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 47,751 47,534 46,113 42,203 42,814 47,748 52,044 1990's 45,998 48,075 50,359 58,810 51,953 46,739 46,868 50,409 51,967 55,780 2000's 67,294 78,493 86,075 86,027 90,771 101,666 106,843 110,942 802,619 293,941 2010's

  4. Nebraska Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Nebraska Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 2,091 2,300 1,944 1,403 1,261 910 878 1990's 793 785 1,177 1,375 2,098 1,538 1,332 1,194 1,285 1,049 2000's 879 883 892 1,168 1,172 1,172 NA 1,555 3,082 2,908 2010's 2,231 - = No Data Reported; -- = Not Applicable;

  5. New Mexico Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) New Mexico Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 884,517 925,298 880,307 676,886 790,639 752,629 833,593 1990's 949,735 1,029,824 1,274,220 1,489,052 1,510,804 1,480,327 1,553,103 1,540,157 1,483,370 1,511,671 2000's 1,685,664 1,670,644 1,614,045 1,576,639

  6. New York Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) New York Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 17,836 25,200 31,561 22,964 25,676 23,455 20,433 1990's 25,023 21,704 22,543 20,620 19,684 17,325 0 15,415 15,415 15,426 2000's 17,166 27,187 35,941 35,044 45,436 54,377 55,344 54,942 50,320 44,849 2010's 35,241 -

  7. North Dakota Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) North Dakota Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 69,319 60,111 62,371 58,593 51,671 21,240 12,290 1990's 11,537 5,138 3,994 4,420 0 0 0 52,401 53,185 52,862 2000's 48,714 57,949 57,015 57,808 59,513 57,972 53,675 54,745 52,469 59,369 2010's 81,837 - = No Data

  8. Ohio Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Ohio Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 149,096 184,651 180,458 180,287 164,960 166,690 159,730 1990's 154,619 146,189 143,381 135,939 130,855 125,085 119,251 116,246 108,542 102,505 2000's 98,551 97,272 103,158 120,081 119,847 83,523 86,315 88,095 84,858

  9. Oklahoma Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Oklahoma Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 1,730,061 1,985,869 1,936,341 1,917,493 2,004,797 2,106,632 2,185,204 1990's 2,186,153 2,119,161 1,937,224 2,005,971 1,879,257 1,765,788 1,751,487 1,452,233 1,644,531 1,577,961 2000's 1,612,890 1,477,058 1,456,375

  10. Oregon Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Oregon Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 3 2,790 4,080 4,600 3,800 4,000 2,500 1990's 2,815 2,741 2,580 4,003 3,221 1,923 1,439 1,173 1,067 1,291 2000's 1,214 1,069 837 688 467 433 NA 390 751 751 2010's 1,376 - = No Data Reported; -- = Not Applicable; NA =

  11. Pennsylvania Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Pennsylvania Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 118,372 166,342 150,234 159,889 163,318 167,089 191,774 1990's 177,609 152,500 138,675 189,443 187,113 177,139 0 0 0 0 2000's 0 0 0 0 NA NA NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA =

  12. South Dakota Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) South Dakota Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 1,846 1,947 2,558 2,231 3,431 3,920 4,369 1990's 881 93 1,006 854 1,000 848 0 687 772 702 2000's 648 563 531 550 531 446 455 422 1,099 NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available;

  13. Tennessee Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Tennessee Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 3,950 5,022 4,686 3,464 2,707 2,100 1,900 1990's 2,067 1,856 1,770 1,660 1,990 1,820 1,690 1,510 1,420 1,230 2000's 1,150 2,000 2,050 1,803 2,100 2,200 2,663 3,942 4,700 5,478 2010's 5,144 - = No Data Reported; --

  14. Texas Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Texas Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 6,227,995 6,630,246 6,367,936 6,465,964 6,414,021 6,386,544 6,276,968 1990's 6,476,032 6,066,256 5,893,069 5,769,437 5,834,671 5,592,323 4,684,140 4,716,304 4,777,945 5,719,128 2000's 5,869,901 5,159,233 5,166,315

  15. Utah Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Utah Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 63,158 74,698 52,324 21,491 48,654 49,378 58,356 1990's 57,098 62,241 86,682 93,894 154,907 153,804 168,944 174,275 190,230 194,413 2000's 218,283 215,527 250,118 202,784 250,261 267,766 319,268 NA 276,340 389,830

  16. Virginia Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Virginia Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 4,342 8,928 15,041 15,427 19,223 18,424 17,935 1990's 14,283 14,906 24,734 37,840 50,259 49,818 0 0 0 0 2000's 0 0 0 0 NA NA NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W =

  17. Oregon Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Oregon Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1970's 2.00 1980's 2.40 2.60 3.33 3.33 2.78 2.40 2.00 1.45 1.60 1.40 1990's 1.39 1.42 1.29 1.70 2.06 0.93 2.26 2.19 2.38 2.52 2000's 2.69 3.66 3.97 4.48 3.89 4.25 NA 5.27 5.33 4.00 2010's 4.92 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual

  18. Pennsylvania Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Pennsylvania Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.28 0.28 0.28 1970's 0.28 0.27 0.30 0.42 0.44 0.67 0.68 0.80 0.86 1.33 1980's 2.13 2.33 2.80 3.00 3.25 3.16 2.50 2.25 2.15 2.40 1990's 2.35 2.20 1.95 2.71 2.76 2.84 2000's NA NA NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid

  19. California Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) California Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 282,639 343,079 361,739 329,366 346,720 327,399 283,509 1990's 275,738 211,841 195,515 76,381 199,649 263 37,823 219,216 264,810 382,715 2000's 323,864 328,778 309,399 293,691 276,520 274,817 278,933 268,016

  20. Colorado Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Colorado Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 139,820 143,552 126,037 163,684 164,557 191,544 216,737 1990's 242,997 271,159 314,105 388,016 441,343 511,513 559,473 637,375 696,321 705,477 2000's 735,332 800,712 819,205 989,678 1,058,383 1,106,993 1,170,819

  1. Florida Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Florida Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 25,630 18,897 13,162 3,004 1,893 1,883 1,437 1990's 1,443 2,096 3,849 2,612 4,940 3,545 0 0 0 0 2000's 0 0 NA 0 NA NA NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld

  2. Kansas Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Kansas Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 366,189 494,641 532,092 465,695 458,426 577,815 588,757 1990's 555,187 630,155 640,583 668,640 714,659 721,436 712,796 678,652 603,586 553,419 2000's 525,430 480,145 454,901 418,893 397,121 377,229 372,029 366,859

  3. Kentucky Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Kentucky Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 46,720 61,518 73,126 80,195 70,125 44,725 72,417 1990's 75,333 78,904 79,690 86,966 73,081 74,754 81,435 79,547 81,868 76,770 2000's 81,545 81,723 88,259 87,609 94,259 92,795 95,320 95,437 114,116 NA 2010's 135,355

  4. Louisiana Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Louisiana Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 3,149,192 3,650,412 3,179,306 2,986,468 3,243,795 3,158,903 3,066,789 1990's 3,780,551 3,355,867 3,404,963 3,454,646 3,562,360 3,709,015 3,976,305 5,398,216 5,410,523 5,265,670 2000's 3,587,815 1,529,733 1,365,925

  5. Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.30 0.30 0.30 1970's 0.31 0.31 0.32 0.33 0.51 0.51 1.14 1.26 1.31 1.68 1980's 2.85 2.15 3.69 3.30 3.00 3.02 2.45 2.08 2.08 2.19 1990's 2.30 1.88 1.85 2.29 2.15 1.72 2000's NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of

  6. West Virginia Quantity of Production Associated with Reported Wellhead

    U.S. Energy Information Administration (EIA) Indexed Site

    Value (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) West Virginia Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 130,078 143,730 144,883 135,431 160,000 174,942 177,192 1990's 95,271 198,605 202,775 171,024 55,756 50,439 0 0 0 0 2000's 0 0 NA 0 NA NA NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable;

  7. Wyoming Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Wyoming Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 395,656 447,615 416,565 352,858 407,863 471,095 623,915 1990's 690,356 711,799 765,254 63,667 14,283 12,449 27,821 719,933 1,004,020 1,079,375 2000's 1,240,038 1,359,868 1,533,724 1,561,322 1,724,725 1,729,760

  8. Low-Temp Success Stories | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Low-Temp Success Stories Low-Temp Success Stories June 9, 2015 Low-Temp Success Stories Energy Department Honored for Inroads in Geothermal Energy As renewable energy takes a stronger role in supplying the U.S. grid, geothermal power could support a more flexible role to balance the intermittent and variable capacity of wind and solar. June 5, 2015 Geothermal energy, traditionally a baseload power source among renewables, is poised to emerge also as a flexible power source, balancing

  9. Mississippi Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Mississippi Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.17 0.17 0.18 1970's 0.18 0.21 0.27 0.23 0.29 0.50 0.71 0.73 1.15 1.60 1980's 2.32 3.21 3.91 3.78 3.47 3.17 2.13 1.94 1.86 1.97 1990's 1.76 1.66 1.64 1.73 1.49 1.24 1.66 1.73 1.42 1.63 2000's 3.30 3.93 3.06 5.13 5.83 8.54 6.84 6.70 8.80 3.73 2010's 4.17 - = No Data Reported; -- = Not

  10. Montana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Montana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.08 0.09 0.10 1970's 0.10 0.12 0.12 0.24 0.25 0.43 0.45 0.72 0.85 1.21 1980's 1.45 1.91 2.15 2.41 2.46 2.39 2.05 1.80 1.70 1.55 1990's 1.79 1.66 1.62 1.55 1.46 1.36 1.41 1.59 1.53 1.68 2000's 2.84 3.12 2.39 3.73 4.51 6.57 5.53 5.72 7.50 3.16 2010's 3.64 - = No Data Reported; -- = Not Applicable;

  11. Nebraska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Nebraska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.17 0.18 0.17 1970's 0.17 0.18 0.18 0.18 0.34 0.54 0.51 0.65 0.68 0.85 1980's 0.83 1.45 1.99 2.93 2.24 3.01 2.82 2.42 2.66 2.23 1990's 2.26 2.06 1.78 1.81 1.60 1.19 1.43 1.53 1.30 1.36 2000's 2.26 2.16 1.52 3.17 3.22 4.29 NA 4.86 6.22 2.97 2010's 3.98 - = No Data Reported; -- = Not Applicable;

  12. Colorado Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Colorado Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.13 0.13 0.14 1970's 0.15 0.16 0.16 0.18 0.20 0.26 0.48 0.81 0.84 1.41 1980's 1.47 1.97 3.17 3.38 3.43 2.90 2.05 1.76 1.59 1.52 1990's 1.55 1.41 1.37 1.61 1.39 0.95 1.37 2.23 1.90 2.18 2000's 3.67 3.84 2.41 4.54 5.21 7.43 6.12 4.57 6.94 3.21 2010's 3.96 - = No Data Reported; -- = Not Applicable;

  13. Indiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Indiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.23 0.24 0.23 1970's 0.24 0.25 0.15 0.14 0.14 0.39 0.52 0.69 0.71 1.05 1980's 1.35 2.08 1.55 2.09 3.38 2.51 1.23 1.71 1.57 1.71 1990's 2.01 1.72 2.01 2.09 1.97 1.90 2.30 2.18 2.09 2.19 2000's 3.51 3.28 3.11 5.41 6.30 9.11 6.01 5.78 7.58 4.05 2010's 4.13 - = No Data Reported; -- = Not Applicable;

  14. Kansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Kansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.13 0.14 0.14 1970's 0.14 0.14 0.14 0.16 0.17 0.17 0.42 0.48 0.57 0.76 1980's 0.77 0.92 1.51 1.57 1.49 1.27 1.21 1.15 1.36 1.44 1990's 1.56 1.37 1.54 1.80 1.60 1.36 1.92 2.05 1.70 1.80 2000's 3.21 3.66 2.61 4.33 4.94 6.51 5.61 5.69 6.85 3.16 2010's 4.23 - = No Data Reported; -- = Not Applicable;

  15. Kentucky Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Kentucky Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.24 0.25 0.25 1970's 0.25 0.25 0.25 0.35 0.50 0.54 0.55 0.55 0.58 0.95 1980's 0.89 1.01 1.52 1.51 1.70 2.39 1.88 1.82 2.56 2.13 1990's 2.24 2.03 1.92 2.28 2.24 1.64 2.55 2.66 2.39 2.07 2000's 3.16 4.78 3.01 4.54 5.26 6.84 8.83 7.35 8.42 NA 2010's 4.47 - = No Data Reported; -- = Not Applicable;

  16. Louisiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Louisiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.19 0.19 0.19 1970's 0.19 0.20 0.20 0.22 0.31 0.42 0.46 0.70 0.84 1.11 1980's 1.61 2.07 2.60 2.67 2.73 2.66 2.21 1.78 1.81 1.82 1990's 1.83 1.73 1.73 2.14 2.08 1.58 2.33 2.36 2.02 2.22 2000's 3.68 3.99 3.20 5.64 5.96 8.72 6.93 7.02 8.73 3.82 2010's 4.23 - = No Data Reported; -- = Not

  17. Maryland Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Maryland Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.26 0.26 0.25 1970's 0.25 0.24 0.21 0.23 0.24 0.27 0.32 0.39 0.61 1.04 1980's 0.46 0.48 0.78 0.55 0.55 0.59 0.65 0.55 0.93 0.85 1990's 1.14 1.55 1.91 2.44 1.37 1.42 2.23 2.60 2.73 2000's 3.75 4.15 5.98 4.50 6.25 7.43 NA NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not

  18. Michigan Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Michigan Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.25 0.25 0.26 1970's 0.27 0.26 0.31 0.39 0.50 0.63 0.89 1.01 1.20 1.74 1980's 2.35 2.86 3.19 3.58 3.76 3.60 3.60 3.24 3.18 3.16 1990's 3.00 2.79 2.71 2.38 1.96 1.67 2.21 2.19 1.77 1.77 2000's 2.44 3.47 2.16 4.01 3.85 5.30 NA NA 5.63 3.92 2010's 3.79 - = No Data Reported; -- = Not Applicable; NA

  19. Alabama Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Alabama Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.13 0.13 0.13 1970's 0.14 0.15 0.35 0.38 0.74 0.87 0.99 1.47 1.50 2.04 1980's 3.19 4.77 3.44 4.28 3.73 3.71 2.89 2.97 2.65 2.72 1990's 2.75 2.33 2.29 2.46 2.17 1.82 2.62 2.67 2.21 2.32 2000's 3.99 4.23 3.48 5.93 6.66 9.28 7.57 7.44 9.65 4.32 2010's 4.46 - = No Data Reported; -- = Not Applicable;

  20. Alaska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Alaska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.25 0.25 0.25 1970's 0.25 0.24 0.15 0.15 0.17 0.30 0.39 0.40 0.52 0.52 1980's 0.73 0.62 0.63 0.73 0.73 0.74 0.50 0.94 1.27 1.36 1990's 1.38 1.48 1.41 1.42 1.27 1.64 1.61 1.82 1.32 1.37 2000's 1.76 1.99 2.13 2.41 3.42 4.75 5.79 5.63 7.39 2.93 2010's 3.17 - = No Data Reported; -- = Not Applicable;

  1. Arizona Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Arizona Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.15 0.16 0.18 1970's 0.17 0.18 0.18 0.18 0.20 0.28 0.28 0.33 0.37 0.41 1980's 2.59 3.08 2.90 1.80 1990's 1.20 1.50 1.85 1.30 1.40 1.20 1.65 2.40 1.88 2.08 2000's 3.50 4.12 2.60 4.33 5.12 6.86 5.70 5.98 7.09 3.19 2010's 4.11 - = No Data Reported; -- = Not Applicable; NA = Not Available; W =

  2. Arkansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) Arkansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.15 0.16 0.16 1970's 0.16 0.17 0.17 0.18 0.26 0.35 0.53 0.58 0.75 0.96 1980's 0.70 1.81 2.13 2.29 2.54 2.55 2.51 2.29 1.94 2.41 1990's 2.06 1.92 2.15 2.81 2.65 3.02 3.82 4.03 3.92 4.10 2000's 5.23 4.99 4.43 5.17 5.68 7.26 6.43 6.61 8.72 3.43 2010's 3.84 - = No Data Reported; -- = Not Applicable;

  3. California Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    Gasoline and Diesel Fuel Update (EIA)

    Wellhead Price (Dollars per Thousand Cubic Feet) California Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.30 0.31 0.31 1970's 0.32 0.33 0.37 0.37 0.44 0.70 0.94 1.17 1.36 1.70 1980's 2.17 2.57 3.09 3.57 3.80 3.36 2.89 2.37 2.39 2.32 1990's 2.36 2.46 2.34 2.38 1.50 1.73 1.82 2.41 1.97 2.36 2000's 4.81 6.93 2.92 5.04 5.65 7.45 6.47 6.62 8.38 3.96 2010's 4.87 - = No Data Reported; -- = Not

  4. Tennessee Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Tennessee Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.19 0.19 0.19 1970's 0.20 0.22 0.32 0.30 0.35 0.44 0.51 0.74 1.64 1.70 1980's 1.76 2.55 3.00 2.50 3.50 2.48 1.78 1.31 1.50 1.65 1990's 1.65 1.72 1.79 2.65 2.16 1.54 2.54 2.55 2.15 2.28 2000's 4.09 3.60 3.41 5.22 6.90 9.55 6.78 6.63 8.85 3.83 2010's 4.35 - = No Data Reported; -- = Not

  5. Texas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Texas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.13 0.14 0.14 1970's 0.14 0.16 0.16 0.20 0.31 0.52 0.72 0.90 0.99 1.23 1980's 1.56 1.87 2.17 2.36 2.45 2.33 1.65 1.47 1.51 1.53 1990's 1.57 1.59 1.77 2.09 1.89 1.61 2.29 2.48 2.06 2.31 2000's 3.93 4.12 3.16 5.18 5.83 7.55 6.60 6.98 8.51 3.81 2010's 4.70 - = No Data Reported; -- = Not Applicable; NA

  6. Ohio Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Ohio Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.24 0.25 0.26 1970's 0.27 0.34 0.39 0.43 0.48 0.71 1.02 1.40 1.57 1.81 1980's 1.98 2.17 2.71 3.24 3.19 3.08 2.84 2.58 2.55 2.55 1990's 2.54 2.38 2.35 2.46 2.43 2.33 2.63 2.70 2.95 2.43 2000's 4.06 4.54 4.52 5.90 6.65 9.03 7.75 7.59 7.88 4.36 2010's 4.63 - = No Data Reported; -- = Not Applicable; NA

  7. Oklahoma Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Oklahoma Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.14 0.14 0.15 1970's 0.16 0.16 0.16 0.19 0.28 0.32 0.50 0.79 0.90 1.12 1980's 1.51 1.88 2.74 2.83 2.72 2.47 1.71 1.47 1.55 1.59 1990's 1.57 1.47 1.70 1.88 1.70 1.44 2.21 2.32 1.77 2.05 2000's 3.63 4.03 2.94 4.97 5.52 7.21 6.32 6.24 7.56 3.53 2010's 4.71 - = No Data Reported; -- = Not Applicable;

  8. Wyoming Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Wyoming Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.15 0.15 0.15 1970's 0.15 0.15 0.16 0.18 0.25 0.34 0.41 0.64 0.79 1.13 1980's 1.92 2.77 3.22 3.18 3.32 3.01 2.52 1.76 1.53 1.24 1990's 1.16 1.06 1.13 1.99 2.05 1.78 2.57 2.42 1.78 1.97 2000's 3.34 3.49 2.70 4.13 4.96 6.86 5.85 4.65 6.86 3.40 2010's 4.30 - = No Data Reported; -- = Not Applicable;

  9. Utah Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) Utah Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.13 0.16 0.15 1970's 0.15 0.17 0.17 0.19 0.41 0.48 0.50 0.61 0.64 0.72 1980's 1.12 1.10 3.06 3.40 4.08 3.52 2.90 1.88 2.39 1.58 1990's 1.70 1.54 1.63 1.77 1.54 1.15 1.39 1.86 1.73 1.93 2000's 3.28 3.52 1.99 4.11 5.24 7.16 5.49 NA 6.15 3.38 2010's 4.23 - = No Data Reported; -- = Not Applicable; NA =

  10. Property:Building/MeanAnnualTempCalculationPeriod | Open Energy...

    Open Energy Info (EERE)

    Property Edit with form History Property:BuildingMeanAnnualTempCalculationPeriod Jump to: navigation, search This is a property of type Number. Mean annual temperature during the...

  11. ARM: Microwave Radiometer data (MWR Profiles - QME), water vapor, temp, cloud liquid water, precip water retrievals

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Maria Cadeddu

    2004-02-19

    Microwave Radiometer data (MWR Profiles - QME), water vapor, temp, cloud liquid water, precip water retrievals

  12. ARM: Microwave Radiometer data (MWR Profiles - QME), water vapor, temp, cloud liquid water, precip water retrievals

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Maria Cadeddu

    Microwave Radiometer data (MWR Profiles - QME), water vapor, temp, cloud liquid water, precip water retrievals

  13. System and method for converting wellhead gas to liquefied petroleum gases (LPG)

    SciTech Connect (OSTI)

    May, R.L.; Snow, N.J. Jr.

    1983-12-06

    A method of converting natural wellhead gas to liquefied petroleum gases (LPG) may comprise the steps of: separating natural gas from petroleum fluids exiting a well-head; compressing the natural gas; refrigerating the natural gas, liquefying at least a portion thereof; and separating LPG from gas vapors of the refrigerated natural gas. A system for performing the method may comprise: a two-stage gas compressor connected to the wellhead; a refrigeration unit downstream of the gas compressor for cooling the compressed gases therefrom; and a product separator downstream of the refrigeration unit for receiving cooled and compressed gases discharged from the refrigeration unit and separating LPG therein from gases remaining in vapor form.

  14. ,"Montana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Montana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  15. ,"Nebraska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Nebraska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  16. ,"Nevada Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Nevada Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  17. ,"New Mexico Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","New Mexico Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  18. ,"New York Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","New York Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  19. ,"North Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","North Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  20. ,"Ohio Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Ohio Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  1. ,"Oklahoma Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Oklahoma Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  2. ,"Oregon Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Oregon Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  3. ,"Pennsylvania Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Pennsylvania Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  4. ,"South Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","South Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  5. ,"Tennessee Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Tennessee Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  6. ,"Texas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Texas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  7. ,"Utah Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Utah Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  8. ,"Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  9. ,"West Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","West Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  10. ,"Wyoming Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Wyoming Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  11. ,"Alabama Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Alabama Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  12. ,"Alaska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Alaska Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  13. ,"Arizona Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Arizona Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  14. ,"Arkansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Arkansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  15. ,"California Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","California Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  16. ,"Colorado Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Colorado Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  17. ,"Florida Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Florida Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  18. ,"Illinois Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Illinois Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  19. ,"Indiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Indiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  20. ,"Kansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Kansas Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  1. ,"Kentucky Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Kentucky Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  2. ,"Louisiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Louisiana Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  3. ,"Maryland Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Maryland Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  4. ,"Michigan Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Michigan Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  5. ,"Mississippi Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Mississippi Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  6. ,"Missouri Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)"

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","Missouri Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",1997 ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  7. Reservoir Claddings

    SciTech Connect (OSTI)

    2009-05-14

    This information sheet explains how to properly decouple reservoir claddings from water sensitive materials of the wall assembly.

  8. System and method for converting wellhead gas to liquefied petroleum gases (LPG)

    SciTech Connect (OSTI)

    May, R.L.; Sinclair, B.W.

    1984-07-31

    A method of converting natural wellhead gas to liquefied petroleum gases (LPG) may comprise the steps of: separating natural gas from petroleum fluids exiting a wellhead; compressing the natural gas; refrigerating the natural gas, liquefying at least a portion thereof; separating LPG from gas vapors of the refrigerated natural gas; storing the separated LPG in a storage tank with a vapor space therein; and recirculating a portion of the LPG vapors in the storage tank with the natural gas exiting the wellhead to enhance recovery of LPG. A system for performing the method may comprise: a two-stage gas compressor connected to the wellhead; a refrigeration unit downstream of the gas compressor for refrigerating the compressed gases therefrom; at least one product separator downstream of the refrigerator unit for receiving refrigerated and compressed gases discharged from the refrigerator unit and separating LPG therein from gases remaining in vapor form; and a storage tank for receiving and storing the separated LPG therein, the storage tank having a vapor space therein connected upstream of the gas compressor through a pressure regulator allowing recirculation of some LPG vapors with the natural gases through said system.

  9. U.S. Quantity of Production Associated with Reported Wellhead Value

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Cubic Feet) Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) U.S. Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1980's 17,159,365 17,042,578 16,025,662 14,556,226 16,121,625 15,247,466 14,823,587 15,283,764 15,419,723 15,432,773 1990's 16,408,437 15,770,393 15,852,090 15,480,352 15,513,667 15,557,464 14,822,258 17,105,855 17,653,795

  10. South Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) South Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1970's 2.11 1980's 2.75 3.08 3.37 3.67 2.51 2.46 2.71 1.95 1.11 1990's 1.56 1.12 1.79 2.13 1.73 1.59 2.09 2.47 2.13 2000's 3.56 3.42 2.95 4.98 5.49 7.44 6.40 7.22 7.94 NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company

  11. West Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) West Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.24 0.26 0.27 1970's 0.25 0.26 0.30 0.31 0.33 0.37 0.57 0.61 0.66 1.05 1980's 3.00 3.00 3.20 3.10 3.45 3.85 3.90 3.85 3.05 3.11 1990's 3.19 2.97 3.01 3.50 2.62 2.22 2000's NA -- NA NA NA 2010's NA - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid

  12. Geothermal rotary separator turbine: wellhead power system tests at Milford, Utah

    SciTech Connect (OSTI)

    Hughes, E.E.

    1983-08-01

    Through development of a separator/expander engine EPRI is improving the efficiency of single flash geothermal power systems. Under cost-shared contracts with Biphase Energy Systems and Utah Power and Light Company (UP and L), a wellhead power generating system has been built and tested. The wellhead unit has been operated for 4000 hours at Roosevelt Hot Springs near Milford, Utah. Phillips Petroleum Company operates the geothermal field at this site. The rotary separator turbine (RST) is a separating expander that increases the resource utilization efficiency by extracting power upstream of a steam turbine in either a 1-stage or 2-stage flash power system. The first power output was achieved October 28, 1981, six weeks after arrival of the RST at the site. The RST system produced 3270 MWh(e) gross and 2770 MWh(e) net to the UP and L grid. Total equivalent power produced by the wellhead RST (actual power output of the RST plus the power obtainable from the steam flow out of the RST) is 15 to 20 percent above the power that would be produced by an optimum 1-stage direct flash plant operated on the same geothermal well.

  13. Appraisal of transport and deformation in shale reservoirs using natural noble gas tracers

    SciTech Connect (OSTI)

    Heath, Jason E.; Kuhlman, Kristopher L.; Robinson, David G.; Bauer, Stephen J.; Gardner, William Payton

    2015-09-01

    This report presents efforts to develop the use of in situ naturally-occurring noble gas tracers to evaluate transport mechanisms and deformation in shale hydrocarbon reservoirs. Noble gases are promising as shale reservoir diagnostic tools due to their sensitivity of transport to: shale pore structure; phase partitioning between groundwater, liquid, and gaseous hydrocarbons; and deformation from hydraulic fracturing. Approximately 1.5-year time-series of wellhead fluid samples were collected from two hydraulically-fractured wells. The noble gas compositions and isotopes suggest a strong signature of atmospheric contribution to the noble gases that mix with deep, old reservoir fluids. Complex mixing and transport of fracturing fluid and reservoir fluids occurs during production. Real-time laboratory measurements were performed on triaxially-deforming shale samples to link deformation behavior, transport, and gas tracer signatures. Finally, we present improved methods for production forecasts that borrow statistical strength from production data of nearby wells to reduce uncertainty in the forecasts.

  14. ,"U.S. Natural Gas Wellhead Value and Marketed Production"

    U.S. Energy Information Administration (EIA) Indexed Site

    Value and Marketed Production" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","U.S. Natural Gas Wellhead Value and Marketed Production",4,"Annual",2015,"6/30/1900" ,"Release Date:","2/29/2016" ,"Next Release Date:","3/31/2016" ,"Excel File

  15. AcuTemp Expands as Appliances Become More Energy Efficient | Department of

    Broader source: Energy.gov (indexed) [DOE]

    Energy AcuTemp received a $900,000 48C manufacturing tax credit under the American Recovery and Reinvestment Act to increase production of the company's ThermoCor vacuum insulation panels for more efficient ENERGY STAR appliances. | Photo courtesy of AcuTemp | AcuTemp received a $900,000 48C manufacturing tax credit under the American Recovery and Reinvestment Act to increase production of the company's ThermoCor vacuum insulation panels for more efficient ENERGY STAR appliances. | Photo

  16. DOE Fuel Cell Pre-Solicitation Workshop - Breakout Group 3: HIGH TEMP

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    (SOFC) SYSTEM AND BOP | Department of Energy 3: HIGH TEMP (SOFC) SYSTEM AND BOP DOE Fuel Cell Pre-Solicitation Workshop - Breakout Group 3: HIGH TEMP (SOFC) SYSTEM AND BOP Report from Breakout Group 3 of the DOE Fuel Cell Pre-Solicitation Workshop, March 16-17, 2010 PDF icon fuelcell_pre-solicitation_wkshop_hi_temp_sofc.pdf More Documents & Publications DOE Fuel Cell Pre-Solicitation Workshop - Breakout Group 5: Long-Term Innovative Technologies Solid Oxide Fuel Cell System (SOFC)

  17. New Mexico Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) New Mexico Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.13 0.13 0.14 1970's 0.14 0.15 0.19 0.24 0.31 0.40 0.56 0.81 0.99 1.37 1980's 1.76 2.13 2.47 2.68 2.71 2.62 1.87 1.66 1.70 1.56 1990's 1.69 1.37 1.60 1.79 1.58 1.26 1.67 1.76 1.76 2.11 2000's 3.43 3.89 2.68 4.56 4.97 6.91 6.18 6.88 8.40 4.17 2010's 5.32 - = No Data Reported; -- = Not

  18. New York Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) New York Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.31 0.30 0.30 1970's 0.30 0.30 0.33 0.35 0.55 0.74 1.13 1.16 1.19 1.27 1980's 1.95 2.67 3.75 3.85 4.00 3.37 3.39 2.00 2.30 2.20 1990's 2.20 2.15 2.25 2.40 2.35 2.30 2.56 2.56 2.16 2000's 3.75 5.00 3.03 5.78 6.98 7.78 7.13 8.85 8.94 4.21 2010's 4.65 - = No Data Reported; -- = Not Applicable; NA =

  19. North Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)

    U.S. Energy Information Administration (EIA) Indexed Site

    Wellhead Price (Dollars per Thousand Cubic Feet) North Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1960's 0.16 0.17 0.16 1970's 0.16 0.17 0.17 0.20 0.20 0.23 0.34 0.35 0.46 1.28 1980's 1.19 1.94 2.30 2.27 2.26 1.90 1.35 1.30 2.00 1.78 1990's 1.79 1.67 1.97 1.84 2.16 2.14 2.32 2000's 3.94 3.53 2.73 3.53 5.73 8.40 6.52 6.67 8.55 3.74 2010's 3.92 - = No Data Reported; -- = Not Applicable; NA = Not

  20. Property:Building/MeanAnnualTempAtSite | Open Energy Information

    Open Energy Info (EERE)

    of type Number. Mean annual temperature at the site1 Pages using the property "BuildingMeanAnnualTempAtSite" Showing 25 pages using this property. (previous 25) (next 25) S...

  1. Status of Norris Reservoir

    SciTech Connect (OSTI)

    Not Available

    1990-09-01

    This is one in a series of reports prepared by the Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overview of Norris Reservoir summarizes reservoir and watershed characteristics, reservoir uses, conditions that impair reservoir uses, water quality and aquatic biological conditions, and activities of reservoir management agencies. This information was extracted from the most up-to-date publications and data available, and from interviews with water resource professionals in various federal, state, and local agencies, and in public and private water supply and wastewater treatment facilities. 14 refs., 3 figs.

  2. Status of Wheeler Reservoir

    SciTech Connect (OSTI)

    Not Available

    1990-09-01

    This is one in a series of status reports prepared by the Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overview of Wheeler Reservoir summarizes reservoir purposes and operation, reservoir and watershed characteristics, reservoir uses and use impairments, and water quality and aquatic biological conditions. The information presented here is from the most recent reports, publications, and original data available. If no recent data were available, historical data were summarized. If data were completely lacking, environmental professionals with special knowledge of the resource were interviewed. 12 refs., 2 figs.

  3. Status of Cherokee Reservoir

    SciTech Connect (OSTI)

    Not Available

    1990-08-01

    This is the first in a series of reports prepared by Tennessee Valley Authority (TVA) for those interested in the conditions of TVA reservoirs. This overviews of Cherokee Reservoir summarizes reservoir and watershed characteristics, reservoir uses and use impairments, water quality and aquatic biological conditions, and activities of reservoir management agencies. This information was extracted from the most current reports, publications, and data available, and interviews with water resource professionals in various Federal, state, and local agencies and in public and private water supply and wastewater treatment facilities. 11 refs., 4 figs., 1 tab.

  4. MEMS Fuel Cells--Low Temp--High Power Density - Energy Innovation Portal

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Energy Storage Energy Storage Find More Like This Return to Search MEMS Fuel Cells--Low Temp--High Power Density Lawrence Livermore National Laboratory Contact LLNL About This Technology Technology Marketing SummaryRechargeable batteries presently provide limited energy density and cyclical lifetime for portable power applications, with only incremental improvements forecasted in the foreseeable future. Furthermore, recharging requires access to electrical outlets via a tethered charger. The

  5. Final report on HGP-a wellhead generator proof-of-feasibility project

    SciTech Connect (OSTI)

    Chen, B.H.; Lopez, L.P.

    1982-10-01

    The construction of the 3 MW geothermal power plant at HGP-A well was completed in June, 1981. The HGP-A started production on June 12, 1981. Numerous problems developed during the plant startup and shakedown periods. However, the plant was formally turned over to Hawaii Electric Light Company (HELCO), the local utility company on March 1, 1982. Currently, all systems are functioning well and all major objectives have been met. The plan is to operate the power plant through 1990 where long term equipment and material information and reservoir characteristics can be obtained.

  6. TEMP-STRESS analysis of a reinforced concrete vessel under internal pressure

    SciTech Connect (OSTI)

    Marchertas, A.H.; Kennedy, J.M.; Pfeiffer, P.A.

    1987-01-01

    Prediction of the response of the Sandia National laboratory 1/6-scale reinforced concrete containment model test was obtained by Argonne National Laboratory (ANL) employing a computer program developed by ANL. The test model was internally pressurized to failure. The two-dimensional code TEMP-STRESS (1-5) has been developed at ANL for stress analysis of plane and axisymmetric 2-D reinforced structures under various thermal conditions. The program is applicable to a wide variety of nonlinear problems, and is utilized in the present study. The comparison of these pretest computations with test data on the containment model should be a good indication of the state of the code.

  7. Reese River Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Reservoir Temp (Geothermometry): Reservoir Temp (Measured): Sanyal Classification (Reservoir): Depth to Top of Reservoir: Depth to Bottom of Reservoir: Average Depth to...

  8. Reservoir Temperature Estimator

    Energy Science and Technology Software Center (OSTI)

    2014-12-08

    The Reservoir Temperature Estimator (RTEst) is a program that can be used to estimate deep geothermal reservoir temperature and chemical parameters such as CO2 fugacity based on the water chemistry of shallower, cooler reservoir fluids. This code uses the plugin features provided in The Geochemist’s Workbench (Bethke and Yeakel, 2011) and interfaces with the model-independent parameter estimation code Pest (Doherty, 2005) to provide for optimization of the estimated parameters based on the minimization of themore » weighted sum of squares of a set of saturation indexes from a user-provided mineral assemblage.« less

  9. Seismicity and Reservoir Fracture Characterization

    Broader source: Energy.gov [DOE]

    Below are the project presentations and respective peer review results for Seismicity and Reservoir Fracture Characterization.

  10. The energy transfer in the TEMP-4M pulsed ion beam accelerator

    SciTech Connect (OSTI)

    Isakova, Y. I.; Pushkarev, A. I.; Khaylov, I. P.

    2013-07-15

    The results of a study of the energy transfer in the TEMP-4M pulsed ion beam accelerator are presented. The energy transfer efficiency in the Blumlein and a self-magnetically insulated ion diode was analyzed. Optimization of the design of the accelerator allows for 85% of energy transferred from Blumlein to the diode (including after-pulses), which indicates that the energy loss in Blumlein and spark gaps is insignificant and not exceeds 10%12%. Most losses occur in the diode. The efficiency of energy supplied to the diode to the energy of accelerated ions is 8%9% for a planar strip self-magnetic MID, 12%15% for focusing diode and 20% for a spiral self-magnetic MID.

  11. TEMP: a computer code to calculate fuel pin temperatures during a transient. [LMFBR

    SciTech Connect (OSTI)

    Bard, F E; Christensen, B Y; Gneiting, B C

    1980-04-01

    The computer code TEMP calculates fuel pin temperatures during a transient. It was developed to accommodate temperature calculations in any system of axi-symmetric concentric cylinders. When used to calculate fuel pin temperatures, the code will handle a fuel pin as simple as a solid cylinder or as complex as a central void surrounded by fuel that is broken into three regions by two circumferential cracks. Any fuel situation between these two extremes can be analyzed along with additional cladding, heat sink, coolant or capsule regions surrounding the fuel. The one-region version of the code accurately calculates the solution to two problems having closed-form solutions. The code uses an implicit method, an explicit method and a Crank-Nicolson (implicit-explicit) method.

  12. Mauna Loa Southwest Rift Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  13. Under Steamboat Springs Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  14. Honokowai Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    -156.60912475586 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  15. Seven Mile Hole Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  16. Teels Marsh Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  17. Molokai Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    -156.86867675781 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  18. Flint Geothermal Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  19. Under Steamboat Springs Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  20. Mauna Loa Northeast Rift Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  1. Gabbs Alkali Flat Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  2. Walker Lake Valley Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  3. Jemez Mountain Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  4. Rhodes Marsh Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  5. Glass Buttes Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  6. San Francisco Volcanic Field Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  7. Truckhaven Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  8. Lassen Volcanic National Park Geothermal Area | Open Energy Informatio...

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  9. Hualalai Northwest Rift Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  10. Mt St Helens Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    -122.04050509296 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  11. Kilauea Summit Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  12. Gabbs Alkali Flat Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  13. Columbus Salt Marsh Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  14. San Juan Volcanic Field Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  15. Fort Bliss Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  16. Sauerlach Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    11.667261505127 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  17. Olowalu-Ukumehame Canyon Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  18. San Juan Volcanic Field Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  19. Haleakala Volcano Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  20. Winnemucca Dry Lake Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  1. White Mountains Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  2. Kawaihae Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  3. Mt Rainier Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    -121.75128794312 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  4. Columbus Salt Marsh Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  5. Mokapu Penninsula Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  6. Winnemucca Dry Lake Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  7. Kauai Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    -159.52462158203 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  8. Obsidian Cliff Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  9. Marysville Mt Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  10. Redfield Campus Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  11. Lester Meadow Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  12. Kilauea Summit Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  13. Jemez Pueblo Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  14. Mt St Helens Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  15. Rangely Oilfield Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  16. Valley Of Ten Thousand Smokes Region Geothermal Area | Open Energy...

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  17. Mauna Loa Southwest Rift Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  18. Upper Hot Creek Ranch Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  19. Mokapu Penninsula Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  20. Florida Mountains Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  1. Kilauea Southwest Rift And South Flank Geothermal Area | Open...

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  2. Zuni Mountains Nm Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  3. Flint Geothermal Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  4. Twilight Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With...

  5. Lahaina-Kaanapali Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean...

  6. Reinjection into geothermal reservoirs

    SciTech Connect (OSTI)

    Bodvarsson, G.S.; Stefansson, V.

    1987-08-01

    Reinjection of geothermal wastewater is practiced as a means of disposal and for reservoir pressure support. Various aspects of reinjection are discussed, both in terms of theoretical studies as well as specific field examples. The discussion focuses on the major effects of reinjection, including pressure maintenance and chemical and thermal effects. (ACR)

  7. Natural Gas Wellhead Price

    Gasoline and Diesel Fuel Update (EIA)

    NA NA NA NA NA NA 1973

  8. Natural Gas Wellhead Price

    Gasoline and Diesel Fuel Update (EIA)

    Pipeline and Distribution Use Price City Gate Price Residential Price Percentage of Total Residential Deliveries included in Prices Commercial Price Percentage of Total Commercial Deliveries included in Prices Industrial Price Percentage of Total Industrial Deliveries included in Prices Vehicle Fuel Price Electric Power Price Period: Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By: Data Series Area 2010

  9. Natural Gas Wellhead Price

    Gasoline and Diesel Fuel Update (EIA)

    Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By: Data Series Area 2010 2011 2012 2013 2014 2015 View History U.S. 4.48 3.95 2.66 NA NA NA 1922-2015 Alabama 4.46 1967-2010 Alaska 3.17 1967-2010 Arizona 4.11 1967-2010 Arkansas 3.84 1967-2010 California 4.87 1967-2010 Colorado 3.96 1967-2010 Florida NA 1967-2010 Illinois NA 1967-2010 Indiana 4.13 1967-2010 Kansas 4.23 1967-2010 Kentucky 4.47 1967-2010

  10. White Mountains Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    New Hampshire Exploration Region: Other GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  11. Fort Bliss Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Texas Exploration Region: Rio Grande Rift GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  12. Lahaina-Kaanapali Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Exploration Region: Hawaii Geothermal Region GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  13. McGee Mountain Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Region GEA Development Phase: Coordinates: 41.8, -118.87 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  14. Glass Buttes Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Oregon Exploration Region: Cascades GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS...

  15. Hot Pot Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Region GEA Development Phase: Coordinates: 40.922, -117.108 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  16. Aqua Quieta Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Identification Coordinates: 40.357346092631, -118.32314453125 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS...

  17. Grass Valley Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Coordinates: 40.60333333, -117.645 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  18. Bingham-Caribou Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Identification Coordinates: 43.071647552759, -112.24770507812 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS...

  19. Crane Creek Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Coordinates: 44.3064, -116.7447 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  20. Dead Horse Wells Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Transition Zone Geothermal Region GEA Development Phase: Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS...

  1. Weiser Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    GEA Development Phase: Coordinates: 44.29833333, -117.0483333 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: USGS Mean Reservoir Temp:...

  2. Collapsible sheath fluid reservoirs for flow cytometers

    DOE Patents [OSTI]

    Mark, Graham A. (Los Alamos, NM)

    2000-01-01

    The present invention is a container in the form of a single housing for holding fluid, including a first collapsible reservoir having a first valve. The first reservoir initially contains a volume of fluid. The container also includes a second reservoir, initially empty (or substantially empty), expandable to a second volume. The second reservoir has a second valve. As the volume of said first reservoir decreases, the volume of the second reservoir proportionally increases.

  3. Water resources review: Ocoee reservoirs, 1990

    SciTech Connect (OSTI)

    Cox, J.P.

    1990-08-01

    Tennessee Valley Authority (TVA) is preparing a series of reports to make technical information on individual TVA reservoirs readily accessible. These reports provide a summary of reservoir purpose and operation; physical characteristics of the reservoir and watershed; water quality conditions; aquatic biological conditions; and designated, actual and potential uses of the reservoir and impairments of those use. This reservoir status report addressed the three Ocoee Reservoirs in Polk County, Tennessee.

  4. Analysis of real-time reservoir monitoring : reservoirs, strategies, & modeling.

    SciTech Connect (OSTI)

    Mani, Seethambal S.; van Bloemen Waanders, Bart Gustaaf; Cooper, Scott Patrick; Jakaboski, Blake Elaine; Normann, Randy Allen; Jennings, Jim; Gilbert, Bob; Lake, Larry W.; Weiss, Chester Joseph; Lorenz, John Clay; Elbring, Gregory Jay; Wheeler, Mary Fanett; Thomas, Sunil G.; Rightley, Michael J.; Rodriguez, Adolfo; Klie, Hector; Banchs, Rafael; Nunez, Emilio J.; Jablonowski, Chris

    2006-11-01

    The project objective was to detail better ways to assess and exploit intelligent oil and gas field information through improved modeling, sensor technology, and process control to increase ultimate recovery of domestic hydrocarbons. To meet this objective we investigated the use of permanent downhole sensors systems (Smart Wells) whose data is fed real-time into computational reservoir models that are integrated with optimized production control systems. The project utilized a three-pronged approach (1) a value of information analysis to address the economic advantages, (2) reservoir simulation modeling and control optimization to prove the capability, and (3) evaluation of new generation sensor packaging to survive the borehole environment for long periods of time. The Value of Information (VOI) decision tree method was developed and used to assess the economic advantage of using the proposed technology; the VOI demonstrated the increased subsurface resolution through additional sensor data. Our findings show that the VOI studies are a practical means of ascertaining the value associated with a technology, in this case application of sensors to production. The procedure acknowledges the uncertainty in predictions but nevertheless assigns monetary value to the predictions. The best aspect of the procedure is that it builds consensus within interdisciplinary teams The reservoir simulation and modeling aspect of the project was developed to show the capability of exploiting sensor information both for reservoir characterization and to optimize control of the production system. Our findings indicate history matching is improved as more information is added to the objective function, clearly indicating that sensor information can help in reducing the uncertainty associated with reservoir characterization. Additional findings and approaches used are described in detail within the report. The next generation sensors aspect of the project evaluated sensors and packaging survivability issues. Our findings indicate that packaging represents the most significant technical challenge associated with application of sensors in the downhole environment for long periods (5+ years) of time. These issues are described in detail within the report. The impact of successful reservoir monitoring programs and coincident improved reservoir management is measured by the production of additional oil and gas volumes from existing reservoirs, revitalization of nearly depleted reservoirs, possible re-establishment of already abandoned reservoirs, and improved economics for all cases. Smart Well monitoring provides the means to understand how a reservoir process is developing and to provide active reservoir management. At the same time it also provides data for developing high-fidelity simulation models. This work has been a joint effort with Sandia National Laboratories and UT-Austin's Bureau of Economic Geology, Department of Petroleum and Geosystems Engineering, and the Institute of Computational and Engineering Mathematics.

  5. Supercritical Carbon Dioxide / Reservoir Rock Chemical Interactions...

    Open Energy Info (EERE)

    Supercritical Carbon Dioxide Reservoir Rock Chemical Interactions Jump to: navigation, search Geothermal Lab Call Projects for Supercritical Carbon Dioxide Reservoir Rock...

  6. Reservoir-Stimulation Optimization with Operational Monitoring...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Reservoir-Stimulation Optimization with Operational Monitoring for Creation of Enhanced Geothermal Systems Reservoir-Stimulation Optimization with Operational Monitoring for ...

  7. Temperature | Open Energy Information

    Open Energy Info (EERE)

    C Property:Combustion Intake Air Temperature F Property:FirstWellTemp G Property:GeochemReservoirTemp Property:GeofluidTemp M Property:MeanReservoirTemp R...

  8. Geothermal Reservoir Dynamics - TOUGHREACT

    SciTech Connect (OSTI)

    Pruess, Karsten; Xu, Tianfu; Shan, Chao; Zhang, Yingqi; Wu,Yu-Shu; Sonnenthal, Eric; Spycher, Nicolas; Rutqvist, Jonny; Zhang,Guoxiang; Kennedy, Mack

    2005-03-15

    This project has been active for several years and has focused on developing, enhancing and applying mathematical modeling capabilities for fractured geothermal systems. The emphasis of our work has recently shifted towards enhanced geothermal systems (EGS) and hot dry rock (HDR), and FY05 is the first year that the DOE-AOP actually lists this project under Enhanced Geothermal Systems. Our overall purpose is to develop new engineering tools and a better understanding of the coupling between fluid flow, heat transfer, chemical reactions, and rock-mechanical deformation, to demonstrate new EGS technology through field applications, and to make technical information and computer programs available for field applications. The objectives of this project are to: (1) Improve fundamental understanding and engineering methods for geothermal systems, primarily focusing on EGS and HDR systems and on critical issues in geothermal systems that are difficult to produce. (2) Improve techniques for characterizing reservoir conditions and processes through new modeling and monitoring techniques based on ''active'' tracers and coupled processes. (3) Improve techniques for targeting injection towards specific engineering objectives, including maintaining and controlling injectivity, controlling non-condensable and corrosive gases, avoiding scale formation, and optimizing energy recovery. Seek opportunities for field testing and applying new technologies, and work with industrial partners and other research organizations.

  9. Chickamauga reservoir embayment study - 1990

    SciTech Connect (OSTI)

    Meinert, D.L.; Butkus, S.R.; McDonough, T.A.

    1992-12-01

    The objectives of this report are three-fold: (1) assess physical, chemical, and biological conditions in the major embayments of Chickamauga Reservoir; (2) compare water quality and biological conditions of embayments with main river locations; and (3) identify any water quality concerns in the study embayments that may warrant further investigation and/or management actions. Embayments are important areas of reservoirs to be considered when assessments are made to support water quality management plans. In general, embayments, because of their smaller size (water surface areas usually less than 1000 acres), shallower morphometry (average depth usually less than 10 feet), and longer detention times (frequently a month or more), exhibit more extreme responses to pollutant loadings and changes in land use than the main river region of the reservoir. Consequently, embayments are often at greater risk of water quality impairments (e.g. nutrient enrichment, filling and siltation, excessive growths of aquatic plants, algal blooms, low dissolved oxygen concentrations, bacteriological contamination, etc.). Much of the secondary beneficial use of reservoirs occurs in embayments (viz. marinas, recreation areas, parks and beaches, residential development, etc.). Typically embayments comprise less than 20 percent of the surface area of a reservoir, but they often receive 50 percent or more of the water-oriented recreational use of the reservoir. This intensive recreational use creates a potential for adverse use impacts if poor water quality and aquatic conditions exist in an embayment.

  10. SMALL, GEOLOGICALLY COMPLEX RESERVOIRS CAN BENEFIT FROM RESERVOIR SIMULATION

    SciTech Connect (OSTI)

    Richard E. Bennett

    2002-06-24

    The Cascade Sand zone of the Mission-Visco Lease in the Cascade Oil field of Los Angeles County, California, has been under water flood since 1970. Increasing water injection to increase oil production rates was being considered as an opportunity to improve oil recovery. However, a secondary gas cap had formed in the up-dip portion of the reservoir with very low gas cap pressures, creating concern that oil could be displaced into the gas cap resulting in the loss of recoverable oil. Therefore, injecting gas into the gas cap to keep the gas cap pressurized and restrict the influx of oil during water injection was also being considered. Further, it was recognized that the reservoir geology in the gas cap area is very complex with numerous folding and faulting and thus there are potential pressure barriers in several locations throughout the reservoir. With these conditions in mind, there were concerns regarding well to well continuity in the gas cap, which could interfere with the intended repressurization impact. Concerns about the pattern of gas flow from well to well, the possibilities of cycling gas without the desired increased pressure, and the possible loss of oil displaced into the gas cap resulted in the decision to conduct a gas tracer survey in an attempt to better define inter-well communication. Following the gas tracer survey, a reservoir model would be developed to integrate the findings of the gas tracer survey, known geologic and reservoir data, and historic production data. The reservoir model would be used to better define the reservoir characteristics and provide information that could help optimize the waterflood-gas injection project under consideration for efficient water and gas injection management to increase oil production. However, due to inadequate gas sampling procedures in the field and insufficiently developed laboratory analytical techniques, the laboratory was unable to detect the tracer in the gas samples taken. At that point, focus on, and an expansion of the scope of the reservoir simulation and modeling effort was initiated, using DOE's BOAST98 (a visual, dynamic, interactive update of BOAST3), 3D, black oil reservoir simulation package as the basis for developing the reservoir model. Reservoir characterization, modeling, and reservoir simulation resulted in a significant change in the depletion strategy. Information from the reservoir characterization and modeling effort indicate that in-fill drilling and relying on natural water influx from the aquifer could increase remaining reserves by 125,000 barrels of oil per well, and that up to 10 infill wells could be drilled in the field. Through this scenario, field production could be increased two to three times over the current 65 bopd. Based on the results of the study, permits have been applied for to drill a directional infill well to encounter the productive zone at a high angle in order to maximize the amount of pay and reservoirs encountered.

  11. Reservoir characterization of Pennsylvanian Sandstone Reservoirs. Annual report

    SciTech Connect (OSTI)

    Kelkar, M.

    1992-09-01

    This annual report describes the progress during the second year of a project on Reservoir Characterization of Pennsylvanian Sandstone Reservoirs. The report is divided into three sections: (i) reservoir description and scale-up procedures; (ii) outcrop investigation; (iii) in-fill drilling potential. The first section describes the methods by which a reservoir can be characterized, can be described in three dimensions, and can be scaled up with respect to its properties, appropriate for simulation purposes. The second section describes the progress on investigation of an outcrop. The outcrop is an analog of Bartlesville Sandstone. We have drilled ten wells behind the outcrop and collected extensive log and core data. The cores have been slabbed, photographed and the several plugs have been taken. In addition, minipermeameter is used to measure permeabilities on the core surface at six inch intervals. The plugs have been analyzed for the permeability and porosity values. The variations in property values will be tied to the geological descriptions as well as the subsurface data collected from the Glen Pool field. The third section discusses the application of geostatistical techniques to infer in-fill well locations. The geostatistical technique used is the simulated annealing technique because of its flexibility. One of the important reservoir data is the production data. Use of production data will allow us to define the reservoir continuities, which may in turn, determine the in-fill well locations. The proposed technique allows us to incorporate some of the production data as constraints in the reservoir descriptions. The technique has been validated by comparing the results with numerical simulations.

  12. Application of Integrated Reservoir Management and Reservoir Characterization to Optimize Infill Drilling

    SciTech Connect (OSTI)

    1998-01-01

    Infill drilling if wells on a uniform spacing without regard to reservoir performance and characterization foes not optimize reservoir development because it fails to account for the complex nature of reservoir heterogeneities present in many low permeability reservoirs, and carbonate reservoirs in particular. New and emerging technologies, such as geostatistical modeling, rigorous decline curve analysis, reservoir rock typing, and special core analysis can be used to develop a 3-D simulation model for prediction of infill locations.

  13. Test and demonstration of a 1-MW wellhead generator: helical screw expander power plant, Model 76-1. Final report to the International Energy Agency

    SciTech Connect (OSTI)

    Not Available

    1985-07-04

    A 1-MW geothermal wellhead power plant incorporating a Lysholm or helical screw expander (HSE) was field tested between 1980 and 1983 by Mexico, Italy, and New Zealand with technical assistance from the United States. The objectives were to provide data on the reliability and performance of the HSE and to assess the costs and benefits of its use. The range of conditions under which the HSE was tested included loads up to 933 kW, mass flowrates of 14,600 to 395, 000 lbs/hr, inlet pressures of 64 to 220 psia, inlet qualities of 0 to 100%, exhaust pressures of 3.1 to 40 psia, total dissolved solids up to 310,000 ppM, and noncondensible gases up to 38% of the vapor mass flow. Typical machine efficiencies of 40 to 50% were calculated. For most operations efficiency increased approximately logarithmically with shaft power, while inlet quality and rotor speed had only small effects. The HSE was designed with oversized internal clearances in the expectation that adherent scale would form during operation. Improvements in machine efficiency of 3.5 to 4 percentage points were observed over some test periods with some scale deposition. A comparison with a 1-MW back-pressure turbine showed that the HSE can compete favorably under certain conditions. The HSE was found to be a rugged energy conversion machine for geothermal applications, but some subsystems were found to require further development. 7 refs., 28 figs., 5 tabs.

  14. Tenth workshop on geothermal reservoir engineering: proceedings

    SciTech Connect (OSTI)

    Not Available

    1985-01-22

    The workshop contains presentations in the following areas: (1) reservoir engineering research; (2) field development; (3) vapor-dominated systems; (4) the Geysers thermal area; (5) well test analysis; (6) production engineering; (7) reservoir evaluation; (8) geochemistry and injection; (9) numerical simulation; and (10) reservoir physics. (ACR)

  15. Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management, Class III

    SciTech Connect (OSTI)

    Koerner, Roy; Clarke, Don; Walker, Scott; Phillips, Chris; Nguyen, John; Moos, Dan; Tagbor, Kwasi

    2001-08-07

    This project was intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs, transferring technology so that it can be applied in other sections of the Wilmington field and by operators in other slope and basin reservoirs is a primary component of the project.

  16. Sunset Reservoir Solar Power Plant | Open Energy Information

    Open Energy Info (EERE)

    Reservoir Solar Power Plant Facility Sunset Reservoir Sector Solar Facility Type Photovoltaic Developer Recurrent Energy Location San Francisco, California Coordinates...

  17. THMC Modeling of EGS Reservoirs … Continuum through Discontinuum...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Evolution and Induced Seismicity THMC Modeling of EGS Reservoirs Continuum through Discontinuum Representations: Capturing Reservoir Stimulation, Evolution and ...

  18. Development of Reservoir Characterization Techniques and Production Models for Exploiting Naturally Fractured Reservoirs

    SciTech Connect (OSTI)

    Wiggins, M.L.; Evans, R.D.; Brown, R.L.; Gupta, A.

    2001-03-28

    This report focuses on integrating geoscience and engineering data to develop a consistent characterization of the naturally fractured reservoirs. During this reporting period, effort was focused on relating seismic data to reservoir properties of naturally fractured reservoirs, scaling well log data to generate interwell descriptors of these reservoirs, enhancing and debugging a naturally fractured reservoir simulator, and developing a horizontal wellbore model for use in the simulator.

  19. Gabbs Valley Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Reservoir Temp (Measured): Sanyal Classification (Reservoir): Depth to Top of Reservoir: Depth to Bottom of Reservoir: Average Depth to Reservoir: Use the "Edit with...

  20. 4. International reservoir characterization technical conference

    SciTech Connect (OSTI)

    1997-04-01

    This volume contains the Proceedings of the Fourth International Reservoir Characterization Technical Conference held March 2-4, 1997 in Houston, Texas. The theme for the conference was Advances in Reservoir Characterization for Effective Reservoir Management. On March 2, 1997, the DOE Class Workshop kicked off with tutorials by Dr. Steve Begg (BP Exploration) and Dr. Ganesh Thakur (Chevron). Tutorial presentations are not included in these Proceedings but may be available from the authors. The conference consisted of the following topics: data acquisition; reservoir modeling; scaling reservoir properties; and managing uncertainty. Selected papers have been processed separately for inclusion in the Energy Science and Technology database.

  1. THMC Modeling of EGS Reservoirs … Continuum through Discontinuum

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Representations: Capturing Reservoir Stimulation, Evolution and Induced Seismicity | Department of Energy THMC Modeling of EGS Reservoirs … Continuum through Discontinuum Representations: Capturing Reservoir Stimulation, Evolution and Induced Seismicity THMC Modeling of EGS Reservoirs … Continuum through Discontinuum Representations: Capturing Reservoir Stimulation, Evolution and Induced Seismicity THMC Modeling of EGS Reservoirs … Continuum through Discontinuum Representations: Capturing

  2. The role of reservoir characterization in the reservoir management process (as reflected in the Department of Energy`s reservoir management demonstration program)

    SciTech Connect (OSTI)

    Fowler, M.L.; Young, M.A.; Madden, M.P.

    1997-08-01

    Optimum reservoir recovery and profitability result from guidance of reservoir practices provided by an effective reservoir management plan. Success in developing the best, most appropriate reservoir management plan requires knowledge and consideration of (1) the reservoir system including rocks, and rock-fluid interactions (i.e., a characterization of the reservoir) as well as wellbores and associated equipment and surface facilities; (2) the technologies available to describe, analyze, and exploit the reservoir; and (3) the business environment under which the plan will be developed and implemented. Reservoir characterization is the essential to gain needed knowledge of the reservoir for reservoir management plan building. Reservoir characterization efforts can be appropriately scaled by considering the reservoir management context under which the plan is being built. Reservoir management plans de-optimize with time as technology and the business environment change or as new reservoir information indicates the reservoir characterization models on which the current plan is based are inadequate. BDM-Oklahoma and the Department of Energy have implemented a program of reservoir management demonstrations to encourage operators with limited resources and experience to learn, implement, and disperse sound reservoir management techniques through cooperative research and development projects whose objectives are to develop reservoir management plans. In each of the three projects currently underway, careful attention to reservoir management context assures a reservoir characterization approach that is sufficient, but not in excess of what is necessary, to devise and implement an effective reservoir management plan.

  3. Compound hybrid geothermal-fossil power plants: thermodynamic...

    Office of Scientific and Technical Information (OSTI)

    SUPERHEATING; THERMODYNAMICS; WELL TEMPERATURE; WELLHEADS; WESTERN REGION; HEATING; HYDROGEN COMPOUNDS; NORTH AMERICA; OXYGEN COMPOUNDS; POWER PLANTS; RESERVOIR TEMPERATURE;...

  4. TITLE AUTHORS SUBJECT SUBJECT RELATED DESCRIPTION PUBLISHER AVAILABILI...

    Office of Scientific and Technical Information (OSTI)

    SUPERHEATING THERMODYNAMICS WELL TEMPERATURE WELLHEADS WESTERN REGION HEATING HYDROGEN COMPOUNDS NORTH AMERICA OXYGEN COMPOUNDS POWER PLANTS RESERVOIR TEMPERATURE THERMAL...

  5. Storage capacity in hot dry rock reservoirs

    DOE Patents [OSTI]

    Brown, D.W.

    1997-11-11

    A method is described for extracting thermal energy, in a cyclic manner, from geologic strata which may be termed hot dry rock. A reservoir comprised of hot fractured rock is established and water or other liquid is passed through the reservoir. The water is heated by the hot rock, recovered from the reservoir, cooled by extraction of heat by means of heat exchange apparatus on the surface, and then re-injected into the reservoir to be heated again. Water is added to the reservoir by means of an injection well and recovered from the reservoir by means of a production well. Water is continuously provided to the reservoir and continuously withdrawn from the reservoir at two different flow rates, a base rate and a peak rate. Increasing water flow from the base rate to the peak rate is accomplished by rapidly decreasing backpressure at the outlet of the production well in order to meet periodic needs for amounts of thermal energy greater than a baseload amount, such as to generate additional electric power to meet peak demands. The rate of flow of water provided to the hot dry rock reservoir is maintained at a value effective to prevent depletion of the liquid inventory of the reservoir. 4 figs.

  6. Skimming' a reservoir for trash

    SciTech Connect (OSTI)

    Shenman, L.E. )

    1993-02-01

    Several hydropower facilities are using a new technology for removing floating trash in reservoirs. Representatives from the facilities say the boat, called a trashskimmer, is efficient, easy to maneuver, and transportable. Designed by United Marine International, Inc., the pontoon boat features an operators cab that straddles an open hull between the skis of the pontoon, and uses dual propellers to maneuver through the water. The Marineskimmer allows the operator to approach the trash from the water side upstream of the plant. The Tennessee Valley Authority has used the boat since 1990.

  7. Characterization of Fractures in Geothermal Reservoirs Using...

    Open Energy Info (EERE)

    Abstract The optimal design of production in fractured geothermal reservoirs requires knowledge of the resource's connectivity, therefore making fracture characterization highly...

  8. International reservoir operations agreement helps NW fish &...

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    or 503-230-5131 International reservoir operations agreement helps Northwest fish and power Portland, Ore. - The Bonneville Power Administration and the British Columbia...

  9. Geothermometry At Blackfoot Reservoir Area (Hutsinpiller & Parry...

    Open Energy Info (EERE)

    Activity Details Location Blackfoot Reservoir Area Exploration Technique Geothermometry Activity Date Usefulness useful DOE-funding Unknown References Amy Hutsinpiller, W. T....

  10. 201202 Reservoir System Modeling Technologies Conference

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Modeling Applied To The Columbia River - PSR Adjoint Modeling Framework for Real-Time Control of Water - Deltares Reservoir Operations Analysis in the Willamette Water 2100...

  11. Hydrothermal Convection Systems with Reservoir Temperatures greater...

    Open Energy Info (EERE)

    Systems with Reservoir Temperatures greater than or equal to 90 degrees C Authors Brook, Mariner, Mabey, Swanson, Guffanti and Muffler Published Journal Assessment of...

  12. Evaluation Of Chemical Geothermometers For Calculating Reservoir...

    Open Energy Info (EERE)

    Geothermometers For Calculating Reservoir Temperatures At Nevada Geothermal Power Plants Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Paper:...

  13. Analysis of Geothermal Reservoir Stimulation using Geomechanics...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Stochastic Analysis of Injection-Induced Seismicity Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity ...

  14. Precise Gravimetry and Geothermal Reservoir Management | Open...

    Open Energy Info (EERE)

    Precise Gravimetry and Geothermal Reservoir Management Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Paper: Precise Gravimetry and Geothermal...

  15. Geothermal reservoirs in hydrothermal convection systems

    SciTech Connect (OSTI)

    Sorey, M.L.

    1982-01-01

    Geothermal reservoirs commonly exist in hydrothermal convection systems involving fluid circulation downward in areas of recharge and upwards in areas of discharge. Because such reservoirs are not isolated from their surroundings, the nature of thermal and hydrologic connections with the rest of the system may have significant effects on the natural state of the reservoir and on its response to development. Conditions observed at numerous developed and undeveloped geothermal fields are discussed with respect to a basic model of the discharge portion of an active hydrothermal convection system. Effects of reservoir development on surficial discharge of thermal fluid are also delineated.

  16. Storage capacity in hot dry rock reservoirs

    DOE Patents [OSTI]

    Brown, Donald W. (Los Alamos, NM)

    1997-01-01

    A method of extracting thermal energy, in a cyclic manner, from geologic strata which may be termed hot dry rock. A reservoir comprised of hot fractured rock is established and water or other liquid is passed through the reservoir. The water is heated by the hot rock, recovered from the reservoir, cooled by extraction of heat by means of heat exchange apparatus on the surface, and then re-injected into the reservoir to be heated again. Water is added to the reservoir by means of an injection well and recovered from the reservoir by means of a production well. Water is continuously provided to the reservoir and continuously withdrawn from the reservoir at two different flow rates, a base rate and a peak rate. Increasing water flow from the base rate to the peak rate is accomplished by rapidly decreasing backpressure at the outlet of the production well in order to meet periodic needs for amounts of thermal energy greater than a baseload amount, such as to generate additional electric power to meet peak demands. The rate of flow of water provided to the hot dry rock reservoir is maintained at a value effective to prevent depletion of the liquid

  17. Full Reviews: Reservoir Characterization | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    The Role of Geochemistry and Stress on Fracture Development and Proppant Behavior in EGS Reservoirs Joseph Moore and John McLennan, University of Utah Project Presentation | Peer ...

  18. Modeling of Geothermal Reservoirs: Fundamental Processes, Computer...

    Open Energy Info (EERE)

    of Geothermal Reservoirs: Fundamental Processes, Computer Simulation and Field Applications Jump to: navigation, search OpenEI Reference LibraryAdd to library Journal Article:...

  19. Increasing Waterflooding Reservoirs in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Clarke, Don; Koerner, Roy; Moos, Dan; Nguyen, John; Phillips, Chris; Tagbor, Kwasi; Walker, Scott

    1999-11-09

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period July - September 1998 and to report all technical data and findings as specified in the ''Federal Assistance Reporting Checklist''. The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology.

  20. Reservoir Engineering for Unconventional Gas Reservoirs: What Do We Have to Consider?

    SciTech Connect (OSTI)

    Clarkson, Christopher R

    2011-01-01

    The reservoir engineer involved in the development of unconventional gas reservoirs (UGRs) is required to integrate a vast amount of data from disparate sources, and to be familiar with the data collection and assessment. There has been a rapid evolution of technology used to characterize UGR reservoir and hydraulic fracture properties, and there currently are few standardized procedures to be used as guidance. Therefore, more than ever, the reservoir engineer is required to question data sources and have an intimate knowledge of evaluation procedures. We propose a workflow for the optimization of UGR field development to guide discussion of the reservoir engineer's role in the process. Critical issues related to reservoir sample and log analysis, rate-transient and production data analysis, hydraulic and reservoir modeling and economic analysis are raised. Further, we have provided illustrations of each step of the workflow using tight gas examples. Our intent is to provide some guidance for best practices. In addition to reviewing existing methods for reservoir characterization, we introduce new methods for measuring pore size distribution (small-angle neutron scattering), evaluating core-scale heterogeneity, log-core calibration, evaluating core/log data trends to assist with scale-up of core data, and modeling flow-back of reservoir fluids immediately after well stimulation. Our focus in this manuscript is on tight and shale gas reservoirs; reservoir characterization methods for coalbed methane reservoirs have recently been discussed.

  1. Economics of Developing Hot Stratigraphic Reservoirs

    SciTech Connect (OSTI)

    Greg Mines; Hillary Hanson; Rick Allis; Joseph Moore

    2014-09-01

    Stratigraphic geothermal reservoirs at 3 – 4 km depth in high heat-flow basins are capable of sustaining 100 MW-scale power plants at about 10 c/kWh. This paper examines the impacts on the levelized cost of electricity (LCOE) of reservoir depth and temperature, reservoir productivity, and drillhole/casing options. For a reservoir at 3 km depth with a moderate productivity index by hydrothermal reservoir standards (about 50 L/s/MPa, 5.6 gpm/psi), an LCOE of 10c/kWh requires the reservoir to be at about 200°C. This is the upper temperature limit for pumps. The calculations assume standard hydrothermal drilling costs, with the production interval completed with a 7 inch liner in an 8.5 inch hole. If a reservoir at 4 km depth has excellent permeability characteristics with a productivity index of 100 L/s/MPa (11.3 gpm/psi), then the LCOE is about 11 c/kWh assuming the temperature decline rate with development is not excessive (< 1%/y, with first thermal breakthrough delayed by about 10 years). Completing wells with modest horizontal legs (e.g. several hundred meters) may be important for improving well productivity because of the naturally high, sub-horizontal permeability in this type of reservoir. Reducing the injector/producer well ratio may also be cost-effective if the injectors are drilled as larger holes.

  2. Water resources review: Wheeler Reservoir, 1990

    SciTech Connect (OSTI)

    Wallus, R.; Cox, J.P.

    1990-09-01

    Protection and enhancement of water quality is essential for attaining the full complement of beneficial uses of TVA reservoirs. The responsibility for improving and protecting TVA reservoir water quality is shared by various federal, state, and local agencies, as well as the thousands of corporations and property owners whose individual decisions affect water quality. TVA's role in this shared responsibility includes collecting and evaluating water resources data, disseminating water resources information, and acting as a catalyst to bring together agencies and individuals that have a responsibility or vested interest in correcting problems that have been identified. This report is one in a series of status reports that will be prepared for each of TVA's reservoirs. The purpose of this status report is to provide an up-to-date overview of the characteristics and conditions of Wheeler Reservoir, including: reservoir purposes and operation; physical characteristics of the reservoir and the watershed; water quality conditions: aquatic biological conditions: designated, actual, and potential uses of the reservoir and impairments of those uses; ongoing or planned reservoir management activities. Information and data presented here are form the most recent reports, publications, and original data available. 21 refs., 8 figs., 29 tabs.

  3. Development of Reservoir Characterization Techniques and Production Models for Exploiting Naturally Fractured Reservoirs

    SciTech Connect (OSTI)

    Wiggins, Michael L.; Brown, Raymon L.; Civan, Faruk; Hughes, Richard G.

    2003-02-11

    This research was directed toward developing a systematic reservoir characterization methodology which can be used by the petroleum industry to implement infill drilling programs and/or enhanced oil recovery projects in naturally fractured reservoir systems in an environmentally safe and cost effective manner. It was anticipated that the results of this research program will provide geoscientists and engineers with a systematic procedure for properly characterizing a fractured reservoir system and a reservoir/horizontal wellbore simulator model which can be used to select well locations and an effective EOR process to optimize the recovery of the oil and gas reserves from such complex reservoir systems.

  4. Increasing Waterflood Reserves in the Wilmington Oil Field Through Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Chris Phillips; Dan Moos; Don Clarke; John Nguyen; Kwasi Tagbor; Roy Koerner; Scott Walker

    1997-04-10

    This project is intended to increase recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs. Transferring technology so that it can be applied in other sections of the Wilmington Field and by operators in other slope and basin reservoirs is a primary component of the project.

  5. The Potosi Reservoir Model 2013

    SciTech Connect (OSTI)

    Adushita, Yasmin; Smith, Valerie; Leetaru, Hannes

    2014-09-30

    As a part of a larger project co-funded by the United States Department of Energy (US DOE) to evaluate the potential of formations within the Cambro-Ordovician strata above the Mt. Simon as potential targets for carbon sequestration in the Illinois and Michigan Basins, the Illinois Clean Coal Institute (ICCI) requested Schlumberger to evaluate the potential injectivity and carbon dioxide (CO2) plume size of the Cambrian Potosi Formation. The evaluation of this formation was accomplished using wireline data, core data, pressure data, and seismic data from the US DOE-funded Illinois Basin–Decatur Project (IBDP) being conducted by the Midwest Geological Sequestration Consortium in Macon County, Illinois. In 2010, technical performance evaluations on the Cambrian Potosi Formation were performed through reservoir modeling. The data included formation tops from mud logs, well logs from the VW1 and the CCS1 wells, structural and stratigraphic formation from three dimensional (3D) seismic data, and field data from several waste water injection wells for Potosi Formation. Intention was for two million tons per annum (MTPA) of CO2 to be injected for 20 years. In the preceding, the 2010 Potosi heterogeneous model (referred to as the "Potosi Dynamic Model 2010" in this topical report) was re-run using a new injection scenario; 3.2 MTPA for 30 years. The extent of the Potosi Dynamic Model 2010, however, appeared too small for the new injection target. It was not sufficiently large enough to accommodate the evolution of the plume. The new model, Potosi Dynamic Model 2013a, was built by extending the Potosi Dynamic Model 2010 grid to 30 miles x 30 miles (48.3km x48.3km), while preserving all property modeling workflows and layering. This model was retained as the base case of Potosi Dynamic Model 2013a. The Potosi reservoir model was updated to take into account the new data from the verification well VW2 which was drilled in 2012. The new porosity and permeability modeling was performed to take into account the log data from the new well. Revisions of the 2010 modeling assumptions were also done on relative permeability, capillary pressures, formation water salinity, and the maximum allowable well bottomhole pressure. Dynamic simulations were run using the injection target of 3.2 MTPA for 30 years. This new dynamic model was named Potosi Dynamic Model 2013b. Due to the major uncertainties on the vugs permeability, two models were built; the Pessimistic and Optimistic Cases. The Optimistic Case assumes vugs permeability of 9,000 mD, which is analog to the vugs permeability identified in the pressure fall off test of a waste water injector in the Tuscola site, approx. 40 miles (64.4km) away from the IBDP area. The Pessimistic Case assumes that the vugs permeability is equal to the log data, which does not take into account the permeability from secondary porosity. The probability of such case is deemed low and could be treated as the worst case scenario, since the contribution of secondary porosity to the permeability is neglected and the loss circulation events might correspond to a much higher permeability. It is considered important, however, to identify the range of possible reservoir performance since there are no rigorous data available for the vugs permeability. The Optimistic Case gives an average CO2 injection rate of 0.8 MTPA and cumulative injection of 26 MT in 30 years, which corresponds to 27% of the injection target. The injection rate is approx. 3.2 MTPA in the first year as the well is injecting into the surrounding vugs, and declines rapidly to 0.8 MTPA in year 4 once the surrounding vugs are full and the CO2 start to reach the matrix. This implies that according to this preliminary model, a minimum of four (4) wells could be required to achieve the injection target. This result is lower than the injectivity estimated in the Potosi Dynamic Model 2013a (43 MT in 30 years), since the permeability model applied in the Potosi Dynamic Model 2013b is more conservative. This revision was deemed necessary to treat the uncertainty in a more appropriate manner. As the CO2 follows the paths where vugs interconnection exists, a reasonably large and irregular plume extent was created. For the Optimistic Case, the plume extends 17 miles (27.4km) in E-W and 14 miles (22.5km) in N-S directions after 30 years. After injection is completed, the plume continues to migrate laterally, mainly driven by the remaining pressure gradient. After 100 years post injection, the plume extends 20 miles (32.2km) in E-W and 15.5 miles (24.9km) in N-S directions. Should the targeted cumulative injection of 96 MT be achieved; a much larger plume extent could be expected. For the Optimistic Case, the increase of reservoir pressure at the end of injection is approximately 1200 psia (8,274 kPa) around the injector and gradually decreases away from the well. The reservoir pressure increase is less than 30 psia (206.8 kPa) beyond 14 miles (22.5km) away from injector. Should the targeted cumulative injection of 96 MT be achieved; a much larger areal pressure increase could be expected. The initial reservoir pressure is nearly restored after approximately 100 years post injection. The presence of matrix slows down the pressure dissipations. The Pessimistic Case gives an average CO2 injection rate of 0.2 MTPA and cumulative injection of 7 MT in 30 years, which corresponds to 7% of the injection target. This implies that in the worst case scenario, a minimum of sixteen (16) wells could be required to achieve the injection target. The present evaluation is mainly associated with uncertainty on the vugs permeability, distribution, and interconnectivity. The different results indicated by the Optimistic and Pessimistic Cases signify the importance of vugs permeability characterization. Therefore, injection test and pressure interference test among the wells could be considered to evaluate the local vugs permeability, extent, and interconnectivity. Porosity mapping derived from the seismic inversion could also be used in the succeeding task to characterize the lateral porosity distribution within the reservoir. With or without seismic inversion porosity mapping, it is worth exploring whether increased lateral heterogeneity plays a significant role in Potosi injectivity. Investigations on vugular, dolomitic outcrops suggest that there may be significantly greater lateral heterogeneity than what has been modeled here. Facies modeling within the Potosi has yet to be thoroughly addressed. The carbonates during the time of deposition are believed to be regionally extensive. However, it may be worth delineating the reservoir with other regional wells or modern day analogues to understand the extent of the Potosi. More specifically, the model could incorporate lateral changes or trends if deemed necessary to represent facies transition. Data acquisitions to characterize the fracture pressure gradient, the formation water properties, the relative permeability, and the capillary pressure could also be considered in order to allow a more rigorous evaluation of the Potosi storage performance. A simulation using several injectors could also be considered to determine the required number of wells to achieve the injection target while taking into account the pressure interference.

  6. EIA - Natural Gas Pipeline Network - Depleted Reservoir Storage

    Gasoline and Diesel Fuel Update (EIA)

    Configuration Depleted Reservoir Storage Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 2007/2008 with selected updates Depleted Production Reservoir Underground Natural Gas Storage Well Configuration Depleted Production Reservoir Storage

  7. Monitoring EGS Stimulation and Reservoir Dynamics with InSAR...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    EGS Stimulation and Reservoir Dynamics with InSAR and MEQ Monitoring EGS Stimulation and Reservoir Dynamics with InSAR and MEQ Monitoring EGS Stimulation and Reservoir Dynamics ...

  8. Geysers Hi-T Reservoir Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Geysers Hi-T Reservoir Geothermal Area Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Geysers Hi-T Reservoir Geothermal Area Contents 1 Area Overview 2 History and...

  9. An Updated Conceptual Model Of The Los Humeros Geothermal Reservoir...

    Open Energy Info (EERE)

    Humeros Geothermal Reservoir (Mexico) Abstract An analysis of production and reservoir engineering data of 42 wells from the Los Humeros geothermal field (Mexico) allowed...

  10. IPGT Reservoir Modeling Working Group | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    IPGT Reservoir Modeling Working Group Summary of recommendations and geothermal reservoir benchmarking workshop PDF icon gtp2012peerreviewreservoirmodeling.pdf More Documents & ...

  11. EIA - Natural Gas Pipeline Network - Depleted Reservoir Storage...

    U.S. Energy Information Administration (EIA) Indexed Site

    Gas based on data through 20072008 with selected updates Depleted Production Reservoir Underground Natural Gas Storage Well Configuration Depleted Production Reservoir Storage

  12. Dispersed Fluid Flow in Fractured Reservoirs- an Analysis of...

    Open Energy Info (EERE)

    Reservoirs- an Analysis of Tracer-Determined Residence Time Distributions Abstract A methodology for analyzing the internal flow characteristics of a fractured geothermal reservoir...

  13. Two-dimensional simulation of the Raft River geothermal reservoir...

    Open Energy Info (EERE)

    of the Raft River geothermal reservoir and wells. (SINDA-3G program) Abstract Computer models describing both the transient reservoir pressure behavior and the time...

  14. Update on the Raft River Geothermal Reservoir | Open Energy Informatio...

    Open Energy Info (EERE)

    the Raft River Geothermal Reservoir Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Proceedings: Update on the Raft River Geothermal Reservoir...

  15. EIA - Natural Gas Pipeline Network - Salt Cavern Storage Reservoir...

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Salt Cavern Underground Natural Gas Storage Reservoir Configuration Salt Cavern Underground Natural Gas Storage Reservoir Configuration Source: PB Energy Storage Services Inc.

  16. Performance testing the Phase 2 HDR reservoir

    SciTech Connect (OSTI)

    Ponden, R.F.; Dreesen, D.S. ); Thomson, J.C. )

    1991-01-01

    The geothermal energy program at the Los Alamos National Laboratory is directed toward developing the Hot Dry Rock (HDR) technology as an alternate energy source. Positive results have been obtained in previous circulation tests of HDR reservoirs at the Laboratory's test site in Fenton Hill, New Mexico. There still remains however, the need to demonstrate that adequate geothermal energy can be extracted in an efficient manner to support commercial power production. This year, the Laboratory will begin a circulation test of its Phase 2, reservoir. The objectives of this test are to characterize steady-state power production and long-term reservoir performance. 6 refs., 2 figs., 3 tabs.

  17. Characterization of geothermal reservoir crack patterns using...

    Open Energy Info (EERE)

    the time delays of the split waves they determined tomographically the 3-D fracture density distribution in the reservoir. Authors Lou, M.; Rial and J.A. Published Journal...

  18. Magic Reservoir Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    110C383.15 K 230 F 689.67 R 1 USGS Estimated Reservoir Volume: 2 km 1 USGS Mean Capacity: 9 MW 1 Click "Edit With Form" above to add content History and...

  19. Fifteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Not Available

    1990-01-01

    The Fifteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 23--25, 1990. Major topics included: DOE's geothermal research and development program, well testing, field studies, geosciences, geysers, reinjection, tracers, geochemistry, and modeling.

  20. Three-dimensional Modeling of Fracture Clusters in Geeothermal Reservoirs |

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Department of Energy Geeothermal Reservoirs Three-dimensional Modeling of Fracture Clusters in Geeothermal Reservoirs Three-dimensional Modeling of Fracture Clusters in Geeothermal Reservoirs presentation at the April 2013 peer review meeting held in Denver, Colorado. PDF icon ghassemi_factures_peer2013.pdf More Documents & Publications Three-dimensional Modeling of Fracture Clusters in Geothermal Reservoirs Three-dimensional Modeling of Fracture Clusters in Geothermal Reservoirs; 2010

  1. Application of integrated reservoir management and reservoir characterization to optimize infill drilling, Class II

    SciTech Connect (OSTI)

    Bergeron, Jack; Blasingame, Tom; Doublet, Louis; Kelkar, Mohan; Freeman, George; Callard, Jeff; Moore, David; Davies, David; Vessell, Richard; Pregger, Brian; Dixon, Bill; Bezant, Bryce

    2000-03-16

    The major purpose of this project was to demonstrate the use of cost effective reservoir characterization and management tools that will be helpful to both independent and major operators for the optimal development of heterogeneous, low permeability carbonate reservoirs such as the North Robertson (Clearfork) Unit.

  2. Reservoir Characterization, Production Characteristics, and Research Needs for Fluvial/Alluvial Reservoirs in the United States

    SciTech Connect (OSTI)

    Cole, E.L.; Fowler, M.L.; Jackson, S.R.; Madden, M.P.; Raw-Schatzinger, V.; Salamy, S.P.; Sarathi, P.; Young, M.A.

    1999-04-28

    The Department of Energy's (DOE's) Oil Recovery Field Demonstration Program was initiated in 1992 to maximize the economically and environmentally sound recovery of oil from known domestic reservoirs and to preserve access to this resource. Cost-shared field demonstration projects are being initiated in geology defined reservoir classes which have been prioritized by their potential for incremental recovery and their risk of abandonment. This document defines the characteristics of the fifth geological reservoir class in the series, fluvial/alluvial reservoirs. The reservoirs of Class 5 include deposits of alluvial fans, braided streams, and meandering streams. Deposit morphologies vary as a complex function of climate and tectonics and are characterized by a high degree of heterogeneity to fluid flow as a result of extreme variations in water energy as the deposits formed.

  3. Experience in operating the Bratsk Reservoir

    SciTech Connect (OSTI)

    Nazarov, A.V.

    1984-04-01

    The Bratsk reservoir is the largest in the USSR and second largest in the world. Initially, the reservoir was expected to be filled by the end of 1966. However, the actual filling was not completed until September of 1967. During filling and in the first years of operation it was constantly necessary to deal with floating timber in order to ensure normal operation of the hydrostation, navigation safety, conditions for fishery, and fulfillment of the sanitary requirements. During seasonal variations of the reservoir level about 160 sq km of the shore zone was subjected to variable flooding and waterlogging. Maximum erosion occurred on expanded stretches, and within their limits on slopes composed of loam and sand deposits. Within the narrows, where the banks are composed mainly of hard and soft rocks and wave action is weak, erosion is negligible. Wind setup and setdown cause maximum denivellation of the water surface. The maximum increase of the level during setup reaches 232 cm and the maximum decrease during setdown is 24 cm. Seiche oscillations with various amplitudes and periods are observed on the reservoir surface. The main uses of the complex are hydropower, water transport, timber floating, water supply, and fishery. For the successful development of the shores of reservoirs it is necessary to select the construction sites with consideration of possible occurrence of karstic and landslide processes; the construction of heavy structures requires special karst-control measures. 3 references, 3 figures, 1 table.

  4. Eolian reservoir characteristics predicted from dune type

    SciTech Connect (OSTI)

    Kocurek, G.; Nielson, J.

    1985-02-01

    The nature of eolian-dune reservoirs is strongly influenced by stratification types (in decreasing order of quality: grain-flow, grain-fall, wind-ripple deposits) and their packaging by internal bounding surfaces. These are, in turn, a function of dune surface processes and migration behavior, allowing for predictive models of reservoir behavior. Migrating, simple crescentic dunes produce tabular bodies consisting mainly of grain-flow cross-strata, and form the best, most predictable reservoirs. Reservoir character improves as both original dune height and preserved set thickness increase, because fewer grain-fall deposits and a lower percentage of dune-apron deposits occur in the cross-strata, respectively. It is probable that many linear and star dunes migrate laterally, leaving a blanket of packages of wind ripple laminae reflecting deposition of broad, shifting aprons. This is distinct from models generated by freezing large portions of these dunes in place. Trailing margins of linear and star dunes are prone to reworking by sand-sheet processes that decrease potential reservoir quality. The occurrence of parabolic dunes isolated on vegetated sand sheets results in a core of grain-flow and grain-fall deposits surrounded by less permeable and porous deposits. Compound crescentic dunes, perhaps the most preservable dune type, may yield laterally (1) single sets of cross-strate, (2) compound sets derived from superimposed simple dunes, or (3) a complex of diverse sets derived from superimposed transverse and linear elements.

  5. Silurian "Clinton" Sandstone Reservoir Characterization for Evaluation of CO2-EOR Potential in the East Canton Oil Field, Ohio

    SciTech Connect (OSTI)

    Ronald Riley; John Wicks; Christopher Perry

    2009-12-30

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian 'Clinton' sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test ('Huff-n-Puff') was conducted on a well in Stark County to test the injectivity in a 'Clinton'-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day 'soak' period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the 'Clinton' sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent, gradual flashout of the CO2 within the reservoir during the ensuing monitored production period; and (D) a large amount of CO2 continually off-gassed from wellhead oil samples collected as late as 3 1/2 months after injection. After the test well was returned to production, it produced 174 bbl of oil during a 60-day period (September 22 to November 21, 2008), which represents an estimated 58 percent increase in incremental oil production over preinjection estimates of production under normal, conditions. The geologic model was used in a reservoir simulation model for a 700-acre model area and to design a pilot to test the model. The model was designed to achieve a 1-year response time and a five-year simulation period. The reservoir simulation modeling indicated that the injection wells could enhance oil production and lead to an additional 20 percent recovery in the pilot area over a five-year period. The base case estimated that by injecting 500 MCF per day of CO2 into each of the four corner wells, 26,000 STBO would be produced by the central producer over the five-year period. This would compare to 3,000 STBO if a new well were drilled without the benefit of CO2 injection. This study has added significant knowledge to the reservoir characterization of the 'Clinton' in the ECOF and succeeded in identifying a range on CO2-EOR potential. However, additional data on fluid properties (PVT and swelling test), fractures (oriented core and microseis), and reservoir characteristics (relative permeability, capillary pressure, and wet ability) are needed to further narrow the uncertainties and refine the reservoir model and simulation. After collection of this data and refinement of the model and simulation, it is recommended that a larger scale cyclic-CO2 injection test be conducted to better determine the efficacy of CO2-EOR in the 'Clinton' reservoir in the ECOF.

  6. Silurian "Clinton" Sandstone Reservoir Characterization for Evaluation of CO2-EOR Potential in the East Canton Oil Field, Ohio

    SciTech Connect (OSTI)

    Riley, Ronald; Wicks, John; Perry, Christopher

    2009-12-30

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian Clinton sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test (Huff-n-Puff) was conducted on a well in Stark County to test the injectivity in a Clinton-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day soak period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the Clinton sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent, gradual flashout of the CO2 within the reservoir during the ensuing monitored production period; and (D) a large amount of CO2 continually off-gassed from wellhead oil samples collected as late as 3 months after injection. After the test well was returned to production, it produced 174 bbl of oil during a 60-day period (September 22 to November 21, 2008), which represents an estimated 58 percent increase in incremental oil production over preinjection estimates of production under normal, conditions. The geologic model was used in a reservoir simulation model for a 700-acre model area and to design a pilot to test the model. The model was designed to achieve a 1-year response time and a five-year simulation period. The reservoir simulation modeling indicated that the injection wells could enhance oil production and lead to an additional 20 percent recovery in the pilot area over a five-year period. The base case estimated that by injecting 500 MCF per day of CO2 into each of the four corner wells, 26,000 STBO would be produced by the central producer over the five-year period. This would compare to 3,000 STBO if a new well were drilled without the benefit of CO2 injection. This study has added significant knowledge to the reservoir characterization of the Clinton in the ECOF and succeeded in identifying a range on CO2-EOR potential. However, additional data on fluid properties (PVT and swelling test), fractures (oriented core and microseis), and reservoir characteristics (relative permeability, capillary pressure, and wet ability) are needed to further narrow the uncertainties and refine the reservoir model and simulation. After collection of this data and refinement of the model and simulation, it is recommended that a larger scale cyclic- CO2 injection test be conducted to better determine the efficacy of CO2-EOR in the Clinton reservoir in the ECOF.

  7. Improved characterization of reservoir behavior by integration of reservoir performances data and rock type distributions

    SciTech Connect (OSTI)

    Davies, D.K.; Vessell, R.K.; Doublet, L.E.

    1997-08-01

    An integrated geological/petrophysical and reservoir engineering study was performed for a large, mature waterflood project (>250 wells, {approximately}80% water cut) at the North Robertson (Clear Fork) Unit, Gaines County, Texas. The primary goal of the study was to develop an integrated reservoir description for {open_quotes}targeted{close_quotes} (economic) 10-acre (4-hectare) infill drilling and future recovery operations in a low permeability, carbonate (dolomite) reservoir. Integration of the results from geological/petrophysical studies and reservoir performance analyses provide a rapid and effective method for developing a comprehensive reservoir description. This reservoir description can be used for reservoir flow simulation, performance prediction, infill targeting, waterflood management, and for optimizing well developments (patterns, completions, and stimulations). The following analyses were performed as part of this study: (1) Geological/petrophysical analyses: (core and well log data) - {open_quotes}Rock typing{close_quotes} based on qualitative and quantitative visualization of pore-scale features. Reservoir layering based on {open_quotes}rock typing {close_quotes} and hydraulic flow units. Development of a {open_quotes}core-log{close_quotes} model to estimate permeability using porosity and other properties derived from well logs. The core-log model is based on {open_quotes}rock types.{close_quotes} (2) Engineering analyses: (production and injection history, well tests) Material balance decline type curve analyses to estimate total reservoir volume, formation flow characteristics (flow capacity, skin factor, and fracture half-length), and indications of well/boundary interference. Estimated ultimate recovery analyses to yield movable oil (or injectable water) volumes, as well as indications of well and boundary interference.

  8. INCREASING WATERFLOOD RESERVES IN THE WILMINGTON OIL FIELD THROUGH IMPROVED RESERVOIR CHARACTERIZATION AND RESERVOIR MANAGEMENT

    SciTech Connect (OSTI)

    Scott Walker; Chris Phillips; Roy Koerner; Don Clarke; Dan Moos; Kwasi Tagbor

    2002-02-28

    This project increased recoverable waterflood reserves in slope and basin reservoirs through improved reservoir characterization and reservoir management. The particular application of this project is in portions of Fault Blocks IV and V of the Wilmington Oil Field, in Long Beach, California, but the approach is widely applicable in slope and basin reservoirs. Transferring technology so that it can be applied in other sections of the Wilmington Field and by operators in other slope and basin reservoirs is a primary component of the project. This project used advanced reservoir characterization tools, including the pulsed acoustic cased-hole logging tool, geologic three-dimensional (3-D) modeling software, and commercially available reservoir management software to identify sands with remaining high oil saturation following waterflood. Production from the identified high oil saturated sands was stimulated by recompleting existing production and injection wells in these sands using conventional means as well as a short radius redrill candidate. Although these reservoirs have been waterflooded over 40 years, researchers have found areas of remaining oil saturation. Areas such as the top sand in the Upper Terminal Zone Fault Block V, the western fault slivers of Upper Terminal Zone Fault Block V, the bottom sands of the Tar Zone Fault Block V, and the eastern edge of Fault Block IV in both the Upper Terminal and Lower Terminal Zones all show significant remaining oil saturation. Each area of interest was uncovered emphasizing a different type of reservoir characterization technique or practice. This was not the original strategy but was necessitated by the different levels of progress in each of the project activities.

  9. DEVELOPMENT OF RESERVOIR CHARACTERIZATION TECHNIQUES AND PRODUCTION MODELS FOR EXPLOITING NATURALLY FRACTURED RESERVOIRS

    SciTech Connect (OSTI)

    Michael L. Wiggins; Raymon L. Brown; Faruk Civan; Richard G. Hughes

    2002-12-31

    For many years, geoscientists and engineers have undertaken research to characterize naturally fractured reservoirs. Geoscientists have focused on understanding the process of fracturing and the subsequent measurement and description of fracture characteristics. Engineers have concentrated on the fluid flow behavior in the fracture-porous media system and the development of models to predict the hydrocarbon production from these complex systems. This research attempts to integrate these two complementary views to develop a quantitative reservoir characterization methodology and flow performance model for naturally fractured reservoirs. The research has focused on estimating naturally fractured reservoir properties from seismic data, predicting fracture characteristics from well logs, and developing a naturally fractured reservoir simulator. It is important to develop techniques that can be applied to estimate the important parameters in predicting the performance of naturally fractured reservoirs. This project proposes a method to relate seismic properties to the elastic compliance and permeability of the reservoir based upon a sugar cube model. In addition, methods are presented to use conventional well logs to estimate localized fracture information for reservoir characterization purposes. The ability to estimate fracture information from conventional well logs is very important in older wells where data are often limited. Finally, a desktop naturally fractured reservoir simulator has been developed for the purpose of predicting the performance of these complex reservoirs. The simulator incorporates vertical and horizontal wellbore models, methods to handle matrix to fracture fluid transfer, and fracture permeability tensors. This research project has developed methods to characterize and study the performance of naturally fractured reservoirs that integrate geoscience and engineering data. This is an important step in developing exploitation strategies for optimizing the recovery from naturally fractured reservoir systems. The next logical extension of this work is to apply the proposed methods to an actual field case study to provide information for verification and modification of the techniques and simulator. This report provides the details of the proposed techniques and summarizes the activities undertaken during the course of this project. Technology transfer activities were highlighted by a two-day technical conference held in Oklahoma City in June 2002. This conference attracted over 90 participants and included the presentation of seventeen technical papers from researchers throughout the United States.

  10. Tight gas reservoirs: A visual depiction

    SciTech Connect (OSTI)

    Not Available

    1993-12-01

    Future gas supplies in the US will depend on an increasing contribution from unconventional sources such as overpressured and tight gas reservoirs. Exploitation of these resources and their conversion to economically producible gas reserves represents a major challenge. Meeting this challenge will require not only the continuing development and application of new technologies, but also a detailed understanding of the complex nature of the reservoirs themselves. This report seeks to promote understanding of these reservoirs by providing examples. Examples of gas productive overpressured tight reservoirs in the Greater Green River Basin, Wyoming are presented. These examples show log data (raw and interpreted), well completion and stimulation information, and production decline curves. A sampling of wells from the Lewis and Mesaverde formations are included. Both poor and good wells have been chosen to illustrate the range of productivity that is observed. The second section of this document displays decline curves and completion details for 30 of the best wells in the Greater Green River Basin. These are included to illustrate the potential that is present when wells are fortuitously located with respect to local stratigraphy and natural fracturing, and are successfully hydraulically fractured.

  11. Underground natural gas storage reservoir management

    SciTech Connect (OSTI)

    Ortiz, I.; Anthony, R.

    1995-06-01

    The objective of this study is to research technologies and methodologies that will reduce the costs associated with the operation and maintenance of underground natural gas storage. This effort will include a survey of public information to determine the amount of natural gas lost from underground storage fields, determine the causes of this lost gas, and develop strategies and remedial designs to reduce or stop the gas loss from selected fields. Phase I includes a detailed survey of US natural gas storage reservoirs to determine the actual amount of natural gas annually lost from underground storage fields. These reservoirs will be ranked, the resultant will include the amount of gas and revenue annually lost. The results will be analyzed in conjunction with the type (geologic) of storage reservoirs to determine the significance and impact of the gas loss. A report of the work accomplished will be prepared. The report will include: (1) a summary list by geologic type of US gas storage reservoirs and their annual underground gas storage losses in ft{sup 3}; (2) a rank by geologic classifications as to the amount of gas lost and the resultant lost revenue; and (3) show the level of significance and impact of the losses by geologic type. Concurrently, the amount of storage activity has increased in conjunction with the net increase of natural gas imports as shown on Figure No. 3. Storage is playing an ever increasing importance in supplying the domestic energy requirements.

  12. Fourteenth workshop geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

    1989-12-31

    The Fourteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 24--26, 1989. Major areas of discussion include: (1) well testing; (2) various field results; (3) geoscience; (4) geochemistry; (5) reinjection; (6) hot dry rock; and (7) numerical modelling. For these workshop proceedings, individual papers are processed separately for the Energy Data Base.

  13. Fourteenth workshop geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

    1989-01-01

    The Fourteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 24--26, 1989. Major areas of discussion include: (1) well testing; (2) various field results; (3) geoscience; (4) geochemistry; (5) reinjection; (6) hot dry rock; and (7) numerical modelling. For these workshop proceedings, individual papers are processed separately for the Energy Data Base.

  14. Tracer testing in geothermal reservoirs | Open Energy Information

    Open Energy Info (EERE)

    geothermal reservoirs Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Tracer testing in geothermal reservoirs Author PetroWiki Published PetroWiki,...

  15. EIA - Natural Gas Pipeline Network - Aquifer Storage Reservoir

    Gasoline and Diesel Fuel Update (EIA)

    Configuration Aquifer Storage Reservoir Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 2007/2008 with selected updates Aquifer Underground Natural Gas Storage Reservoir Configuration Aquifer Underground Natural Gas Well

  16. Texas Dry Natural Gas New Reservoir Discoveries in Old Fields...

    U.S. Energy Information Administration (EIA) Indexed Site

    New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Texas Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3...

  17. Monitoring and Modeling Fluid Flow in a Developing EGS Reservoir

    Broader source: Energy.gov [DOE]

    Project objectives: Better understand and model fluid injection into a tight reservoir on the edges of a hydrothermal field. Use seismic data to constrain geomechanical/hydrologic/thermal model of reservoir.

  18. Water Sampling At Blackfoot Reservoir Area (Hutsinpiller & Parry...

    Open Energy Info (EERE)

    Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Exploration Activity: Water Sampling At Blackfoot Reservoir Area (Hutsinpiller & Parry, 1985) Exploration Activity...

  19. Assessing the relative permeability of heterogeneous reservoir rock

    Office of Scientific and Technical Information (OSTI)

    (Conference) | SciTech Connect Conference: Assessing the relative permeability of heterogeneous reservoir rock Citation Details In-Document Search Title: Assessing the relative permeability of heterogeneous reservoir rock Reservoir engineers are often faced with heterogeneous core material, for which conventional methods of estimating relative permeability are susceptible to error and may lead to incorrect conclusions regarding displacement efficiency, wettability and reservoir performance.

  20. Reservoir Modeling Working Group Meeting | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Reservoir Modeling Working Group Meeting Reservoir Modeling Working Group Meeting Reservoir Modeling working group meeting presentation on May 10, 2012 at the 2012 Peer Review Meeting. PDF icon gtp_2012peerreview_reservoir_modeling_wg.pdf More Documents & Publications Welcome to the Geothermal Technologies Program 2012 Annual Peer Review Integration of Noise and Coda Correlation Data into Kinematic and Waveform Inversions Stanford Geothermal Workshop 2012 Annual Meeting

  1. Incorporating reservoir heterogeneity with geostatistics to investigate waterflood recoveries

    SciTech Connect (OSTI)

    Wolcott, D.S. ); Chopra, A.K. )

    1993-03-01

    This paper presents an investigation of infill drilling performance and reservoir continuity with geostatistics and a reservoir simulator. The geostatistical technique provides many possible realizations and realistic descriptions of reservoir heterogeneity. Correlation between recovery efficiency and thickness of individual sand subunits is shown. Additional recovery from infill drilling results from thin, discontinuous subunits. The technique may be applied to variations in continuity for other sandstone reservoirs.

  2. Increasing Waterflood Reserves in the Wilmington Oil Field through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Clarke, D.; Koerner, R.; Moos D.; Nguyen, J.; Phillips, C.; Tagbor, K.; Walker, S.

    1999-04-05

    This project used advanced reservoir characterization tools, including the pulsed acoustic cased-hole logging tool, geologic three-dimensional (3-D) modeling software, and commercially available reservoir management software to identify sands with remaining high oil saturation following waterflood. Production from the identified high oil saturated sands was stimulated by recompleting existing production and injection wells in these sands using conventional means as well as a short radius redrill candidate.

  3. Relation between facies, diagenesis, and reservoir quality of Rotliegende reservoirs in north Germany

    SciTech Connect (OSTI)

    David, F.; Gast, R.; Kraft, T. (BEB Erdgas Erdol GmbH, Hannover (Germany))

    1993-09-01

    In north Germany, the majority of Rotliegende gas fields is confined to an approximately 50 km-wide east-west-orientated belt, which is situated on the gently north-dipping flank of the southern Permian basin. Approximately 400 billion m[sup 3] of natural gas has been found in Rotliegende reservoir sandstones with average porosities of depths ranging from 3500 to 5000 m. Rotliegende deposition was controlled by the Autunian paleo-relief, and arid climate and cyclic transgressions of the desert lake. In general, wadis and large dunefields occur in the hinterland, sebkhas with small isolate dunes and shorelines define the coastal area, and a desert lake occurs to the north. The sandstones deposited in large dunefields contain only minor amounts of illite, anhydrite, and calcite and form good reservoirs. In contrast, the small dunes formed in the sebkha areas were affected by fluctuations of the desert lake groundwaters, causing the infiltration of detrital clay and precipitation of gypsum and calcite. These cements were transformed to illite, anhydrite, and calcite-II during later diagenesis, leading to a significant reduction of the reservoir quality. The best reservoirs occur in the shoreline sandstones because porosity and permeability were preserved by early magnesium-chlorite diagenesis. Since facies controls diagenesis and consequently reservoir quality, mapping of facies also indicates the distribution of reservoir and nonreservoir rocks. This information is used to identify play area and to interpret and calibrate three-dimensional seismic data.

  4. EIA - Natural Gas Pipeline Network - Salt Cavern Storage Reservoir

    Gasoline and Diesel Fuel Update (EIA)

    Configuration Salt Cavern Storage Reservoir Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 2007/2008 with selected updates Salt Cavern Underground Natural Gas Storage Reservoir Configuration Salt Cavern Underground Natural Gas Storage Reservoir Configuration Source: PB Energy Storage Services Inc.

  5. Chemistry, Reservoir, and Integrated Models | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Chemistry, Reservoir, and Integrated Models Chemistry, Reservoir, and Integrated Models Below are the project presentations and respective peer review results for Chemistry, Reservoir and Integrated Models. Development and Validation of an Advanced Stimulation Prediction Model for Enhanced Geothermal Systems (EGS), Marte Gutierrez and Masami Nakagawa, Colorado School of Mines Development of Advanced Thermal-Hydrological-Mechanical-Chemical (THMC) Modeling Capabilities for Enhanced Geothermal

  6. Template:GeothermalResourceArea | Open Energy Information

    Open Energy Info (EERE)

    USGSMeanCapacity - The USGS-defined (2008) mean capacity. MeanReservoirTemp - Literature-reported mean temperature. EstReservoirVol - Literature-reported estimated reservoir...

  7. 5641_FrozenReservoirs | netl.doe.gov

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Producing Light Oil from a Frozen Reservoir: Reservoir and Fluid Characterization of Umiat Field, National Petroleum Reserve, Alaska Last Reviewed 3/27/2013 DE-FC26-08NT0005641 Goal The goal of this project is to develop a robust reservoir model to test possible oil recovery methods that do not use steam or a liquid capable of freezing for the Umiat and similar frozen reservoirs. The results will provide important information concerning production methods for this and similar frozen reservoirs

  8. Alan Farquharson, SVP Reservoir Engineering Economics! Upstream

    Gasoline and Diesel Fuel Update (EIA)

    June 16, 2015 Alan Farquharson, SVP - Reservoir Engineering & Economics! Upstream Developments Generate Growing Hydrocarbon Gas Liquids Supply! 2 Forward-Looking Statements Certain statements and information in this presentation may constitute "forward-looking statements" within the meaning of the Private Securities Litigation Reform Act of 1995. The words "anticipate," "believe," "estimate," "expect," "forecast," "plan,"

  9. Innovative MIOR Process Utilizing Indigenous Reservoir Constituents

    SciTech Connect (OSTI)

    Hitzman, D.O.; Stepp, A.K.; Dennis, D.M.; Graumann, L.R.

    2003-02-11

    This research program was directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal was to identify indigenous microbial populations which can produce beneficial metabolic products and develop a methodology to stimulate those select microbes with inorganic nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents.

  10. ALKALINE-SURFACTANT-POLYMER FLOODING AND RESERVOIR CHARACTERIZATION OF THE BRIDGEPORT AND CYPRESS RESERVOIRS OF THE LAWRENCE FIELD

    SciTech Connect (OSTI)

    Malcolm Pitts; Ron Damm; Bev Seyler

    2003-04-01

    Feasibility of alkaline-surfactant-polymer flood for the Lawrence Field in Lawrence County, Illinois is being studied. Two injected formulations are being designed; one for the Bridgeport A and Bridgeport B reservoirs and one for Cypress and Paint Creek reservoirs. Fluid-fluid and coreflood evaluations have developed a chemical solution that produces incremental oil in the laboratory from the Cypress and Paint Creek reservoirs. A chemical formulation for the Bridgeport A and Bridgeport B reservoirs is being developed. A reservoir characterization study is being done on the Bridgeport A, B, & D sandstones, and on the Cypress sandstone. The study covers the pilot flood area and the Lawrence Field.

  11. ALKALINE-SURFACTANT-POLYMER FLOODING AND RESERVOIR CHARACTERIZATION OF THE BRIDGEPORT AND CYPRESS RESERVOIRS OF THE LAWRENCE FIELD

    SciTech Connect (OSTI)

    Malcolm Pitts; Ron Damm; Bev Seyler

    2003-03-01

    Feasibility of alkaline-surfactant-polymer flood for the Lawrence Field in Lawrence County, Illinois is being studied. Two injected formulations are being designed; one for the Bridgeport A and Bridgeport B reservoirs and one for Cypress and Paint Creek reservoirs. Fluid-fluid and coreflood evaluations have developed a chemical solution that produces incremental oil in the laboratory from the Cypress and Paint Creek reservoirs. A chemical formulation for the Bridgeport A and Bridgeport B reservoirs is being developed. A reservoir characterization study is being done on the Bridgeport A, B, & D sandstones, and on the Cypress sandstone. The study covers the pilot flood area and the Lawrence Field.

  12. Quantification of Libby Reservoir Levels Needed to Maintain or Enhance Reservoir Fisheries, 1985 Annual Report.

    SciTech Connect (OSTI)

    Chisholm, Ian

    1985-01-01

    The goal was to quantify seasonal water levels needed to maintain or enhance the reservoir fishery in Libby. This report summarizes data collected from July 1984 through July 1985, and, where appropriate, presents data collected since 1983. The Canada, Rexford, and Tenmile areas of the reservoir are differentially affected by drawdown. Relative changes in water volume and surface area are greatest in the Canada area and smallest in the Tenmile area. Reservoir morphology and hydraulics probably play a major role in fish distribution through their influence on water temperature. Greatest areas of habitat with optimum water temperature for Salmo spp. and kokanee occurred during the spring and fall months. Dissolved oxygen, pH and conductivity levels were not limiting during any sampling period. Habitat enhancement work was largely unsuccessful. Littoral zone vegetation plantings did not survive well, primarily the result of extreme water level fluctuations. Relative abundances of fish species varied seasonally within and between the three areas. Water temperature is thought to be the major influence in fish distribution patterns. Other factors, such as food availability and turbidity, may mitigate its influence. Sampling since 1975 illustrates a continued increase in kokanee numbers and a dramatic decline in redside shiners. Salmo spp., bull trout, and burbot abundances are relatively low while peamouth and coarsescale sucker numbers remain high. A thermal dynamics model and a trophic level components model will be used to quantify the impact of reservoir operation on the reservoir habitat, primary production, secondary production and fish populations. Particulate carbon will be used to track energy flow through trophic levels. A growth-driven population dynamics simulation model that will estimate the impacts of reservoir operation on fish population dynamics is also being considered.

  13. Seventeenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Cook, J.W.

    1992-01-31

    PREFACE The Seventeenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 29-31, 1992. There were one hundred sixteen registered participants which equaled the attendance last year. Participants were from seven foreign countries: Italy, Japan, United Kingdom, France, Belgium, Mexico and New Zealand. Performance of many geothermal fields outside the United States was described in the papers. The Workshop Banquet Speaker was Dr. Raffaele Cataldi. Dr. Cataldi gave a talk on the highlights of his geothermal career. The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy was awarded to Dr. Cataldi. Dr. Frank Miller presented the award at the banquet. Thirty-eight papers were presented at the Workshop with two papers submitted for publication only. Dr. Roland Horne opened the meeting and the key note speaker was J.E. ''Ted'' Mock who discussed the DOE Geothermal R. & D. Program. The talk focused on aiding long-term, cost effective private resource development. Technical papers were organized in twelve sessions concerning: geochemistry, hot dry rock, injection, geysers, modeling, and reservoir mechanics. Session chairmen were major contributors to the program and we thank: Sabodh Garg., Jim Lovekin, Jim Combs, Ben Barker, Marcel Lippmann, Glenn Horton, Steve Enedy, and John Counsil. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate audiovisual equipment and to Francois Groff who coordinated the meeting arrangements for the Workshop. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook -vii

  14. Reservoir and injection technology: Geothermal reservoir engineering research at Stanford: Third annual report for the period October 1, 1986 through September 30, 1987: (Final report)

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Horne, R.N.; Miller, F.G.; Brigham, W.E.

    1988-02-01

    This paper discusses different aspects of geothermal reservoir engineering. General topics covered are: reinjection technology, reservoir technology, and heat extraction. (LSP)

  15. Geothermal Reservoir Well Stimulation Program: technology transfer

    SciTech Connect (OSTI)

    Not Available

    1980-05-01

    A literature search on reservoir and/or well stimulation techniques suitable for application in geothermal fields is presented. The literature on stimulation techniques in oil and gas field applications was also searched and evaluated as to its relevancy to geothermal operations. The equivalent low-temperature work documented in the open literature is cited, and an attempt is made to evaluate the relevance of this information as far as high-temperature stimulation work is concerned. Clays play an important role in any stimulation work. Therefore, special emphasis has been placed on clay behavior anticipated in geothermal operations. (MHR)

  16. Innovative MIOR Process Utilizing Indigenous Reservoir Constituents

    SciTech Connect (OSTI)

    Hitzman, D.O.; Stepp, A.K.

    2003-02-11

    This research program was directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal was to identify indigenous microbial populations which can produce beneficial metabolic products and develop a methodology to stimulate those select microbes with inorganic nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents. The potential of the system will be illustrated and demonstrated by the example of biopolymer production on oil recovery.

  17. Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Stochastic Analysis of Injection-Induced Seismicity | Department of Energy Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity presentation at the April 2013 peer review meeting held in Denver,

  18. Three-dimensional Modeling of Fracture Clusters in Geothermal Reservoirs;

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    2010 Geothermal Technology Program Peer Review Report | Department of Energy Three-dimensional Modeling of Fracture Clusters in Geothermal Reservoirs; 2010 Geothermal Technology Program Peer Review Report Three-dimensional Modeling of Fracture Clusters in Geothermal Reservoirs; 2010 Geothermal Technology Program Peer Review Report DOE 2010 Geothermal Technologies Program Peer Review PDF icon reservoir_028_ghassmi.pdf More Documents & Publications Tracer Methods for Characterizing

  19. Sustainability of Shear-Induced Permeability for EGS Reservoirs...

    Broader source: Energy.gov (indexed) [DOE]

    Sustainability of Shear-Induced Permeability for EGS Reservoirs A Laboratory Study ... PDF icon kneafseyfracturesustainabilitypeer2013.pdf More Documents & Publications The ...

  20. Compound and Elemental Analysis At Blackfoot Reservoir Area ...

    Open Energy Info (EERE)

    References Amy Hutsinpiller, W. T. Parry (1985) Geochemistry And Geothermometry Of Spring Water From The Blackfoot Reservoir Region, Southeastern Idaho Additional References...

  1. Carbonation Mechanism of Reservoir Rock by Supercritical Carbon...

    Open Energy Info (EERE)

    Carbonation Mechanism of Reservoir Rock by Supercritical Carbon Dioxide Geothermal Lab Call Project Jump to: navigation, search Last modified on July 22, 2011. Project Title...

  2. Hydraulics and Well Testing of Engineered Geothermal Reservoirs...

    Open Energy Info (EERE)

    with downhole pumps from the reservoir than is injected. Authors Hugh Murphy, Donald W Brown, Reinhard Jung, Isao Matsunaga and Roger Parker Published Journal Geothermics, 1999...

  3. Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code...

    Office of Scientific and Technical Information (OSTI)

    Conference: Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code Comparison Study Citation Details In-Document Search Title: Flow and Thermal Behavior of an EGS...

  4. Deep Geothermal Reservoir Temperatures in the Eastern Snake River...

    Office of Scientific and Technical Information (OSTI)

    ESRP. Masking much of the deep thermal potential of the ... apply the RTEst model to water compositions measured from ... on Geothermal Reservoir Engineering,Stanford,02242014,02...

  5. Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code...

    Office of Scientific and Technical Information (OSTI)

    Conference: Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code Comparison Study Citation Details In-Document Search Title: Flow and Thermal Behavior of an EGS ...

  6. Pressure Testing of a High Temperature Naturally Fractured Reservoir...

    Office of Scientific and Technical Information (OSTI)

    Conference: Pressure Testing of a High Temperature Naturally Fractured Reservoir Citation Details In-Document Search Title: Pressure Testing of a High Temperature Naturally ...

  7. Variations in dissolved gas compositions of reservoir fluids...

    Open Energy Info (EERE)

    distinct regions of single-phase (liquid) reservoir are present and possess distinctive gas and liquid compositions. Relationships in soluble and insoluble gases preclude...

  8. ,"New Mexico Dry Natural Gas New Reservoir Discoveries in Old...

    U.S. Energy Information Administration (EIA) Indexed Site

    Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","New Mexico Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic...

  9. ,"Texas Dry Natural Gas New Reservoir Discoveries in Old Fields...

    U.S. Energy Information Administration (EIA) Indexed Site

    ,"Worksheet Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","Texas Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic...

  10. Use Of Electrical Surveys For Geothermal Reservoir Characterization...

    Open Energy Info (EERE)

    geothermal reservoir characteristics. Authors Sabodh K. Garg, John W. Pritchett, Philip E. Wannamaker and Jim Combs Published GRC, 2007 DOI Not Provided Check for DOI...

  11. EIA - Natural Gas Pipeline Network - Aquifer Storage Reservoir...

    U.S. Energy Information Administration (EIA) Indexed Site

    Transporting Natural Gas based on data through 20072008 with selected updates Aquifer Underground Natural Gas Storage Reservoir Configuration Aquifer Underground Natural Gas Well

  12. Tectonic setting of the Coso geothermal reservoir | Open Energy...

    Open Energy Info (EERE)

    eastern California Optimum development of this reservoir requires an understanding of the fracture hydrology of the Coso Mountains crystalline terrain and its hydrologic connection...

  13. Reservoir-Scale Fracture Permeability in the Dixie Valley, Nevada...

    Open Energy Info (EERE)

    Reservoir-Scale Fracture Permeability in the Dixie Valley, Nevada, Geothermal Field Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Paper:...

  14. Methodologies for Reservoir Characterization Using Fluid Inclusion Gas Chemistry

    Broader source: Energy.gov [DOE]

    Methodologies for Reservoir Characterization Using Fluid Inclusion Gas Chemistry presentation at the April 2013 peer review meeting held in Denver, Colorado.

  15. ,"Texas--State Offshore Crude Oil Reserves in Nonproducing Reservoirs...

    U.S. Energy Information Administration (EIA) Indexed Site

    Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","Texas--State Offshore Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)",1,"Annual",2...

  16. A Simple, Fast Method of Estimating Fractured Reservoir Geometry...

    Open Energy Info (EERE)

    Fractured Reservoir Geometry from Tracer Tests Abstract A simple method of estimating flow geometry and pore geometry from conservative tracer tests in single phase geothermal...

  17. Geothermal reservoir temperatures estimated from the oxygen isotope...

    Open Energy Info (EERE)

    applied to thermal systems of Yellowstone Park, Wyoming, Long Valley, California, and Raft River, Idaho to estimate deep reservoir temperatures of 360, 240, and 142C,...

  18. ,"North Dakota Crude Oil Reserves in Nonproducing Reservoirs...

    U.S. Energy Information Administration (EIA) Indexed Site

    Of Series","Frequency","Latest Data for" ,"Data 1","North Dakota Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)",1,"Annual",2014 ,"Release...

  19. ,"West Virginia Crude Oil Reserves in Nonproducing Reservoirs...

    U.S. Energy Information Administration (EIA) Indexed Site

    Of Series","Frequency","Latest Data for" ,"Data 1","West Virginia Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)",1,"Annual",2014 ,"Release...

  20. Twentieth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    1995-01-26

    PREFACE The Twentieth Workshop on Geothermal Reservoir Engineering, dedicated to the memory of Professor Hank Ramey, was held at Stanford University on January 24-26, 1995. There were ninety-five registered participants. Participants came from six foreign countries: Japan, Mexico, England, Italy, New Zealand and Iceland. The performance of many geothermal reservoirs outside the United States was described in several of the papers. Professor Roland N. Horne opened the meeting and welcomed visitors to the campus. The key note speaker was Marshall Reed, who gave a brief overview of the Department of Energy's current plan. Thirty-two papers were presented in the technical sessions of the workshop. Technical papers were organized into eleven sessions concerning: field development, modeling, well tesubore, injection, geoscience, geochemistry and field operations. Session chairmen were major contributors to the workshop, and we thank: Ben Barker, Bob Fournier, Mark Walters, John Counsil, Marcelo Lippmann, Keshav Goyal, Joel Renner and Mike Shook. In addition to the technical sessions, a panel discussion was held on ''What have we learned in 20 years?'' Panel speakers included Patrick Muffler, George Frye, Alfred Truesdell and John Pritchett. The subject was further discussed by Subir Sanyal, who gave the post-dinner speech at the banquet. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank our students who operated the audiovisual equipment. Shaun D. Fitzgerald Program Manager

  1. INNOVATIVE MIOR PROCESS UTILIZING INDIGENOUS RESERVOIR CONSTITUENTS

    SciTech Connect (OSTI)

    D.O. Hitzman; A.K. Stepp; D.M. Dennis; L.R. Graumann

    2003-09-01

    This research program was directed at improving the knowledge of reservoir ecology and developing practical microbial solutions and technologies for improving oil production. The goal was to identify and utilize indigenous microbial populations which can produce beneficial metabolic products and develop a methodology to stimulate those select microbes with nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents. Experimental laboratory work in model sandpack cores was conducted using microbial cultures isolated from produced water samples. Comparative laboratory studies demonstrating in situ production of microbial products as oil recovery agents were conducted in sand packs with natural field waters using cultures and conditions representative of oil reservoirs. Increased oil recovery in multiple model sandpack systems was achieved and the technology and results were verified by successful field studies. Direct application of the research results has lead to the development of a feasible, practical, successful, and cost-effective technology which increases oil recovery. This technology is now being commercialized and applied in numerous field projects to increase oil recovery. Two field applications of the developed technology reported production increases of 21% and 24% in oil recovery.

  2. AveCryostatTemp.key

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    #$ 280#$ 260#$ 240#$ 220#$ 200#$ 180#$ 160#$ 140#$ 120#$ 100# Temperature$[Kelvin] Time$(5/20/2015$to$6/17/2015) Average$Cryostat$Temperature

  3. Intrinsic Bioprobes, Inc. (Tempe, AZ)

    DOE Patents [OSTI]

    Nelson, Randall W. (Phoenix, AZ); Williams, Peter (Phoenix, AZ); Krone, Jennifer Reeve (Granbury, TX)

    2008-07-15

    Rapid mass spectrometric immunoassay methods for detecting and/or quantifying antibody and antigen analytes utilizing affinity capture to isolate the analytes and internal reference species (for quantification) followed by mass spectrometric analysis of the isolated analyte/internal reference species. Quantification is obtained by normalizing and calibrating obtained mass spectrum against the mass spectrum obtained for an antibody/antigen of known concentration.

  4. Sixth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.

    1980-12-18

    INTRODUCTION TO THE PROCEEDINGS OF THE SIXTH GEOTHERMAL RESERVOIR ENGINEERING WORKSHOP, STANFORD GEOTHERMAL PROGRAM Henry J. Ramey, Jr., and Paul Kruger Co-Principal Investigators Ian G. Donaldson Program Manager Stanford Geothermal Program The Sixth Workshop on Geothermal Reservoir Engineering convened at Stanford University on December 16, 1980. As with previous Workshops the attendance was around 100 with a significant participation from countries other than the United States (18 attendees from 6 countries). In addition, there were a number of papers from foreign contributors not able to attend. Because of the success of all the earlier workshops there was only one format change, a new scheduling of Tuesday to Thursday rather than the earlier Wednesday through Friday. This change was in general considered for the better and will be retained for the Seventh Workshop. Papers were presented on two and a half of the three days, the panel session, this year on the numerical modeling intercomparison study sponsored by the Department of Energy, being held on the second afternoon. This panel discussion is described in a separate Stanford Geothermal Program Report (SGP-TR42). This year there was a shift in subject of the papers. There was a reduction in the number of papers offered on pressure transients and well testing and an introduction of several new subjects. After overviews by Bob Gray of the Department of Energy and Jack Howard of Lawrence Berkeley Laboratory, we had papers on field development, geopressured systems, production engineering, well testing, modeling, reservoir physics, reservoir chemistry, and risk analysis. A total of 51 papers were contributed and are printed in these Proceedings. It was, however, necessary to restrict the presentations and not all papers printed were presented. Although the content of the Workshop has changed over the years, the format to date has proved to be satisfactory. The objectives of the Workshop, the bringing together of researchers, engineers and managers involved in geothermal reservoir study and development and the provision of a forum for the prompt and open reporting of progress and for the exchange of ideas, continue to be met . Active discussion by the majority of the participants is apparent both in and outside the workshop arena. The Workshop Proceedings now contain some of the most highly cited geothermal literature. Unfortunately, the popularity of the Workshop for the presentation and exchange of ideas does have some less welcome side effects. The major one is the developing necessity for a limitation of the number of papers that are actually presented. We will continue to include all offered papers in the Summaries and Proceedings. As in the recent past, this sixth Workshop was supported by a grant from the Department of Energy. This grant is now made directly to Stanford as part of the support for the Stanford Geothermal Program (Contract No. DE-AT03-80SF11459). We are certain that all participants join us in our appreciation of this continuing support. Thanks are also due to all those individuals who helped in so many ways: The members of the program committee who had to work so hard to keep the program to a manageable size - George Frye (Aminoil USA), Paul G. Atkinson (Union Oil Company). Michael L. Sorey (U.S.G.S.), Frank G. Miller (Stanford Geothermal Program), and Roland N. Horne (Stanford Geothermal Program). The session chairmen who contributed so much to the organization and operation of the technical sessions - George Frye (Aminoil USA), Phillip H. Messer (Union Oil Company), Leland L. Mink (Department of Energy), Manuel Nathenson (U.S.G.S.), Gunnar Bodvarsson (Oregon State University), Mohindar S. Gulati (Union Oil Company), George F. Pinder (Princeton University), Paul A. Witherspoon (Lawrence Berkeley Laboratory), Frank G. Miller (Stanford Geothermal Program) and Michael J. O'Sullivan (Lawrence Berkeley Laboratory). The many people who assisted behind the scenes, making sure that everything was prepared and organized - in particular we would like to t

  5. Potosi Reservoir Modeling; History and Recommendations

    SciTech Connect (OSTI)

    Smith, Valerie; Leetaru, Hannes

    2014-09-30

    As a part of a larger project co-funded by the United States Department of Energy (US DOE) to evaluate the potential of formations within the Cambro-Ordovician strata above the Mt. Simon as potential targets for carbon sequestration in the Illinois and Michigan Basins, the Illinois Clean Coal Institute (ICCI) requested Schlumberger to evaluate the potential injectivity and carbon dioxide (CO₂) plume size of the Cambrian Potosi Formation. The evaluation of this formation was accomplished using wireline data, core data, pressure data, and seismic data from two projects: the US DOE-funded Illinois Basin–Decatur Project being conducted by the Midwest Geological Sequestration Consortium in Macon County, Illinois, as well as data from the Illinois – Industrial Carbon Capture and Sequestration (IL-ICCS) project funded through the American Recovery and Reinvestment Act. In 2010, technical performance evaluations on the Cambrian Potosi Formation were performed through reservoir modeling. The data included formation tops from mud logs, well logs from the Verification Well 1 (VW1) and the Injection Well (CCS1), structural and stratigraphic formation from three dimensional (3D) seismic data, and field data from several waste water injection wells for the Potosi Formation. The intention was for two million tonnes per annum (MTPA) of CO₂ to be injected for 20 years into the Potosi Formation. In 2013, updated reservoir models for the Cambrian Potosi Formation were evaluated. The data included formation tops from mud logs, well logs from the CCS1, VW1, and Verification Well 2 (VW2) wells, structural and stratigraphic formation from a larger 3D seismic survey, and field data from several waste water injection wells for Potosi Formation. The objective is to simulate the injection of CO₂ at a rate 3.5 million tons per annum (3.2 million tonnes per annum [MTPA]) for 30 years 106 million tons (96 MT total) into the Potosi Formation. The Potosi geomodeling efforts have evolved from using data from a single well in 2010 to the inclusion of data from three wells in 2013 which largely leverage the porosity and permeability logs plus knowledge of lost circulation zones. The first Potosi model (Potosi Geobody Model 2010) attempted to use the available seismic inversion data to inform the geomodel and predict vugular zones in advance of drilling VW1. Lost circulation zones in VW1 came in as the geologists predicted. The model was not implemented in subsequent simulation work. To date, reservoir models used for flow simulation work have relied predominately on Gaussian distributed properties (porosity and permeability) and have employed a single injection well. Potosi Model 2013b incorporated the new VW2 logs, and exhibited an extra level of sophistication by delineating the vugular intervals. This method added further realism that likely represents the best reservoir approximation to date. Where the 2010 reservoir models were 10 by 10 mi (16 by 16 km) in area, the 2013 models were expanded in size to 30 by 30 mi (48 by 48 km). The latest reservoir simulations show that a minimum of four injectors might be required to meet target injection rates. Still, there is data that requires further scrutiny and modeling methodologies that require testing for the Potosi Formation. This work is currently ongoing, and the next phase of the reservoir modeling intends to implement valuable data like porosity derived from seismic inversion, seismically derived geobodies, or a combination of both to further define vugular zones and the porosity distribution within the Potosi Formation. Understanding the dual porosity, dual permeability character of the Potosi remains the greatest challenge in representing this formation. Further analysis of the FMI* fullbore formation microimager data may aid in assessing this uncertainty. The Potosi Formation is indeed an interesting formation, and recommendations to further characterize it are included in the following list: - Data acquisition to identify the vugs permeability, distribution, and interconnectivity could be considered to perform a more rigorous evaluation of the Potosi Formation injectivity and capacity. This could be achieved by performing an injection test on a vugular interval to determine the vugs permeability, and an interference test between wells to evaluate the local vugs extent and interconnectivity. - A thorough study of the available FMI data may reveal specifics on estimating the vug to matrix ratio. This estimate could be used to further condition the porosity distribution. Porosity logs alone might underestimate the formation’s porosity associated with vugs. Porosity mapping derived from the seismic inversion could also be used in the succeeding task to characterize the lateral porosity distribution within the reservoir. This could involve the geobody methodology previously attempted in 2010. With or without seismic inversion porosity mapping, it is worth exploring whether increased lateral heterogeneity plays a significant role in Potosi injectivity. Investigations on vugular, dolomitic outcrops suggest that there may be significantly greater lateral heterogeneity than what has been modeled here. - The FMI data also reveals the presence of and helps describe open fractures. The presence of fractures will further enhance the formation’s permeability. The task of leveraging this data in the geomodeling effort still remains. Under the best of circumstances, this data describing open fractures may be combined with seismic attributes to delineate fracture corridors. Fracture modeling would certainly add another layer of sophistication to the model. Its contribution and applicability remain to be explored. - Facies modeling within the Potosi has yet to be thoroughly addressed. The carbonates during the time of deposition are believed to be regionally extensive. However, it may be worth delineating the reservoir with other regional wells or modern day analogues to understand the extent of the Potosi. More specifically, the model could incorporate lateral changes or trends if deemed necessary to represent facies transition. - Currently there is no fracture gradient data available for the Potosi in the Decatur project area. The acquisition of the fracture pressure data could be considered to determine an appropriate maximum allowable bottomhole injection pressure. This would allow the evaluation of injectivity and the required number of wells in a more precise manner. - Special core analysis (SCAL) to determine the relative permeability and capillary pressure of the vugs and matrix could be considered to have a better estimation of the reservoir injectivity and plume extent. - Formation water sampling and analysis could be considered for the Potosi to estimate the water salinity and properties. A vertical flow performance evaluation could be considered for the succeeding task to determine the appropriate tubing size, the required injection tubing head pressure, and to investigate whether the corresponding well injection rate falls within the tubing erosional velocity limit. - A simulation using several injectors could also be considered to determine the required number of wells to achieve the injection target while taking into account the pressure interference.

  6. Reservoir technology - geothermal reservoir engineering research at Stanford. Fifth annual report, October 1, 1984-September 30, 1985

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Miller, F.G.; Brigham, W.E.

    1985-09-01

    The objective is to carry out research on geothermal reservoir engineering techniques useful to the geothermal industry. A parallel objective is the training of geothermal engineers and scientists. The research is focused toward accelerated development of hydrothermal resources through the evaluation of fluid reserves, and the forecasting of field behavior with time. Injection technology is a research area receiving special attention. The program is divided into reservoir definition research, modeling of heat extraction from fractured reservoirs, application and testing of new and proven reservoir engineering technology, and technology transfer. (ACR)

  7. Ninth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Gudmundsson, J.S.

    1983-12-15

    The attendance at the Workshop was similar to last year's with 123 registered participants of which 22 represented 8 foreign countries. A record number of technical papers (about 60) were submitted for presentation at the Workshop. The Program Committee, therefore, decided to have several parallel sessions to accommodate most of the papers. This format proved unpopular and will not be repeated. Many of the participants felt that the Workshop lost some of its unique qualities by having parallel sessions. The Workshop has always been held near the middle of December during examination week at Stanford. This timing was reviewed in an open discussion at the Workshop. The Program Committee subsequently decided to move the Workshop to January. The Tenth Workshop will be held on January 22-24, 1985. The theme of the Workshop this year was ''field developments worldwide''. The Program Committee addressed this theme by encouraging participants to submit field development papers, and by inviting several international authorities to give presentations at the Workshop. Field developments in at least twelve countries were reported: China, El Salvador, France, Greece, Iceland, Italy, Japan, Kenya, Mexico, New Zealand, the Philippines, and the United States. There were 58 technical presentations at the Workshop, of which 4 were not made available for publication. Several authors submitted papers not presented at the Workshop. However, these are included in the 60 papers of these Proceedings. The introductory address was given by Ron Toms of the U.S. Department of Energy, and the banquet speaker was A1 Cooper of Chevron Resources Company. An important contribution was made to the Workshop by the chairmen of the technical sessions. Other than Stanford Geothermal Program faculty members, they included: Don White (Field Developments), Bill D'Olier (Hydrothermal Systems), Herman Dykstra (Well Testing), Karsten Pruess (Well Testing), John Counsil (Reservoir Chemistry), Malcolm Mossman (Reservoir Chemistry), Greg Raasch (Production), Manny Nathenson (Injection), Susan Petty (Injection), Subir Sanyal (Simulation), Marty Molloy (Petrothermal), and Allen Moench (Reservoir Physics). The Workshop was organized by the Stanford Geothermal Program faculty, staff and students. We would like to thank Jean Cook, Joanne Hartford, Terri Ramey, Amy Osugi, and Marilyn King for their valued help with the Workshop arrangements and the Proceedings. We also owe thanks to the program students who arranged and operated the audio-visual equipment. The Ninth Workshop was supported by the Geothermal and Hydropower Technologies Division of the U . S . Department of Energy through contract DE-AT03-80SF11459. We deeply appreciate this continued support. H. J. Ramey, Jr., R. N. Horne, P. Kruger, W. E. Brigham, F. G. Miller, J. S . Gudmundsson -vii

  8. Aligned vertical fractures, HTI reservoir symmetry, and Thomsenseismic anisotropy parameters

    SciTech Connect (OSTI)

    Berryman, James G.

    2007-06-27

    The Sayers and Kachanov (1991) crack-influence parametersare shown to be directly related to Thomsen (1986) weak-anisotropyseismic parameters for fractured reservoirs when the crack density issmall enough. These results are then applied to seismic wave propagationin reservoirs having HTI symmetry due to aligned vertical fractures. Theapproach suggests a method of inverting for fracture density from wavespeed data.

  9. Gypsy Field project in reservoir characterization

    SciTech Connect (OSTI)

    Castagna, John P.; Jr., O'Meara, Daniel J.

    2000-01-12

    The overall objective of this project was to use extensive Gypsy Field Laboratory and data as a focus for developing and testing reservoir characterization methods that are targeted at improved recovery of conventional oil. This report describes progress since project report DOE/BC/14970-7 and covers the period June 1997-September 1998 and represents one year of funding originally allocated for the year 1996. During the course of the work previously performed, high resolution geophysical and outcrop data revealed the importance of fractures at the Gypsy site. In addition, personnel changes and alternative funding (OCAST and oil company support of various kinds) allowed the authors to leverage DOE contributions and focus more on geophysical characterization.

  10. PROCEEDINGS SECOND WORKSHOP GEOTHERMAL RESERVOIR ENGINEERING

    Office of Scientific and Technical Information (OSTI)

    SECOND WORKSHOP GEOTHERMAL RESERVOIR ENGINEERING December 1-3,1976 TABLE O F CONTENTS . I Page . - - I n t r o d u c t i o n - H. J . Ramey, Jr. . . . . . . . . . . . . . . . . . . . . . . Ove r v i ews Geo t he rma F. G. Geot herma Geotherma v. w. R e s e r v o i r Eng R e s e r v o i r Eng R e s e r v o i r Eng M i l l e r . . R o b e r t s . . . n e e r i n g Research - H. J. Ramey, J r . , and . . . . . . . . . . . . . . . . . . . . . . . . . n e e r i n g i n I n d u s t r y - S. C . Lipman

  11. CALIBRATION OF SEISMIC ATTRIBUTES FOR RESERVOIR CHARACTERIZATION

    SciTech Connect (OSTI)

    Wayne D. Pennington; Horacio Acevedo; Aaron Green; Joshua Haataja; Shawn Len; Anastasia Minaeva; Deyi Xie

    2002-10-01

    The project, ''Calibration of Seismic Attributes for Reservoir Calibration,'' is now complete. Our original proposed scope of work included detailed analysis of seismic and other data from two to three hydrocarbon fields; we have analyzed data from four fields at this level of detail, two additional fields with less detail, and one other 2D seismic line used for experimentation. We also included time-lapse seismic data with ocean-bottom cable recordings in addition to the originally proposed static field data. A large number of publications and presentations have resulted from this work, including several that are in final stages of preparation or printing; one of these is a chapter on ''Reservoir Geophysics'' for the new Petroleum Engineering Handbook from the Society of Petroleum Engineers. Major results from this project include a new approach to evaluating seismic attributes in time-lapse monitoring studies, evaluation of pitfalls in the use of point-based measurements and facies classifications, novel applications of inversion results, improved methods of tying seismic data to the wellbore, and a comparison of methods used to detect pressure compartments. Some of the data sets used are in the public domain, allowing other investigators to test our techniques or to improve upon them using the same data. From the public-domain Stratton data set we have demonstrated that an apparent correlation between attributes derived along ''phantom'' horizons are artifacts of isopach changes; only if the interpreter understands that the interpretation is based on this correlation with bed thickening or thinning, can reliable interpretations of channel horizons and facies be made. From the public-domain Boonsville data set we developed techniques to use conventional seismic attributes, including seismic facies generated under various neural network procedures, to subdivide regional facies determined from logs into productive and non-productive subfacies, and we developed a method involving cross-correlation of seismic waveforms to provide a reliable map of the various facies present in the area. The Wamsutter data set led to the use of unconventional attributes including lateral incoherence and horizon-dependent impedance variations to indicate regions of former sand bars and current high pressure, respectively, and to evaluation of various upscaling routines. The Teal South data set has provided a surprising set of results, leading us to develop a pressure-dependent velocity relationship and to conclude that nearby reservoirs are undergoing a pressure drop in response to the production of the main reservoir, implying that oil is being lost through their spill points, never to be produced. Additional results were found using the public-domain Waha and Woresham-Bayer data set, and some tests of technologies were made using 2D seismic lines from Michigan and the western Pacific ocean.

  12. Calibration of Seismic Attributes for Reservoir Characterization

    SciTech Connect (OSTI)

    Wayne D. Pennington

    2002-09-29

    The project, "Calibration of Seismic Attributes for Reservoir Characterization," is now complete. Our original proposed scope of work included detailed analysis of seismic and other data from two to three hydrocarbon fields; we have analyzed data from four fields at this level of detail, two additional fields with less detail, and one other 2D seismic line used for experimentation. We also included time-lapse seismic data with ocean-bottom cable recordings in addition to the originally proposed static field data. A large number of publications and presentations have resulted from this work, inlcuding several that are in final stages of preparation or printing; one of these is a chapter on "Reservoir Geophysics" for the new Petroleum Engineering Handbook from the Society of Petroleum Engineers. Major results from this project include a new approach to evaluating seismic attributes in time-lapse monitoring studies, evaluation of pitfalls in the use of point-based measurements and facies classifications, novel applications of inversion results, improved methods of tying seismic data to the wellbore, and a comparison of methods used to detect pressure compartments. Some of the data sets used are in the public domain, allowing other investigators to test our techniques or to improve upon them using the same data. From the public-domain Stratton data set we have demonstrated that an apparent correlation between attributes derived along 'phantom' horizons are artifacts of isopach changes; only if the interpreter understands that the interpretation is based on this correlation with bed thickening or thinning, can reliable interpretations of channel horizons and facies be made. From the public-domain Boonsville data set we developed techniques to use conventional seismic attributes, including seismic facies generated under various neural network procedures, to subdivide regional facies determined from logs into productive and non-productive subfacies, and we developed a method involving cross-correlation of seismic waveforms to provide a reliable map of the various facies present in the area. The Wamsutter data set led to the use of unconventional attributes including lateral incoherence and horizon-dependent impedance variations to indicate regions of former sand bars and current high pressure, respectively, and to evaluation of various upscaling routines. The Teal South data set has provided a surprising set of results, leading us to develop a pressure-dependent velocity relationship and to conclude that nearby reservoirs are undergoing a pressure drop in response to the production of the main reservoir, implying that oil is being lost through their spill points, never to be produced. Additional results were found using the public-domain Waha and Woresham-Bayer data set, and some tests of technologies were made using 2D seismic lines from Michigan and the western Pacific ocean.

  13. High resolution reservoir geological modelling using outcrop information

    SciTech Connect (OSTI)

    Zhang Changmin; Lin Kexiang; Liu Huaibo

    1997-08-01

    This is China`s first case study of high resolution reservoir geological modelling using outcrop information. The key of the modelling process is to build a prototype model and using the model as a geological knowledge bank. Outcrop information used in geological modelling including seven aspects: (1) Determining the reservoir framework pattern by sedimentary depositional system and facies analysis; (2) Horizontal correlation based on the lower and higher stand duration of the paleo-lake level; (3) Determining the model`s direction based on the paleocurrent statistics; (4) Estimating the sandbody communication by photomosaic and profiles; (6) Estimating reservoir properties distribution within sandbody by lithofacies analysis; and (7) Building the reservoir model in sandbody scale by architectural element analysis and 3-D sampling. A high resolution reservoir geological model of Youshashan oil field has been built by using this method.

  14. Transient well testing in two-phase geothermal reservoirs

    SciTech Connect (OSTI)

    Aydelotte, S.R.

    1980-03-01

    A study of well test analysis techniques in two-phase geothermal reservoirs has been conducted using a three-dimensional, two-phase, wellbore and reservoir simulation model. Well tests from Cerro Prieto and the Hawaiian Geothermal project have been history matched. Using these well tests as a base, the influence of reservoir permeability, porosity, thickness, and heat capacity, along with flow rate and fracturing were studied. Single and two-phase transient well test equations were used to analyze these tests with poor results due to rapidly changing fluid properties and inability to calculate the flowing steam saturation in the reservoir. The injection of cold water into the reservoir does give good data from which formation properties can be calculated.

  15. Chickamauga Reservoir 1992 fisheries monitoring cove rotenone results

    SciTech Connect (OSTI)

    Kerley, B.L.

    1993-06-01

    The Tennessee Valley Authority (TVA) is required by the National Pollutant Discharge Elimination System (NPDES) Permit for Sequoyah Nuclear Plant (SQN) to conduct and report annually a nonradiological operational monitoring program to evaluate potential effects of SQN on Chickamauga Reservoir. This monitoring program was initially designed to identify potential changes in water quality and biological communities in Chickamauga Reservoir resulting from operation of SQU. Chickamauga Reservoir cove rotenone sampling has also been conducted as part of the preoperational monitoring program for Watts Bar Nuclear Plant (WBN) to evaluate the combined effects of operating two nuclear facilities on one reservoir once WBU becomes operational. The purpose of this report is to present results of cove rotenone sampling conducted on Chickamauga Reservoir in 1992.

  16. Opportunities to improve oil productivity in unstructured deltaic reservoirs

    SciTech Connect (OSTI)

    Not Available

    1991-01-01

    This report contains presentations presented at a technical symposium on oil production. Chapter 1 contains summaries of the presentations given at the Department of Energy (DOE)-sponsored symposium and key points of the discussions that followed. Chapter 2 characterizes the light oil resource from fluvial-dominated deltaic reservoirs in the Tertiary Oil Recovery Information System (TORIS). An analysis of enhanced oil recovery (EOR) and advanced secondary recovery (ASR) potential for fluvial-dominated deltaic reservoirs based on recovery performance and economic modeling as well as the potential resource loss due to well abandonments is presented. Chapter 3 provides a summary of the general reservoir characteristics and properties within deltaic deposits. It is not exhaustive treatise, rather it is intended to provide some basic information about geologic, reservoir, and production characteristics of deltaic reservoirs, and the resulting recovery problems.

  17. Eighteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Horne, R.J.; Kruger, P.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

    1993-01-28

    PREFACE The Eighteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 26-28, 1993. There were one hundred and seventeen registered participants which was greater than the attendance last year. Participants were from eight foreign countries: Italy, Japan, United Kingdom, Mexico, New Zealand, the Philippines, Guatemala, and Iceland. Performance of many geothermal fields outside the United States was described in several of the papers. Dean Gary Ernst opened the meeting and welcomed the visitors to the campus. The key note speaker was J.E. ''Ted'' Mock who gave a brief overview of the Department of Energy's current plan. The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy was awarded to Dr. Mock who also spoke at the banquet. Thirty-nine papers were presented at the Workshop with two papers submitted for publication only. Technical papers were organized in twelve sessions concerning: field operations, The Geysers, geoscience, hot-dry-rock, injection, modeling, slim hole wells, geochemistry, well test and wellbore. Session chairmen were major contributors to the program and we thank: John Counsil, Kathleen Enedy, Harry Olson, Eduardo Iglesias, Marcelo Lippmann, Paul Atkinson, Jim Lovekin, Marshall Reed, Antonio Correa, and David Faulder. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate audiovisual equipment and to John Hornbrook who coordinated the meeting arrangements for the Workshop. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook

  18. Reviving Abandoned Reservoirs with High-Pressure Air Injection: Application in a Fractured and Karsted Dolomite Reservoir

    SciTech Connect (OSTI)

    Robert Loucks; Stephen C. Ruppel; Dembla Dhiraj; Julia Gale; Jon Holder; Jeff Kane; Jon Olson; John A. Jackson; Katherine G. Jackson

    2006-09-30

    Despite declining production rates, existing reservoirs in the United States contain vast volumes of remaining oil that is not being effectively recovered. This oil resource constitutes a huge target for the development and application of modern, cost-effective technologies for producing oil. Chief among the barriers to the recovery of this oil are the high costs of designing and implementing conventional advanced recovery technologies in these mature, in many cases pressure-depleted, reservoirs. An additional, increasingly significant barrier is the lack of vital technical expertise necessary for the application of these technologies. This lack of expertise is especially notable among the small operators and independents that operate many of these mature, yet oil-rich, reservoirs. We addressed these barriers to more effective oil recovery by developing, testing, applying, and documenting an innovative technology that can be used by even the smallest operator to significantly increase the flow of oil from mature U.S. reservoirs. The Bureau of Economic Geology and Goldrus Producing Company assembled a multidisciplinary team of geoscientists and engineers to evaluate the applicability of high-pressure air injection (HPAI) in revitalizing a nearly abandoned carbonate reservoir in the Permian Basin of West Texas. The Permian Basin, the largest oil-bearing basin in North America, contains more than 70 billion barrels of remaining oil in place and is an ideal venue to validate this technology. We have demonstrated the potential of HPAI for oil-recovery improvement in preliminary laboratory tests and a reservoir pilot project. To more completely test the technology, this project emphasized detailed characterization of reservoir properties, which were integrated to access the effectiveness and economics of HPAI. The characterization phase of the project utilized geoscientists and petroleum engineers from the Bureau of Economic Geology and the Department of Petroleum Engineering (both at The University of Texas at Austin) to define the controls on fluid flow in the reservoir as a basis for developing a reservoir model. The successful development of HPAI technology has tremendous potential for increasing the flow of oil from deep carbonate reservoirs in the Permian Basin, a target resource that can be conservatively estimated at more than 1.5 billion barrels. Successful implementation in the field chosen for demonstration, for example, could result in the recovery of more than 34 million barrels of oil that will not otherwise be produced. Geological and petrophysical analysis of available data at Barnhart field reveals the following important observations: (1) the Barnhart Ellenburger reservoir is similar to most other Ellenburger reservoirs in terms of depositional facies, diagenesis, and petrophysical attributes; (2) the reservoir is characterized by low to moderate matrix porosity much like most other Ellenburger reservoirs in the Permian Basin; (3) karst processes (cave formation, infill, and collapse) have substantially altered stratigraphic architecture and reservoir properties; (4) porosity and permeability increase with depth and may be associated with the degree of karst-related diagenesis; (5) tectonic fractures overprint the reservoir, improving overall connectivity; (6) oil-saturation profiles show that the oil-water contact (OWC) is as much as 125 ft lower than previous estimations; (7) production history and trends suggest that this reservoir is very similar to other solution-gas-drive reservoirs in the Permian Basin; and (8) reservoir simulation study showed that the Barnhart reservoir is a good candidate for HPAI and that application of horizontal-well technology can improve ultimate resource recovery from the reservoir.

  19. Methods and systems using encapsulated tracers and chemicals for reservoir interrogation and manipulation

    DOE Patents [OSTI]

    Roberts, Jeffery; Aines, Roger D; Duoss, Eric B; Spadaccini, Christopher M

    2014-11-04

    An apparatus, method, and system of reservoir interrogation. A tracer is encapsulating in a receptacle. The receptacle containing the tracer is injected into the reservoir. The tracer is analyzed for reservoir interrogation.

  20. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Chris Phillips; Dan Moos; Don Clarke; John Nguyen; Kwasi Tagbor; Roy Koerner; Scott Walker

    1998-01-26

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period October - December 1997 and to report all technical data and findings as specified in the "Federal Assistance Reporting Checklist". The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology. The identification of the sands with high remaining oil saturation will be accomplished by developing a deterministic three dimensional (3-D) geologic model and by using a state of the art reservoir management computer software. The wells identified by the geologic and reservoir engineering work as having the best potential will be logged with cased-hole logging tools. The application of the logging tools will be optimized in the lab by developing a rock-log model. This rock-log model will allow us to translate measurements through casing into effective porosity and hydrocarbon saturation. The wells that are shown to have the best oil production potential will be recompleted. The recompletions will be optimized by evaluating short radius lateral recompletions as well as other recompletion techniques such as the sand consolidation through steam injection.

  1. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management.

    SciTech Connect (OSTI)

    Koerner, R.; Clarke, D.; Walker, S.; Phillips, C.; Nguyen, J.; Moos, D.; Tagbor, K.

    1997-10-21

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period July - September 1997 and to report all technical data and findings as specified in the `Federal Assistance Reporting Checklist`. The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology. The identification of the sands with high remaining oil saturation will be accomplished by developing a deterministic three dimensional (3-D) geologic model and by using a state of the art reservoir management computer software. The wells identified by the geologic and reservoir engineering work as having the best potential will be logged with a pulsed acoustic cased-hole logging tool. The application of the logging tools will be optimized in the lab by developing a rock-log model. This rock-log model will allow us to convert shear wave velocity measured through casing into effective porosity and hydrocarbon saturation. The wells that are shown to have the best oil production potential will be recompleted. The recompletions will be optimized by evaluating short radius and ultra-short radius lateral recompletions as well as other techniques.

  2. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Chris Phillips; Dan Moos; Don Clarke; John Nguyen; Kwasi Tagbor; Roy Koerner; Scott Walker.

    1998-01-26

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period October - December 1997 and to report all technical data and findings as specified in the Federal Assistance Reporting Checklist . The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology. The identification of the sands with high remaining oil saturation will be accomplished by developing a deterministic three dimensional (3-D) geologic model and by using a state of the art reservoir management computer software. The wells identified by the geologic and reservoir engineering work as having the best potential will be logged with cased-hole logging tools. The application of the logging tools will be optimized in the lab by developing a rock-log model. This rock-log model will allow us to translate measurements through casing into effective porosity and hydrocarbon saturation. The wells that are shown to have the best oil production potential will be recompleted. The recompletions will be optimized by evaluating short radius lateral recompletions as well as other recompletion techniques such as the sand consolidation through steam injection.

  3. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Chris Phillips; Dan Moos; Don Clarke; John Nguyen; Kwasi Tagbor; Roy Koerner; Scott Walker

    1998-04-22

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period January - March 1998 and to report all technical data and findings as specified in the "Federal Assistance Reporting Checklist". The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology. The identification of the sands with high remaining oil saturation will be accomplished by developing a deterministic three dimensional (3-D) geologic model and by using a state of the art reservoir management computer software. The wells identified by the geologic and reservoir engineering work as having the best potential will be logged with cased-hole logging tools. The application of the logging tools will be optimized in the lab by developing a rock-log model. This rock-log model will allow us to translate measurements through casing into effective porosity and hydrocarbon saturation. The wells that are shown to have the best oil production potential will be recompleted. The recompletions will be optimized by evaluating short radius lateral recompletions as well as other recompletion techniques such as the sand consolidation through steam injection.

  4. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management.

    SciTech Connect (OSTI)

    Koerner, Roy; Clarke, Don; Walker, Scott; Phillips, Chris; Nauyen, John; Moos, Dan; Tagbor, Kwasi

    1997-07-28

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period April - June 1997 and to report all technical data and findings as specified in the `Federal Assistance Reporting Checklist`. The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology. The identification of the sands with high remaining oil saturation will be accomplished by developing a deterministic three dimensional (3-D) geologic model and by using a state of the art reservoir management computer software. The wells identified by the geologic and reservoir engineering work as having the best potential will be logged with a pulsed acoustic cased-hole logging tool. The application of the logging tools will be optimized in the lab by developing a rock-log model. This rock-log model will allow us to convert shear wave velocity measured through casing into effective porosity and hydrocarbon saturation. The wells that are shown to have the best oil production potential will be recompleted. The recompletions will be optimized by evaluating short radius and ultra-short radius lateral recompletions as well as other techniques.

  5. Spectral SP: A New Approach to Mapping Reservoir Flow and Permeability...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Reservoir Flow and Permeability Spectral SP: A New Approach to Mapping Reservoir Flow and Permeability presentation at the April 2013 peer review meeting held in Denver, Colorado. ...

  6. Texas--RRC District 10 Crude Oil Reserves in Nonproducing Reservoirs...

    Gasoline and Diesel Fuel Update (EIA)

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 10 Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  7. Texas--RRC District 1 Crude Oil Reserves in Nonproducing Reservoirs...

    Gasoline and Diesel Fuel Update (EIA)

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 1 Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  8. Texas--RRC District 6 Crude Oil Reserves in Nonproducing Reservoirs...

    Gasoline and Diesel Fuel Update (EIA)

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 6 Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  9. Texas--RRC District 5 Crude Oil Reserves in Nonproducing Reservoirs...

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 5 Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  10. Texas--RRC District 9 Crude Oil Reserves in Nonproducing Reservoirs...

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 9 Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  11. Texas--RRC District 8 Crude Oil Reserves in Nonproducing Reservoirs...

    Gasoline and Diesel Fuel Update (EIA)

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 8 Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  12. Novel use of 4D Monitoring Techniques to Improve Reservoir Longevity...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    use of 4D Monitoring Techniques to Improve Reservoir Longevity and Productivity in Enhanced Geothermal Systems Novel use of 4D Monitoring Techniques to Improve Reservoir Longevity ...

  13. Putting integrated reservoir characterization into practice - in house training

    SciTech Connect (OSTI)

    Wright, F.M. Jr.; Best, D.A.; Clarke, R.T.

    1997-08-01

    The need for even more efficient reservoir characterization and management has forced a change in the way Mobil Oil provides technical support to its production operations. We`ve learned that to be successful, a good understanding of the reservoir is essential. This includes an understanding of the technical and business significance of reservoir heterogeneities at different stages of field development. A multi-disciplinary understanding of the business of integrated reservoir characterization is essential and to facilitate this understanding, Mobil has developed a highly successful {open_quotes}Reservoir Characterization Field Seminar{close_quotes}. Through specific team based case studies that incorporate outcrop examples and data the program provides participants the opportunity to explore historic and alternative approaches to reservoir description, characterization and management. We explore appropriate levels and timing of data gathering, technology applications, risk assessment and management practices at different stages of field development. The case studies presented throughout the course are a unique element of the program which combine real life and hypothetical problem sets that explore how different technical disciplines interact, the approaches to a problem solving they use, the assumptions and uncertainties contained in their contributions and the impact those conclusions may have on other disciplines involved in the overall reservoir management process. The team building aspect of the course was an added bonus.

  14. Nineteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Horne, R.J.; Kruger, P.; Miller, F.G.; Brigham, W.E.; Cook, J.W.

    1994-01-20

    PREFACE The Nineteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 18-20, 1994. This workshop opened on a sad note because of the death of Prof. Henry J. Ramey, Jr. on November 19, 1993. Hank had been fighting leukemia for a long time and finally lost the battle. Many of the workshop participants were present for the celebration of his life on January 21 at Stanford's Memorial Church. Hank was one of the founders of the Stanford Geothermal Program and the Geothermal Reservoir Engineering Workshop. His energy, kindness, quick wit, and knowledge will long be missed at future workshops. Following the Preface we have included a copy of the Memorial Resolution passed by the Stanford University Senate. There were one hundred and four registered participants. Participants were from ten foreign countries: Costa Rica, England, Iceland, Italy, Japan, Kenya, Mexico, New Zealand, Philippines and Turkey. Workshop papers described the performance of fourteen geothermal fields outside the United States. Roland N. Home opened the meeting and welcomed the visitors to the campus. The key note speaker was J.E. ''Ted'' Mock who gave a presentation about the future of geothermal development. The banquet speaker was Jesus Rivera and he spoke about Energy Sources of Central American Countries. Forty two papers were presented at the Workshop. Technical papers were organized in twelve sessions concerning: sciences, injection, production, modeling, and adsorption. Session chairmen are an important part of the workshop and our thanks go to: John Counsil, Mark Walters, Dave Duchane, David Faulder, Gudmundur Bodvarsson, Jim Lovekin, Joel Renner, and Iraj Ershaghi. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate audiovisual equipment and to Xianfa Deng who coordinated the meeting arrangements for the Workshop. Roland N. Home Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook

  15. Sixteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Cook, J.W.

    1991-01-25

    The Sixteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 23-25, 1991. The Workshop Banquet Speaker was Dr. Mohinder Gulati of UNOCAL Geothermal. Dr. Gulati gave an inspiring talk on the impact of numerical simulation on development of geothermal energy both in The Geysers and the Philippines. Dr. Gulati was the first recipient of The Stanford Geothermal Program Reservoir Engineering Award for Excellence in Development of Geothermal Energy. Dr. Frank Miller presented the award. The registered attendance figure of one hundred fifteen participants was up slightly from last year. There were seven foreign countries represented: Iceland, Italy, Philippines, Kenya, the United Kingdom, Mexico, and Japan. As last year, papers on about a dozen geothermal fields outside the United States were presented. There were thirty-six papers presented at the Workshop, and two papers were submitted for publication only. Attendees were welcomed by Dr. Khalid Aziz, Chairman of the Petroleum Engineering Department at Stanford. Opening remarks were presented by Dr. Roland Horne, followed by a discussion of the California Energy Commission's Geothermal Activities by Barbara Crowley, Vice Chairman; and J.E. ''Ted'' Mock's presentation of the DOE Geothermal Program: New Emphasis on Industrial Participation. Technical papers were organized in twelve sessions concerning: hot dry rock, geochemistry, tracer injection, field performance, modeling, and chemistry/gas. As in previous workshops, session chairpersons made major contributions to the program. Special thanks are due to Joel Renner, Jeff Tester, Jim Combs, Kathy Enedy, Elwood Baldwin, Sabodh Garg, Marcel0 Lippman, John Counsil, and Eduardo Iglesias. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and graduate students. We wish to thank Pat Ota, Angharad Jones, Rosalee Benelli, Jeanne Mankinen, Ted Sumida, and Terri A. Ramey who also produces the Proceedings Volumes for publication. We owe a great deal of thanks to our students who operate the audiovisual equipment and to Michael Riley who coordinated the meeting arrangements for a second year. Henry J. Ramey, Jr. Roland N. Horne Frank G. Miller Paul Kruger William E. Brigham Jean W. Cook

  16. Computed microtomography of reservoir core samples

    SciTech Connect (OSTI)

    Coles, M.E.; Muegge, E.L.; Spanne, P.; Jones, K.W.

    1995-03-01

    X-ray computed tomography (CT) is often utilized to evaluate and characterize structural characteristics within reservoir core material systems. Generally, medical CT scanners have been employed because of their availability and ease of use. Of interest lately has been the acquisition of three-dimensional, high resolution descriptions of rock and pore structures for characterization of the porous media and for modeling of single and multiphase transport processes. The spatial resolution of current medical CT scanners is too coarse for pore level imaging of most core samples. Recently developed high resolution computed microtomography (CMT) using synchrotron X-ray sources is analogous to conventional medical CT scanning and provides the ability to obtain three-dimensional images of specimens with a spatial resolution on the order of micrometers. Application of this technique to the study of core samples provides two- and three-dimensional high resolution description of pore structure and mineral distributions. Pore space and interconnectivity is accurately characterized and visualized. Computed microtomography data can serve as input into pore-level simulation techniques. A generalized explanation of the technique is provided, with comparison to conventional CT scanning techniques and results. Computed microtomographic results of several sandstone samples are presented and discussed. Bulk porosity values and mineralogical identification were obtained from the microtomograms and compared with gas porosity and scanning electron microscope results on tandem samples.

  17. Increasing Waterflood Reserves in the Wilmington Oil Field Through Improved Reservoir Characterization and Reservoir Management

    SciTech Connect (OSTI)

    Chris Phillips; Dan Moos; Don Clarke; Dwasi Tagbor; John Nguygen; Roy Koerner; Scott Walker

    1997-04-10

    The objectives of this quarterly report are to summarize the work conducted under each task during the reporting period January - March 1997 and to report all technical data and findings as specified in the "Federal Assistance Reporting Checklist". The main objective of this project is the transfer of technologies, methodologies, and findings developed and applied in this project to other operators of Slope and Basin Clastic Reservoirs. This project will study methods to identify sands with high remaining oil saturation and to recomplete existing wells using advanced completion technology.

  18. Alaska Crude Oil + Lease Condensate New Reservoir Discoveries...

    U.S. Energy Information Administration (EIA) Indexed Site

    Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's...

  19. Integrated seismic studies at the Rye Patch geothermal reservoir...

    Open Energy Info (EERE)

    seismic studies at the Rye Patch geothermal reservoir Authors R. Gritto, T.M. Daley and E.L. Majer Published Journal Geothermal Resources Council Transactions, 2002 DOI Not...

  20. Fracture Evolution Following a Hydraulic Stimulation within an EGS Reservoir

    Broader source: Energy.gov [DOE]

    DOE Geothermal Peer Review 2010 - Presentation. This project will provide the first ever formal evaluation of fracture and fracture flow evolution in an EGS reservoir following a hydraulic stimulation.

  1. Heavy oil reservoirs recoverable by thermal technology. Annual report

    SciTech Connect (OSTI)

    Kujawa, P.

    1981-02-01

    This volume contains reservoir, production, and project data for target reservoirs thermally recoverable by steam drive which are equal to or greater than 2500 feet deep and contain heavy oil in the 8 to 25/sup 0/ API gravity range. Data were collected from three source types: hands-on (A), once-removed (B), and twice-removed (C). In all cases, data were sought depicting and characterizing individual reservoirs as opposed to data covering an entire field with more than one producing interval or reservoir. The data sources are listed at the end of each case. This volume also contains a complete listing of operators and projects, as well as a bibliography of source material.

  2. Discrete Feature Approach for Heterogeneous Reservoir Production Enhancement

    SciTech Connect (OSTI)

    Dershowitz, William S.; Curran, Brendan; Einstein, Herbert; LaPointe, Paul; Shuttle, Dawn; Klise, Kate

    2002-07-26

    The report presents summaries of technology development for discrete feature modeling in support of the improved oil recovery (IOR) for heterogeneous reservoirs. In addition, the report describes the demonstration of these technologies at project study sites.

  3. FLUID STRATIGRAPHY OF THE COSO GEOTHERMAL RESERVOIR | Open Energy...

    Open Energy Info (EERE)

    cross-sections developed using this method. Authors Dilley, L.M.; Norman, D.I.; Moore, J.; McCullouch and J. Published PROCEEDINGS, Thirty-First Workshop on Geothermal Reservoir...

  4. Predicting Reservoir System Quality and Performance | Open Energy...

    Open Energy Info (EERE)

    to library Book Section: Predicting Reservoir System Quality and Performance Authors D.J. Hartmann and E.A. Beaumont Editors E.A. Beaumont and N.H. Foster Published AAPG...

  5. Borehole geophysics evaluation of the Raft River geothermal reservoir...

    Open Energy Info (EERE)

    sup 0C) reservoir was a zone of higher conductivity, increased porosity, decreased density, and lower sonic velocity. It was believed that the long term contact with the hot...

  6. Lithology and alteration mineralogy of reservoir rocks at Coso...

    Open Energy Info (EERE)

    using petrographic and analytical analyses of reservoir rock and vein material. The nature of the low-angle outflow zone and the overlying cap that prevents a surface expression...

  7. Lithology and Alteration Mineralogy of Reservoir Rocks at Coso...

    Open Energy Info (EERE)

    using petrographic and analytical analyses of reservoir rock and vein material. The nature of the low-angle outflow zone and the overlying cap that prevents a surface expression...

  8. Hydroacoustic Estimates of Fish Density Distributions in Cougar Reservoir, 2011

    SciTech Connect (OSTI)

    Ploskey, Gene R.; Zimmerman, Shon A.; Hennen, Matthew J.; Batten, George W.; Mitchell, T. D.

    2012-09-01

    Day and night mobile hydroacoustic surveys were conducted once each month from April through December 2011 to quantify the horizontal and vertical distributions of fish throughout Cougar Reservoir, Lane County, Oregon.

  9. FMI Borehole Geology, Geomechanics and 3D Reservoir Modeling...

    Open Energy Info (EERE)

    FMI Borehole Geology, Geomechanics and 3D Reservoir Modeling Jump to: navigation, search OpenEI Reference LibraryAdd to library Report: FMI Borehole Geology, Geomechanics and 3D...

  10. Exploration model for possible geothermal reservoir, Coso Hot...

    Open Energy Info (EERE)

    Abstract The purpose of this study was to test the hypothesis that a steam-filled fracture geothermal reservoir exists at Coso Hot Springs KGRA, as proposed by Combs and...

  11. Three-dimensional Modeling of Fracture Clusters in Geothermal Reservoirs

    Broader source: Energy.gov [DOE]

    Project objective: to develop a 3-D numerical model for simulating mode I; II; and III (tensile; shear; and tearing propagation of multiple fractures using the virtual multi-dimensional internal bond (VMIB); to predict geothermal reservoir stimulation.

  12. Collection and Analysis of Reservoir Data from Testing and Operation...

    Open Energy Info (EERE)

    Reservoir Data from Testing and Operation of the Raft River 5 MW Power Plant Jump to: navigation, search OpenEI Reference LibraryAdd to library Conference Proceedings: Collection...

  13. Analysis of Geothermal Reservoir Stimulation Using Geomechanics-based

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Stochastic Analysis of Injection-induced Seismicity; 2010 Geothermal Technology Program Peer Review Report | Department of Energy Analysis of Geothermal Reservoir Stimulation Using Geomechanics-based Stochastic Analysis of Injection-induced Seismicity; 2010 Geothermal Technology Program Peer Review Report Analysis of Geothermal Reservoir Stimulation Using Geomechanics-based Stochastic Analysis of Injection-induced Seismicity; 2010 Geothermal Technology Program Peer Review Report DOE 2010

  14. US production of natural gas from tight reservoirs

    SciTech Connect (OSTI)

    Not Available

    1993-10-18

    For the purposes of this report, tight gas reservoirs are defined as those that meet the Federal Energy Regulatory Commission`s (FERC) definition of tight. They are generally characterized by an average reservoir rock permeability to gas of 0.1 millidarcy or less and, absent artificial stimulation of production, by production rates that do not exceed 5 barrels of oil per day and certain specified daily volumes of gas which increase with the depth of the reservoir. All of the statistics presented in this report pertain to wells that have been classified, from 1978 through 1991, as tight according to the FERC; i.e., they are ``legally tight`` reservoirs. Additional production from ``geologically tight`` reservoirs that have not been classified tight according to the FERC rules has been excluded. This category includes all producing wells drilled into legally designated tight gas reservoirs prior to 1978 and all producing wells drilled into physically tight gas reservoirs that have not been designated legally tight. Therefore, all gas production referenced herein is eligible for the Section 29 tax credit. Although the qualification period for the credit expired at the end of 1992, wells that were spudded (began to be drilled) between 1978 and May 1988, and from November 5, 1990, through year end 1992, are eligible for the tax credit for a subsequent period of 10 years. This report updates the EIA`s tight gas production information through 1991 and considers further the history and effect on tight gas production of the Federal Government`s regulatory and tax policy actions. It also provides some high points of the geologic background needed to understand the nature and location of low-permeability reservoirs.

  15. Passive injection: A strategy for mitigating reservoir pressurization,

    Office of Scientific and Technical Information (OSTI)

    induced seismicity and brine migration in geologic CO2 storage (Journal Article) | SciTech Connect Journal Article: Passive injection: A strategy for mitigating reservoir pressurization, induced seismicity and brine migration in geologic CO2 storage Citation Details In-Document Search Title: Passive injection: A strategy for mitigating reservoir pressurization, induced seismicity and brine migration in geologic CO2 storage Authors: Dempsey, David ; Kelkar, Sharad ; Pawar, Rajesh Publication

  16. Heavy oil reservoirs recoverable by thermal technology. Annual report

    SciTech Connect (OSTI)

    Kujawa, P.

    1981-02-01

    The purpose of this study was to compile data on reservoirs that contain heavy oil in the 8 to 25/sup 0/ API gravity range, contain at least ten million barrels of oil currently in place, and are non-carbonate in lithology. The reservoirs within these constraints were then analyzed in light of applicable recovery technology, either steam-drive or in situ combustion, and then ranked hierarchically as candidate reservoirs. The study is presented in three volumes. Volume I presents the project background and approach, the screening analysis, ranking criteria, and listing of candidate reservoirs. The economic and environmental aspects of heavy oil recovery are included in appendices to this volume. This study provides an extensive basis for heavy oil development, but should be extended to include carbonate reservoirs and tar sands. It is imperative to look at heavy oil reservoirs and projects on an individual basis; it was discovered that operators, and industrial and government analysts will lump heavy oil reservoirs as poor producers, however, it was found that upon detailed analysis, a large number, so categorized, were producing very well. A study also should be conducted on abandoned reservoirs. To utilize heavy oil, refiners will have to add various unit operations to their processes, such as hydrotreaters and hydrodesulfurizers and will require, in most cases, a lighter blending stock. A big problem in producing heavy oil is that of regulation; specifically, it was found that the regulatory constraints are so fluid and changing that one cannot settle on a favorable recovery and production plan with enough confidence in the regulatory requirements to commit capital to the project.

  17. Deep Geothermal Reservoir Temperatures in the Eastern Snake River Plain,

    Office of Scientific and Technical Information (OSTI)

    Idaho using Multicomponent Geothermometry (Conference) | SciTech Connect Conference: Deep Geothermal Reservoir Temperatures in the Eastern Snake River Plain, Idaho using Multicomponent Geothermometry Citation Details In-Document Search Title: Deep Geothermal Reservoir Temperatures in the Eastern Snake River Plain, Idaho using Multicomponent Geothermometry The U.S. Geological survey has estimated that there are up to 4,900 MWe of undiscovered geothermal resources and 92,000 MWe of enhanced

  18. Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code

    Office of Scientific and Technical Information (OSTI)

    Comparison Study (Conference) | SciTech Connect Conference: Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code Comparison Study Citation Details In-Document Search Title: Flow and Thermal Behavior of an EGS Reservoir - Geothermal Code Comparison Study Authors: Kelkar, Sharad M. [1] ; Mclure, Mark [2] ; Ghassemi, Ahmad [3] + Show Author Affiliations Los Alamos National Laboratory University of Texas Austin University of Oklahoma Publication Date: 2015-01-26 OSTI Identifier:

  19. LANL researchers develop platform to study subsurface reservoir conditions

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Subsurface reservoir conditions LANL researchers develop platform to study subsurface reservoir conditions This increasing demand for energy around the globe requires a better understanding of subsurface energy resources and their associated environmental issues. March 7, 2016 Shown are time lapse images of supercritical CO2 displacing water in a fracture etched into a shale micromodel. The white, blue and gray colors represent supercritical CO2, water and shale, respectively. Shown are time

  20. Uncertainty quantification for evaluating impacts of caprock and reservoir

    Office of Scientific and Technical Information (OSTI)

    properties on pressure buildup and ground surface displacement during geological CO2 sequestration (Journal Article) | SciTech Connect Uncertainty quantification for evaluating impacts of caprock and reservoir properties on pressure buildup and ground surface displacement during geological CO2 sequestration Citation Details In-Document Search Title: Uncertainty quantification for evaluating impacts of caprock and reservoir properties on pressure buildup and ground surface displacement during

  1. Uncertainty quantification for evaluating impacts of caprock and reservoir

    Office of Scientific and Technical Information (OSTI)

    properties on pressure buildup and ground surface displacement during geological CO2 sequestration (Journal Article) | SciTech Connect quantification for evaluating impacts of caprock and reservoir properties on pressure buildup and ground surface displacement during geological CO2 sequestration Citation Details In-Document Search Title: Uncertainty quantification for evaluating impacts of caprock and reservoir properties on pressure buildup and ground surface displacement during geological

  2. DOE - Office of Legacy Management -- Pantex Sewage Reservoir - TX 03

    Office of Legacy Management (LM)

    Pantex Sewage Reservoir - TX 03 FUSRAP Considered Sites Site: Pantex Sewage Reservoir (TX.03 ) Designated Name: Alternate Name: Location: Evaluation Year: Site Operations: Site Disposition: Radioactive Materials Handled: Primary Radioactive Materials Handled: Radiological Survey(s): Site Status: This site is one of a group of 77 FUSRAP considered sites for which few, if any records are available in their respective site files to provide an historical account of past operations and their

  3. Haleakala Volcano Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  4. Kilauea Southwest Rift And South Flank Geothermal Area | Open...

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  5. Zim's Hot Springs Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  6. Rangely Oilfield Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  7. Marysville Mt Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  8. Wister Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  9. Lualualei Valley Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  10. Valley Of Ten Thousand Smokes Region Geothermal Area | Open Energy...

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  11. Hualalai Northwest Rift Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  12. Separation Creek Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  13. Unterhaching Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  14. Mauna Loa Northeast Rift Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  15. Kawaihae Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  16. Balcova Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  17. Upper Hot Creek Ranch Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  18. Lester Meadow Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  19. Seferihisar Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Volume: Mean Capacity: USGS Mean Reservoir Temp: USGS Estimated Reservoir Volume: USGS Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure...

  20. Shakes Springs Geothermal Area | Open Energy Information

    Open Energy Info (EERE)

    Region: Alaska Geothermal Region GEA Development Phase: Coordinates: 56.71765648, -132.0025034 Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean...

  1. Reservoir analysis of the Palinpinon geothermal field, Negros Oriental, Philippines

    SciTech Connect (OSTI)

    Amistoso, A.E.; Aquino, B.G.; Aunzo, Z.P.; Jordan, O.T.; Ana, F.X.M.S.; Bodvarsson, G.S.; Doughty, C.

    1993-10-01

    The Philippine National Oil Company and Lawrence Berkeley Laboratory have conducted an informal cooperative project on the reservoir evaluation of the Palinpinon geothermal field in the Philippines. The work involved the development of various numerical models of the field in order to understand the observed data. A three-dimensional porous medium model of the reservoir has been developed that matches well the observed pressure declines and enthalpy transients of the wells. Submodels representing the reservoir as a fractured porous medium were developed for the analysis of chemical transport of chlorides within the reservoir and the movement of the cold water front away from injection wells. These models indicate that the effective porosity of the reservoir varies between 1 and 7% and the effective permeability between 1 and 45 millidarcies. The numerical models were used to predict the future performance of the Palinpinon reservoir using various possible exploitation scenarios. A limited number of make-up wells were allocated to each sector of the field. When all the make-up wells had been put on line, power production gradually began to decline. The model indicates that under the assumed conditions it will not be possible to maintain the planned power production of 112.5 MWe at Palinpinon I and 80 MWe at Palinpinon II for the next 30 years, but the decline in power output will be within acceptable normal operating capacities of the plants.

  2. The Role of Geochemistry and Stress on Fracture Development and Proppant Behavior in EGS Reservoirs

    Broader source: Energy.gov [DOE]

    Project objective: Develop Improved Methods For Maintaining Permeable Fracture Volumes In EGS Reservoirs.

  3. A general formulation for compositional reservoir simulation

    SciTech Connect (OSTI)

    Rodriguez, F.; Guzman, J.; Galindo-Nava, A.

    1994-12-31

    In this paper the authors present a general formulation to solve the non-linear difference equations that arise in compositional reservoir simulation. The general approach here presented is based on newton`s method and provides a systematic approach to generate several formulations to solve the compositional problem, each possessing a different degree of implicitness and stability characteristics. The Fully-Implicit method is at the higher end of the implicitness spectrum while the IMPECS method, implicit in pressure-explicit in composition and saturation, is at the lower end. They show that all methods may be obtained as particular cases of the fully-implicit method. Regarding the matrix problem, all methods have a similar matrix structure; the composition of the Jacobian matrix is however unique in each case, being in some instances amenable to reductions for optimal solution of the matrix problem. Based on this, a different approach to derive IMPECS type methods is proposed; in this case, the whole set of 2nc + 6 equations, that apply in each gridblock, is reduced to a single pressure equation through matrix reduction operations; this provides a more stable numerical scheme, compared to other published IMPCS methods, in which the subset of thermodynamic equilibrium equations is arbitrarily decoupled form the set of gridblock equations to perform such reduction. The authors discuss how the general formulation here presented can be used to formulate and construct an adaptive-implicit compositional simulators. They also present results on the numerical performance of FI, IMPSEC and IMPECS methods on some test problems.

  4. REVIVING ABANDONED RESERVOIRS WITH HIGH-PRESSURE AIR INJECTION: APPLICATION IN A FRACTURED AND KARSTED DOLOMITE RESERVOIR

    SciTech Connect (OSTI)

    Robert Loucks; Steve Ruppel; Julia Gale; Jon Holder; Jon Olsen; Deanna Combs; Dhiraj Dembla; Leonel Gomez

    2003-06-01

    The Bureau of Economic Geology and Goldrus Producing Company have assembled a multidisciplinary team of geoscientists and engineers to evaluate the applicability of high-pressure air injection (HPAI) in revitalizing a nearly abandoned carbonate reservoir in the Permian Basin of West Texas. The characterization phase of the project is utilizing geoscientists and petroleum engineers from the bureau of Economic Geology and the Department of Petroleum Engineering (both at The University of Texas at Austin) to define the controls on fluid flow in the reservoir as a basis for developing a reservoir model. This model will be used to define a field deployment plant that Goldrus, a small independent oil company, will implement by drilling both vertical and horizontal wells during the demonstration phase of the project. Additional reservoir data are being gathered during the demonstration phase to improve the accuracy of the reservoir model. The results of the demonstration are being closely monitored to provide a basis for improving the design of the HPAI field deployment plan. The results of the reservoir characterization field demonstration and monitoring program will be documented and widely disseminated to facilitate adoption of this technology by oil operators in the Permian Basin and elsewhere in the US.

  5. The Stimulation of Hydrocarbon Reservoirs with Subsurface Nuclear Explosions

    SciTech Connect (OSTI)

    LORENZ,JOHN C.

    2000-12-08

    Between 1965 and 1979 there were five documented and one or more inferred attempts to stimulate the production from hydrocarbon reservoirs by detonating nuclear devices in reservoir strata. Of the five documented tests, three were carried out by the US in low-permeability, natural-gas bearing, sandstone-shale formations, and two were done in the USSR within oil-bearing carbonates. The objectives of the US stimulation efforts were to increase porosity and permeability in a reservoir around a specific well by creating a chimney of rock rubble with fractures extending beyond it, and to connect superimposed reservoir layers. In the USSR, the intent was to extensively fracture an existing reservoir in the more general vicinity of producing wells, again increasing overall permeability and porosity. In both countries, the ultimate goals were to increase production rates and ultimate recovery from the reservoirs. Subsurface explosive devices ranging from 2.3 to about 100 kilotons were used at depths ranging from 1208 m (3963 ft) to 2568 m (8427 ft). Post-shot problems were encountered, including smaller-than-calculated fracture zones, formation damage, radioactivity of the product, and dilution of the BTU value of tie natural gas with inflammable gases created by the explosion. Reports also suggest that production-enhancement factors from these tests fell short of expectations. Ultimately, the enhanced-production benefits of the tests were insufficient to support continuation of the pro-grams within increasingly adversarial political, economic, and social climates, and attempts to stimulate hydrocarbon reservoirs with nuclear devices have been terminated in both countries.

  6. Data Integration for the Generation of High Resolution Reservoir Models

    SciTech Connect (OSTI)

    Albert Reynolds; Dean Oliver; Gaoming Li; Yong Zhao; Chaohui Che; Kai Zhang; Yannong Dong; Chinedu Abgalaka; Mei Han

    2009-01-07

    The goal of this three-year project was to develop a theoretical basis and practical technology for the integration of geologic, production and time-lapse seismic data in a way that makes best use of the information for reservoir description and reservoir performance predictions. The methodology and practical tools for data integration that were developed in this research project have been incorporated into computational algorithms that are feasible for large scale reservoir simulation models. As the integration of production and seismic data require calibrating geological/geostatistical models to these data sets, the main computational tool is an automatic history matching algorithm. The following specific goals were accomplished during this research. (1) We developed algorithms for calibrating the location of the boundaries of geologic facies and the distribution of rock properties so that production and time-lapse seismic data are honored. (2) We developed and implemented specific procedures for conditioning reservoir models to time-lapse seismic data. (3) We developed and implemented algorithms for the characterization of measurement errors which are needed to determine the relative weights of data when conditioning reservoir models to production and time-lapse seismic data by automatic history matching. (4) We developed and implemented algorithms for the adjustment of relative permeability curves during the history matching process. (5) We developed algorithms for production optimization which accounts for geological uncertainty within the context of closed-loop reservoir management. (6) To ensure the research results will lead to practical public tools for independent oil companies, as part of the project we built a graphical user interface for the reservoir simulator and history matching software using Visual Basic.

  7. Twelfth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Rivera, J.

    1987-01-22

    Preface The Twelfth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 20-22, 1987. The year ending December 1986 was very difficult for the domestic geothermal industry. Low oil prices caused a sharp drop in geothermal steam prices. We expected to see some effect upon attendance at the Twelfth Workshop. To our surprise, the attendance was up by thirteen from previous years, with one hundred and fifty-seven registered participants. Eight foreign countries were represented: England, France, Iceland, Italy, Japan, Mexico, New Zealand, and Turkey. Despite a worldwide surplus of oil, international geothermal interest and development is growing at a remarkable pace. There were forty-one technical presentations at the Workshop. All of these are published as papers in this Proceedings volume. Seven technical papers not presented at the Workshop are also published; they concern geothermal developments and research in Iceland, Italy, and New Zealand. In addition to these forty-eight technical presentations or papers, the introductory address was given by Henry J. Ramey, Jr. from the Stanford Geothermal Program. The Workshop Banquet speaker was John R. Berg from the Department of Energy. We thank him for sharing with the Workshop participants his thoughts on the expectations of this agency in the role of alternative energy resources, specifically geothermal, within the country???s energy framework. His talk is represented as a paper in the back of this volume. The chairmen of the technical sessions made an important contribution to the workshop. Other than Stanford faculty members they included: M. Gulati, K. Goyal, G.S. Bodvarsson, A.S. Batchelor, H. Dykstra, M.J. Reed, A. Truesdell, J.S. Gudmundsson, and J.R. Counsil. The Workshop was organized by the Stanford Geothermal Program faculty, staff, and students. We would like to thank Jean Cook, Marilyn King, Amy Osugi, Terri Ramey, and Rosalee Benelli for their valued help with the meeting arrangements and preparing the Proceedings. We also owe great thanks to our students who arranged and operated the audio-visual equipment, specially Jim Lovekin. The Twelfth Workshop was supported by the Geothermal Technology Division of the U. S. Department of Energy through Contract Nos. DE-AS03-80SF11459 and DE-AS07- 84ID12529. We deeply appreciate this continued support. January 1987 Henry J. Ramey, Jr. Paul Kruger Roland N. Horne William E. Brigham Frank G. Miller Jesus Rivera

  8. Thirteenth workshop on geothermal reservoir engineering: Proceedings

    SciTech Connect (OSTI)

    Ramey, H.J. Jr.; Kruger, P.; Horne, R.N.; Brigham, W.E.; Miller, F.G.; Cook, J.W.

    1988-01-21

    PREFACE The Thirteenth Workshop on Geothermal Reservoir Engineering was held at Stanford University on January 19-21, 1988. Although 1987 continued to be difficult for the domestic geothermal industry, world-wide activities continued to expand. Two invited presentations on mature geothermal systems were a keynote of the meeting. Malcolm Grant presented a detailed review of Wairakei, New Zealand and highlighted plans for new development. G. Neri summarized experience on flow rate decline and well test analysis in Larderello, Italy. Attendance continued to be high with 128 registered participants. Eight foreign countries were represented: England, France, Iceland, Italy, New Zealand, Japan, Mexico and The Philippines. A discussion of future workshops produced a strong recommendation that the Stanford Workshop program continue for the future. There were forty-one technical presentations at the Workshop. All of these are published as papers in this Proceedings volume. Four technical papers not presented at the Workshop are also published. In addition to these forty five technical presentations or papers, the introductory address was given by Henry J. Ramey, Jr. from the Stanford Geothermal Program. The Workshop Banquet speaker was Gustavo Calderon from the Inter-American Development Bank. We thank him for sharing with the Workshop participants a description of the Bank???s operations in Costa Rica developing alternative energy resources, specifically Geothermal, to improve the country???s economic basis. His talk appears as a paper in the back of this volume. The chairmen of the technical sessions made an important contribution to the workshop. Other than Stanford faculty members they included: J. Combs, G. T. Cole, J. Counsil, A. Drenick, H. Dykstra, K. Goyal, P. Muffler, K. Pruess, and S. K. Sanyal. The Workshop was organized by the Stanford Geothermal Program faculty, staff and students. We would like to thank Marilyn King, Pat Oto, Terri Ramey, Bronwyn Jones, Yasmin Gulamani, and Rosalee Benelli for their valued help with the meeting arrangements and preparing the Proceedings. We also owe great thanks to our students who arranged and operated the audio-visual equipment, especially Jeralyn Luetkehans. The Thirteenth Workshop was supported by the Geothermal Technology Division of the U.S. Department of Energy through Contract No. DE-AS07-84ID12529. We deeply appreciate this continued support. Henry J. Ramey, Jr. Paul Kruger Roland N. Horne William E. Brigham Frank G. Miller Jean W. Cook

  9. US Geological Survey publications on western tight gas reservoirs

    SciTech Connect (OSTI)

    Krupa, M.P.; Spencer, C.W.

    1989-02-01

    This bibliography includes reports published from 1977 through August 1988. In 1977 the US Geological Survey (USGS), in cooperation with the US Department of Energy's, (DOE), Western Gas Sands Research program, initiated a geological program to identify and characterize natural gas resources in low-permeability (tight) reservoirs in the Rocky Mountain region. These reservoirs are present at depths of less than 2,000 ft (610 m) to greater than 20,000 ft (6,100 m). Only published reports readily available to the public are included in this report. Where appropriate, USGS researchers have incorporated administrative report information into later published studies. These studies cover a broad range of research from basic research on gas origin and migration to applied studies of production potential of reservoirs in individual wells. The early research included construction of regional well-log cross sections. These sections provide a basic stratigraphic framework for individual areas and basins. Most of these sections include drill-stem test and other well-test data so that the gas-bearing reservoirs can be seen in vertical and areal dimensions. For the convenience of the reader, the publications listed in this report have been indexed by general categories of (1) authors, (2) states, (3) geologic basins, (4) cross sections, (5) maps (6) studies of gas origin and migration, (7) reservoir or mineralogic studies, and (8) other reports of a regional or specific topical nature.

  10. Maquoketa paleotopography key to reservoirs in western Illinois

    SciTech Connect (OSTI)

    Whitaker, S.T.; Ledbetter, J.C.

    1996-08-12

    Shallow Silurian reservoirs in western Illinois have been a primary target for exploration since the late 1950s. It was not until the discovery and development of Buckhorn Consolidated field in the early 1980s, however, that significant drilling efforts for Silurian reservoirs were focused on western Illinois. At Buckhorn, 1.7 million bbl of oil have been produced from a basal Silurian dolomite at about 650 ft. Drawn by inexpensive drilling and available acreage, hundreds of operators flocked to western Illinois to try their luck. By the late 1980s, however, exploration efforts in western Illinois were curtailed due to the failure to locate additional significant reservoirs. Much of this failure was due to the lack of a suitable geologic model that could be used to explain the reason for reservoir development and thereby guide exploration efforts. An article by Whitaker and Howard in 1995 presented a geologic model explaining Silurian reservoir development and stratigraphic entrapment of oil at Buckhorn Consolidated field were formed as Silurian dolomite in-filled a shallow paleovalley cut into the underlying Ordovician Maquoketa shale. Some companies have recently initiated new exploration efforts in the area using this model. This paper discusses the efforts and results of several of these new areas.

  11. Reservoir Stimulation Optimization with Operational Monitoring for Creation of EGS

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Fernandez, Carlos A.

    EGS field projects have not sustained production at rates greater than of what is needed for economic viability. The primary limitation that makes commercial EGS infeasible is our current inability to cost-effectively create high-permeability reservoirs from impermeable, igneous rock within the 3,000-10,000 ft depth range. Our goal is to develop a novel fracturing fluid technology that maximizes reservoir permeability while reducing stimulation cost and environmental impact. Laboratory equipment development to advance laboratory characterization/monitoring is also a priority of this project to study and optimize the physicochemical properties of these fracturing fluids in a range of reservoir conditions. Barrier G is the primarily intended GTO barrier to be addressed as well as support addressing barriers D, E and I.

  12. Reservoir Stimulation Optimization with Operational Monitoring for Creation of EGS

    DOE Data Explorer [Office of Scientific and Technical Information (OSTI)]

    Fernandez, Carlos A.

    2013-09-25

    EGS field projects have not sustained production at rates greater than of what is needed for economic viability. The primary limitation that makes commercial EGS infeasible is our current inability to cost-effectively create high-permeability reservoirs from impermeable, igneous rock within the 3,000-10,000 ft depth range. Our goal is to develop a novel fracturing fluid technology that maximizes reservoir permeability while reducing stimulation cost and environmental impact. Laboratory equipment development to advance laboratory characterization/monitoring is also a priority of this project to study and optimize the physicochemical properties of these fracturing fluids in a range of reservoir conditions. Barrier G is the primarily intended GTO barrier to be addressed as well as support addressing barriers D, E and I.

  13. Reservoir characterization of the Smackover Formation in southwest Alabama

    SciTech Connect (OSTI)

    Kopaska-Merkel, D.C.; Hall, D.R.; Mann, S.D.; Tew, B.H.

    1993-02-01

    The Upper Jurassic Smackover Formation is found in an arcuate belt in the subsurface from south Texas to panhandle Florida. The Smackover is the most prolific hydrocarbon-producing formation in Alabama and is an important hydrocarbon reservoir from Florida to Texas. In this report Smackover hydrocarbon reservoirs in southwest Alabama are described. Also, the nine enhanced- and improved-recovery projects that have been undertaken in the Smackover of Alabama are evaluated. The report concludes with recommendations about potential future enhanced- and improved-recovery projects in Smackover reservoirs in Alabama and an estimate of the potential volume of liquid hydrocarbons recoverable by enhanced- and improved-recovery methods from the Smackover of Alabama.

  14. Seismic and Rockphysics Diagnostics of Multiscale Reservoir Textures

    SciTech Connect (OSTI)

    Gary Mavko

    2005-07-01

    This final technical report summarizes the results of the work done in this project. The main objective was to quantify rock microstructures and their effects in terms of elastic impedances in order to quantify the seismic signatures of microstructures. Acoustic microscopy and ultrasonic measurements were used to quantify microstructures and their effects on elastic impedances in sands and shales. The project led to the development of technologies for quantitatively interpreting rock microstructure images, understanding the effects of sorting, compaction and stratification in sediments, and linking elastic data with geologic models to estimate reservoir properties. For the public, ultimately, better technologies for reservoir characterization translates to better reservoir development, reduced risks, and hence reduced energy costs.

  15. Application of Integrated Reservoir Management and Reservoir Characterization to Optimize Infill Drillings. Annual technical progress report, June 13, 1996 to June 12, 1998

    SciTech Connect (OSTI)

    Nevans, Jerry W.; Blasingame, Tom; Doublet, Louis; Kelkar, Mohan; Freeman, George; Callard, Jeff; Moore, David; Davies, David; Vessell, Richard; Pregger, Brian; Dixon, Bill

    1999-04-27

    Infill drilling of wells on a uniform spacing, without regard to reservoir performance and characterization, does not optimize reservoir development because it fails to account for the complex nature of reservoir heterogeneities present in many low permeability reservoirs, and carbonate reservoirs in particular. New and emerging technologies, such as geostatistical modeling, rigorous decline curve analysis, reservoir rock typing, and special core analysis can be used to develop a 3-D simulation model for prediction of infill locations. Other technologies, such as inter-well injection tracers and magnetic flow conditioners, can also aid in the efficient evaluation and operation of both injection and producing wells. The purpose of this project was to demonstrate useful and cost effective methods of exploitation of the shallow shelf carbonate reservoirs of the Permian Basin located in West Texas.

  16. Upscaling verticle permeability within a fluvio-aeolian reservoir

    SciTech Connect (OSTI)

    Thomas, S.D.; Corbett, P.W.M.; Jensen, J.L.

    1997-08-01

    Vertical permeability (k{sub v}) is a crucial factor in many reservoir engineering issues. To date there has been little work undertaken to understand the wide variation of k{sub v} values measured at different scales in the reservoir. This paper presents the results of a study in which we have modelled the results of a downhole well tester using a statistical model and high resolution permeability data. The work has demonstrates and quantifies a wide variation in k{sub v} at smaller, near wellbore scales and has implications for k{sub v} modelling at larger scales.

  17. Miscellaneous States Crude Oil Reserves in Nonproducing Reservoirs (Million

    Gasoline and Diesel Fuel Update (EIA)

    Barrels) Reserves in Nonproducing Reservoirs (Million Barrels) Miscellaneous States Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 1 1 2000's 1 1 16 17 4 4 2 5 4 7 2010's 5 7 12 9 6 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved

  18. Montana Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Montana Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 6 83 2000's 36 43 65 79 104 88 91 90 50 42 2010's 74 59 95 104 155 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing

  19. Federal Offshore--California Crude Oil Reserves in Nonproducing Reservoirs

    Gasoline and Diesel Fuel Update (EIA)

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Federal Offshore--California Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 21 15 2000's 42 62 62 93 55 32 37 20 12 12 2010's 13 13 25 17 18 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release

  20. Florida Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Florida Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 6 12 2000's 9 7 7 6 6 2 1 12 0 2 2010's 2 4 3 9 6 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves of Crude

  1. Illinois Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Illinois Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 4 11 2000's 4 15 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves of Crude Oil Illinois Proved

  2. Kansas Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Kansas Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 11 12 2000's 13 21 23 18 11 16 17 9 11 3 2010's 2 4 6 11 34 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves

  3. Kentucky Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Kentucky Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 0 0 2000's 0 0 4 4 5 5 0 0 1 3 2010's 0 0 0 1 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves of Crude

  4. Louisiana--North Crude Oil Reserves in Nonproducing Reservoirs (Million

    Gasoline and Diesel Fuel Update (EIA)

    Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Louisiana--North Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 18 42 2000's 31 28 16 14 11 17 14 11 9 8 2010's 45 30 13 12 17 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  5. Louisiana--South Onshore Crude Oil Reserves in Nonproducing Reservoirs

    Gasoline and Diesel Fuel Update (EIA)

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Louisiana--South Onshore Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 143 146 2000's 123 134 139 150 115 148 162 164 122 129 2010's 126 113 125 155 188 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next

  6. Louisiana--State Offshore Crude Oil Reserves in Nonproducing Reservoirs

    Gasoline and Diesel Fuel Update (EIA)

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Louisiana--State Offshore Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 37 38 2000's 50 66 30 26 24 28 22 18 13 12 2010's 12 9 19 13 16 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date:

  7. Michigan Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Michigan Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 3 1 2000's 4 6 4 14 10 17 15 2 9 6 2010's 0 0 0 4 3 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves of

  8. Alabama (with State Offshore) Crude Oil Reserves in Nonproducing Reservoirs

    Gasoline and Diesel Fuel Update (EIA)

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Alabama (with State Offshore) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 4 2 2000's 2 4 1 2 2 2 0 0 0 0 2010's 0 1 2 2 15 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016

  9. Alaska (with Total Offshore) Crude Oil Reserves in Nonproducing Reservoirs

    Gasoline and Diesel Fuel Update (EIA)

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Alaska (with Total Offshore) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 806 932 2000's 511 389 546 734 707 595 442 400 529 633 2010's 622 566 802 639 548 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015

  10. Arkansas Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Arkansas Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 2 5 2000's 7 4 5 2 3 2 1 0 0 0 2010's 1 0 11 10 8 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves of Crude

  11. California--State Offshore Crude Oil Reserves in Nonproducing Reservoirs

    Gasoline and Diesel Fuel Update (EIA)

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) California--State Offshore Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 7 0 2000's 32 30 42 25 30 35 34 27 23 46 2010's 47 62 53 52 46 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date:

  12. Colorado Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    Gasoline and Diesel Fuel Update (EIA)

    Reserves in Nonproducing Reservoirs (Million Barrels) Colorado Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 26 30 2000's 49 44 56 61 62 74 102 122 123 42 2010's 180 208 283 607 765 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved

  13. Pressure Testing of a High Temperature Naturally Fractured Reservoir

    Office of Scientific and Technical Information (OSTI)

    (Conference) | SciTech Connect Conference: Pressure Testing of a High Temperature Naturally Fractured Reservoir Citation Details In-Document Search Title: Pressure Testing of a High Temperature Naturally Fractured Reservoir Los Alamos National Laboratory has conducted a number of pumping and flow-through tests at the Hot Dry rock (HDR) test site at Fenton Hill, New Mexico. These tests consisted of injecting fresh water at controlled rates up to 12 BPM (32 {ell}/s) and surface pressures up to

  14. Mississippi Dry Natural Gas New Reservoir Discoveries in Old Fields

    U.S. Energy Information Administration (EIA) Indexed Site

    (Billion Cubic Feet) New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Mississippi Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1970's 2 65 9 1980's 50 31 24 8 20 11 5 3 9 28 1990's 19 8 9 3 8 2 1 2 0 8 2000's 1 19 27 28 7 3 6 1 3 0 2010's 0 0 0 0 2 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data.

  15. Pennsylvania Dry Natural Gas New Reservoir Discoveries in Old Fields

    U.S. Energy Information Administration (EIA) Indexed Site

    (Billion Cubic Feet) New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Pennsylvania Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1970's 0 0 3 1980's 0 4 14 8 0 17 2 0 0 12 1990's 2 3 5 4 29 2 29 5 4 1 2000's 0 1 18 3 3 0 0 3 32 0 2010's 904 322 0 79 6 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data.

  16. Texas--State Offshore Crude Oil Reserves in Nonproducing Reservoirs

    U.S. Energy Information Administration (EIA) Indexed Site

    (Million Barrels) Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--State Offshore Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 0 0 2000's 0 0 0 2 0 1 0 0 0 0 2010's 0 1 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  17. New Mexico Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs (Million Barrels) New Mexico Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 97 157 2000's 91 161 146 133 142 171 159 147 136 149 2010's 180 185 232 314 489 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages:

  18. North Dakota Crude Oil Reserves in Nonproducing Reservoirs (Million

    U.S. Energy Information Administration (EIA) Indexed Site

    Barrels) Reserves in Nonproducing Reservoirs (Million Barrels) North Dakota Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 17 22 2000's 29 91 62 47 52 56 53 107 148 463 2010's 969 1,421 2,207 3,278 3,456 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016

  19. Ohio Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs (Million Barrels) Ohio Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 0 17 2000's 10 6 8 8 7 7 8 8 7 5 2010's 1 1 2 7 3 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing Reserves of Crude Oil

  20. Oklahoma Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs (Million Barrels) Oklahoma Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 98 80 2000's 111 109 105 92 92 101 90 118 129 138 2010's 143 244 279 292 444 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved

  1. Pennsylvania Crude Oil Reserves in Nonproducing Reservoirs (Million

    U.S. Energy Information Administration (EIA) Indexed Site

    Barrels) Reserves in Nonproducing Reservoirs (Million Barrels) Pennsylvania Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 0 5 2000's 1 1 1 1 1 0 0 0 1 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing

  2. Wyoming Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs (Million Barrels) Wyoming Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 31 52 2000's 63 74 69 61 45 249 258 208 162 144 2010's 152 188 233 219 362 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved

  3. Utah Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)

    U.S. Energy Information Administration (EIA) Indexed Site

    Reserves in Nonproducing Reservoirs (Million Barrels) Utah Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 36 58 2000's 91 100 91 76 61 52 164 174 140 235 2010's 257 258 368 312 261 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved

  4. West Virginia Crude Oil Reserves in Nonproducing Reservoirs (Million

    U.S. Energy Information Administration (EIA) Indexed Site

    Barrels) Reserves in Nonproducing Reservoirs (Million Barrels) West Virginia Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 3 3 2000's 0 0 0 0 0 0 0 0 0 0 2010's 0 1 1 2 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Proved Nonproducing

  5. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2003-10-01

    This report presents the work done so far on Hunton Formation in West Carney Field in Lincoln County, Oklahoma. West Carney Field produces oil and gas from the Hunton Formation. The field was developed starting in 1995. Some of the unique characteristics of the field include decreasing water oil ratio over time, decreasing gas-oil ratio at the beginning of production, inability to calculate oil reserves in the field based on log data, and sustained oil rates over long periods of time. To understand the unique characteristics of the field, an integrated evaluation was undertaken. Production data from the field were meticulously collected, and over forty wells were cored and logged to better understand the petrophysical and engineering characteristics. Based on the work done in this budget period so far, some of the preliminary conclusions can be listed as follows: (1) Based on PVT analysis, the field most likely contains volatile oil with bubble point close to initial reservoir pressure of 1,900 psia. (2) The initial oil in place, which is contact with existing wells, can be determined by newly developed material balance technique. The oil in place, which is in communication, is significantly less than determined by volumetric analysis, indicating heterogeneous nature of the reservoir. The oil in place, determined by material balance, is greater than determined by decline curve analysis. This difference may lead to additional locations for in fill wells. (3) The core and log evaluation indicates that the intermediate pores (porosity between 2 and 6 %) are very important in determining production potential of the reservoir. These intermediate size pores contain high oil saturation. (4) The limestone part of the reservoir, although low in porosity (mostly less than 6 %) is much more prolific in terms of oil production than the dolomite portion of the reservoir. The reason for this difference is the higher oil saturation in low porosity region. As the average porosity increases, the remaining oil saturation decreases. This is evident from log and core analysis. (5) Using a compositional simulator, we are able to reproduce the important reservoir characteristics by assuming a two layer model. One layer is high permeability region containing water and the other layer is low permeability region containing mostly oil. The results are further verified by using a dual porosity model. Assuming that most of the volatile oil is contained in the matrix and the water is contained in the fractures, we are able to reproduce important reservoir performance characteristics. (6) Evaluation of secondary mechanisms indicates that CO{sub 2} flooding is potentially a viable option if CO{sub 2} is available at reasonable price. We have conducted detailed simulation studies to verify the effectiveness of CO{sub 2} huff-n-puff process. We are in the process of conducting additional lab tests to verify the efficacy of the same displacement. (7) Another possibility of improving the oil recovery is to inject surfactants to change the near well bore wettability of the rock from oil wet to water wet. By changing the wettability, we may be able to retard the water flow and hence improve the oil recovery as a percentage of total fluid produced. If surfactant is reasonably priced, other possibility is also to use huff-n-puff process using surfactants. Laboratory experiments are promising, and additional investigation continues. (8) Preliminary economic evaluation indicates that vertical wells outperform horizontal wells. Future work in the project would include: (1) Build multi-well numerical model to reproduce overall reservoir performance rather than individual well performance. Special emphasis will be placed on hydrodynamic connectivity between wells. (2) Collect data from adjacent Hunton reservoirs to validate our understanding of what makes it a productive reservoir. (3) Develop statistical methods to rank various reservoirs in Hunton formation. This will allow us to evaluate other Hunton formations based on old well logs, and determine, apriori, if

  6. THMC Modeling of EGS Reservoirs -- Continuum through Discontinuum Representations. Capturing Reservoir Stimulation, Evolution and Induced Seismicity

    SciTech Connect (OSTI)

    Elsworth, Derek; Izadi, Ghazal; Gan, Quan; Fang, Yi; Taron, Josh; Sonnenthal, Eric

    2015-07-28

    This work has investigated the roles of effective stress induced by changes in fluid pressure, temperature and chemistry in contributing to the evolution of permeability and induced seismicity in geothermal reservoirs. This work has developed continuum models [1] to represent the progress or seismicity during both stimulation [2] and production [3]. These methods have been used to resolve anomalous observations of induced seismicity at the Newberry Volcano demonstration project [4] through the application of modeling and experimentation. Later work then focuses on the occurrence of late stage seismicity induced by thermal stresses [5] including the codifying of the timing and severity of such responses [6]. Furthermore, mechanistic linkages between observed seismicity and the evolution of permeability have been developed using data from the Newberry project [7] and benchmarked against field injection experiments. Finally, discontinuum models [8] incorporating the roles of discrete fracture networks have been applied to represent stimulation and then thermal recovery for new arrangements of geothermal wells incorporating the development of flow manifolds [9] in order to increase thermal output and longevity in EGS systems.

  7. Carbonation Mechanism of Reservoir Rock by Supercritical Carbon Dioxide

    Broader source: Energy.gov [DOE]

    Project Objectives: Elucidate comprehensively the carbonation reaction mechanisms between supercritical carbon dioxide (scCO2) and reservoir rocks consisting of different mineralogical compositions in aqueous and non-aqueous environments at temperatures of up to 250ºC, and to develop chemical modeling of CO2-reservior rock interactions.

  8. Evaluation of field development plans using 3-D reservoir modelling

    SciTech Connect (OSTI)

    Seifert, D.; Lewis, J.J.M.; Newbery, J.D.H.

    1997-08-01

    Three-dimensional reservoir modelling has become an accepted tool in reservoir description and is used for various purposes, such as reservoir performance prediction or integration and visualisation of data. In this case study, a small Northern North Sea turbiditic reservoir was to be developed with a line drive strategy utilising a series of horizontal producer and injector pairs, oriented north-south. This development plan was to be evaluated and the expected outcome of the wells was to be assessed and risked. Detailed analyses of core, well log and analogue data has led to the development of two geological {open_quotes}end member{close_quotes} scenarios. Both scenarios have been stochastically modelled using the Sequential Indicator Simulation method. The resulting equiprobable realisations have been subjected to detailed statistical well placement optimisation techniques. Based upon bivariate statistical evaluation of more than 1000 numerical well trajectories for each of the two scenarios, it was found that the wells inclinations and lengths had a great impact on the wells success, whereas the azimuth was found to have only a minor impact. After integration of the above results, the actual well paths were redesigned to meet external drilling constraints, resulting in substantial reductions in drilling time and costs.

  9. Advanced Reservoir Imaging Using Frequency-Dependent Seismic Attributes

    SciTech Connect (OSTI)

    Fred Hilterman; Tad Patzek; Gennady Goloshubin; Dmitriy Silin; Charlotte Sullivan; Valeri Korneev

    2007-12-31

    Our report concerning advanced imaging and interpretation technology includes the development of theory, the implementation of laboratory experiments and the verification of results using field data. We investigated a reflectivity model for porous fluid-saturated reservoirs and demonstrated that the frequency-dependent component of the reflection coefficient is asymptotically proportional to the reservoir fluid mobility. We also analyzed seismic data using different azimuths and offsets over physical models of fractures filled with air and water. By comparing our physical model synthetics to numerical data we have identified several diagnostic indicators for quantifying the fractures. Finally, we developed reflectivity transforms for predicting pore fluid and lithology using rock-property statistics from 500 reservoirs in both the shelf and deep-water Gulf of Mexico. With these transforms and seismic AVO gathers across the prospect and its down-dip water-equivalent reservoir, fluid saturation can be estimated without a calibration well that ties the seismic. Our research provides the important additional mechanisms to recognize, delineate, and validate new hydrocarbon reserves and assist in the development of producing fields.

  10. EXPLOITATION AND OPTIMIZATION OF RESERVOIR PERFORMANCE IN HUNTON FORMATION, OKLAHOMA

    SciTech Connect (OSTI)

    Mohan Kelkar

    2005-02-01

    Hunton formation in Oklahoma has displayed some unique production characteristics. These include high initial water-oil and gas-oil ratios, decline in those ratios over time and temporary increase in gas-oil ratio during pressure build up. The formation also displays highly complex geology, but surprising hydrodynamic continuity. This report addresses three key issues related specifically to West Carney Hunton field and, in general, to any other Hunton formation exhibiting similar behavior: (1) What is the primary mechanism by which oil and gas is produced from the field? (2) How can the knowledge gained from studying the existing fields can be extended to other fields which have the potential to produce? (3) What can be done to improve the performance of this reservoir? We have developed a comprehensive model to explain the behavior of the reservoir. By using available production, geological, core and log data, we are able to develop a reservoir model which explains the production behavior in the reservoir. Using easily available information, such as log data, we have established the parameters needed for a field to be economically successful. We provide guidelines in terms of what to look for in a new field and how to develop it. Finally, through laboratory experiments, we show that surfactants can be used to improve the hydrocarbons recovery from the field. In addition, injection of CO{sub 2} or natural gas also will help us recover additional oil from the field.

  11. Improved Oil Recovery in Mississippian Carbonate Reservoirs of Kansas - Near-Term, Class II

    SciTech Connect (OSTI)

    Carr, Timothy R.; Green, Don W.; Willhite, G. Paul

    2001-10-30

    The focus of this project was development and demonstration of cost-effective reservoir description and management technologies to extend the economic life of mature reservoirs in Kansas and the mid-continent.

  12. Analysis of Geothermal Reservoir Stimulation using Geomechanics-Based Stochastic Analysis of Injection-Induced Seismicity

    Broader source: Energy.gov [DOE]

    This project will develop a model for seismicity-based reservoir characterization (SBRC) by combining rock mechanics; finite element modeling; geo-statistical concepts to establish relationships between micro-seismicity; reservoir flow and geomechanical characteristics.

  13. Visual display of reservoir parameters affecting enhanced oil recovery. Quarterly report, July 1995--September 1995

    SciTech Connect (OSTI)

    Wood, J.R.

    1995-10-01

    Research continued on reservoir characterization. An atlas of thin section petrology of reservoir samples from the Southern San Joaquin Basin was acquired. One-dimensional modeling activities were initiated. Results of a modeling study of Elk Hills is described.

  14. FRAC-STIM: A Physics-Based Fracture Simulation, /reservoir Flow...

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    FRAC-STIM: A Physics-Based Fracture Simulation, reservoir Flow and Heat Transport Simulator(aka FALCON) FRAC-STIM: A Physics-Based Fracture Simulation, reservoir Flow and Heat ...

  15. Texas--RRC District 8A Crude Oil Reserves in Nonproducing Reservoirs...

    Gasoline and Diesel Fuel Update (EIA)

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 8A Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  16. Texas--RRC District 7B Crude Oil Reserves in Nonproducing Reservoirs...

    Gasoline and Diesel Fuel Update (EIA)

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 7B Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  17. Texas--RRC District 7C Crude Oil Reserves in Nonproducing Reservoirs...

    Annual Energy Outlook [U.S. Energy Information Administration (EIA)]

    Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Texas--RRC District 7C Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2...

  18. New York Dry Natural Gas New Reservoir Discoveries in Old Fields...

    U.S. Energy Information Administration (EIA) Indexed Site

    New Reservoir Discoveries in Old Fields (Billion Cubic Feet) New York Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0 Year-1 Year-2...

  19. Monitoring EGS Stimulation and Reservoir Dynamics with InSAR and MEQ |

    Office of Energy Efficiency and Renewable Energy (EERE) Indexed Site

    Department of Energy EGS Stimulation and Reservoir Dynamics with InSAR and MEQ Monitoring EGS Stimulation and Reservoir Dynamics with InSAR and MEQ Monitoring EGS Stimulation and Reservoir Dynamics with InSAR and MEQ presentation at the April 2013 peer review meeting held in Denver, Colorado. PDF icon monitoring_egs_insar_meq_peer2013.pdf More Documents & Publications Novel use of 4D Monitoring Techniques to Improve Reservoir Longevity and Productivity in Enhanced Geothermal Systems

  20. Lower Watts Bar Reservoir Clinch River/Poplar Creek | Department of Energy

    Office of Environmental Management (EM)

    Watts Bar Reservoir Clinch River/Poplar Creek Lower Watts Bar Reservoir Clinch River/Poplar Creek This document discusses the Lower Watts Bar Reservoir Clinch River/Poplar Creek. Topics include: * The area's safety * Any use limitations for the area * History and cleanup background for this area * How DOE's cleanup program addressed the problem PDF icon Lower Watts Bar Reservoir Clinch River/Poplar Creek More Documents & Publications EA-1175: Final Environmental Assessment OREM

  1. Mapping of Reservoir Properties and Facies Through Integration of Static and Dynamic Data

    SciTech Connect (OSTI)

    Reynolds, Albert C.; Oliver, Dean S.; Zhang, Fengjun; Dong, Yannong; Skjervheim, Jan Arild; Liu, Ning

    2003-03-10

    The goal of this project was to develop computationally efficient automatic history matching techniques for generating geologically plausible reservoir models which honor both static and dynamic data. Solution of this problem was necessary for the quantification of uncertainty in future reservoir performance predictions and for the optimization of reservoir management.

  2. Nanosensors as Reservoir Engineering Tools to Map Insitu Temperature Distributions in Geothermal Reservoirs

    SciTech Connect (OSTI)

    Morgan Ames

    2011-06-15

    The feasibility of using nanosensors to measure temperature distribution and predict thermal breakthrough in geothermal reservoirs is addressed in this report. Four candidate sensors were identified: melting tin-bismuth alloy nanoparticles, silica nanoparticles with covalently-attached dye, hollow silica nanoparticles with encapsulated dye and impermeable melting shells, and dye-polymer composite time-temperature indicators. Four main challenges associated with the successful implementation of temperature nanosensors were identified: nanoparticle mobility in porous and fractured media, the collection and detection of nanoparticles at the production well, engineering temperature sensing mechanisms that are both detectable and irreversible, and inferring the spatial geolocation of temperature measurements in order to map temperature distribution. Initial experiments were carried out to investigate each of these challenges. It was demonstrated in a slim-tube injection experiment that it is possible to transport silica nanoparticles over large distances through porous media. The feasibility of magnetic collection of nanoparticles from produced fluid was evaluated experimentally, and it was estimated that 3% of the injected nanoparticles were recovered in a prototype magnetic collection device. An analysis technique was tailored to nanosensors with a dye-release mechanism to estimate temperature measurement geolocation by analyzing the return curve of the released dye. This technique was used in a hypothetical example problem, and good estimates of geolocation were achieved. Tin-bismuth alloy nanoparticles were synthesized using a sonochemical method, and a bench heating experiment was performed using these nanoparticles. Particle growth due to melting was observed, indicating that tin-bismuth nanoparticles have potential as temperature nanosensors

  3. APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR

    SciTech Connect (OSTI)

    T. Scott Hickman; James J. Justice

    2001-06-16

    The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

  4. APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR

    SciTech Connect (OSTI)

    T. Scott Hickman; James J. Justice

    2001-12-11

    The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

  5. APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SAN ANDRES RESERVOIR

    SciTech Connect (OSTI)

    T. Scott Hickman

    2003-01-17

    The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

  6. GPFA-AB_Phase1ReservoirTask2DataUpload

    SciTech Connect (OSTI)

    Teresa E. Jordan

    2015-10-22

    This submission to the Geothermal Data Repository (GDR) node of the National Geothermal Data System (NGDS) in support of Phase 1 Low Temperature Geothermal Play Fairway Analysis for the Appalachian Basin. The files included in this zip file contain all data pertinent to the methods and results of this tasks output, which is a cohesive multi-state map of all known potential geothermal reservoirs in our region, ranked by their potential favorability. Favorability is quantified using a new metric, Reservoir Productivity Index, as explained in the Reservoirs Methodology Memo (included in zip file). Shapefile and images of the Reservoir Productivity and Reservoir Uncertainty are included as well.

  7. Monitoring the Bulalo geothermal reservoir, Philippines, using precision gravity data

    SciTech Connect (OSTI)

    San Andres, R.B.; Pedersen, J.R.

    1993-10-01

    Precision gravity monitoring of the Bulalo geothermal field began in 1980 to estimate the natural mass recharge to the reservoir. Between 1980 and 1991, gravity decreases exceeding 2.5 {times} 10{sup {minus}6} N/kg (250 microgals) were observed in response to fluid withdrawals. A maximum rate of {minus}26 microgals per year was observed near the production center. Mass discharges predicted by recent reservoir simulation modeling generally match those inferred from the observed gravity data. According to simulation studies, no recharge occurred between 1980 and 1984. The mass recharge between 1984 and 1991 was estimated to be 30% of net fluid withdrawal during the same period, equivalent to an average rate of 175 kg/s (630 metric tons per hour).

  8. Seismic analysis applied to the delimiting of a gas reservoir

    SciTech Connect (OSTI)

    Ronquillo, G.; Navarro, M.; Lozada, M.; Tafolla, C.

    1996-08-01

    We present the results of correlating seismic models with petrophysical parameters and well logs to mark the limits of a gas reservoir in sand lenses. To fulfill the objectives of the study, we used a data processing sequence that included wavelet manipulation, complex trace attributes and pseudovelocities inversion, along with several quality control schemes to insure proper amplitude preservation. Based on the analysis and interpretation of the seismic sections, several areas of interest were selected to apply additional signal treatment as preconditioning for petrophysical inversion. Signal classification was performed to control the amplitudes along the horizons of interest, and to be able to find an indirect interpretation of lithologies. Additionally, seismic modeling was done to support the results obtained and to help integrate the interpretation. The study proved to be a good auxiliary tool in the location of the probable extension of the gas reservoir in sand lenses.

  9. Lower 48 States Crude Oil Reserves in Nonproducing Reservoirs (Million

    Gasoline and Diesel Fuel Update (EIA)

    Barrels) Reserves in Nonproducing Reservoirs (Million Barrels) Lower 48 States Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 1990's NA NA 3,341 3,274 2000's 3,508 4,806 4,725 4,846 4,436 5,096 4,732 5,055 4,871 5,382 2010's 6,358 8,483 11,082 12,561 14,268 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date:

  10. On Leakage from Geologic Storage Reservoirs of CO2

    SciTech Connect (OSTI)

    Pruess, Karsten

    2006-02-14

    Large amounts of CO2 would need to be injected underground to achieve a significant reduction of atmospheric emissions. The large areal extent expected for CO2 plumes makes it likely that caprock imperfections will be encountered, such as fault zones or fractures, which may allow some CO2 to escape from the primary storage reservoir. Leakage of CO2 could also occur along wellbores. Concerns with escape of CO2 from a primary geologic storage reservoir include (1) acidification of groundwater resources, (2) asphyxiation hazard when leaking CO2 is discharged at the land surface, (3) increase in atmospheric concentrations of CO2, and (4) damage from a high-energy, eruptive discharge (if such discharge is physically possible). In order to gain public acceptance for geologic storage as a viable technology for reducing atmospheric emissions of CO2, it is necessary to address these issues and demonstrate that CO2 can be injected and stored safely in geologic formations.

  11. REVIVING ABANDONED RESERVOIRS WITH HIGH-PRESSURE AIR INJECTION: APPLICATION IN A FRACTURED AND KARSTED DOLOMITE RESERVOIR

    SciTech Connect (OSTI)

    Robert Loucks; Steve Ruppel; Julia Gale; Jon Holder; Jon Olson; Deanna Combs; Dhiraj Dembla

    2004-06-01

    The Bureau of Economic Geology (BEG) and Goldrus Producing Company have assembled a multidisciplinary team of geoscientists and engineers to evaluate the applicability of high-pressure air injection (HPAI) in revitalizing a nearly abandoned carbonate reservoir in the Permian Basin of West Texas. The characterization phase of the project is utilizing geoscientists and petroleum engineers from the Bureau of Economic Geology (BEG) and the Department of Petroleum and Geosystems Engineering (both at The University of Texas at Austin) to define the controls on fluid flow in the reservoir as a basis for developing a reservoir model. This model will be used to define a field deployment plan that Goldrus, a small independent oil company, will implement by drilling both vertical and horizontal wells during the demonstration phase of the project. Additional reservoir data were to be generated during the demonstration phase to improve the accuracy of the reservoir model. The demonstration phase has been delayed by Goldrus because of funding problems. Since the first of the year, Goldrus has been active in searching for partners to help finance the project. To this end it has commissioned several small consulting studies to technically support its effort to secure a partner. After financial support is obtained, the demonstration phase of the project will proceed. Since just after the beginning of the year, BEG has curtailed project activities and spending of DOE funds except for the continued support of one engineering student. This student has now completed his work and has written a thesis describing his research (titled ''Stimulating enhanced oil recovery (EOR) by high-pressure air injection (HPAI) in west Texas light oil reservoir''). We plan to recommence our work on the project as soon as the operator obtains necessary funding to carry out the demonstration phase of the project. In order to complete all activities specified in the proposal, it will be necessary to request an extension of the project from the originally defined completion date. We are confident that Goldrus will obtain the necessary funding to continue and that we can complete the project if an extension is granted. We strongly believe that the results of this study will provide the impetus for a new approach to enhanced oil recovery in the Permian Basin and elsewhere in the United States.

  12. State of Seismic Methods For Geothermal Reservoir Exploration and Assessment

    Office of Scientific and Technical Information (OSTI)

    -D Seismic Methods For Geothermal Reservoir Exploration and Assessment - Summary E.L Majer Lawrence Berkeley National Laboratory Introduction A wide variety of seismic methods covering the spectrum from DC to kilohertz have been employed at one time or the other in geothermal environments. The reasons have varied from exploration for a heat source to attempting to find individual fractures producing hot fluids. For the purposes here we will assume that overall objective of seismic imaging is for

  13. NFFLOW: A reservoir simulator incorporating explicit fractures (SPE 153890)

    SciTech Connect (OSTI)

    Boyle, E.J.; Sams, W.N.

    2012-01-01

    NFFLOW is a research code that quickly and inexpensively simulates flow in moderately fractured reservoirs. It explicitly recognizes fractures separately from rock matrix. In NFFLOW fracture flow is proportional to the pressure gradient along the fracture, and flow in the rock matrix is determined by Darcys Law. The two flow mechanisms are coupled through the pressure gradient between a fracture and its adjacent rock matrix. Presented is a promising change to NFFLOW that allows for flow across a rock matrix block.

  14. Published New Reservoir Proved Revision Revision New Field Discoveries

    Gasoline and Diesel Fuel Update (EIA)

    Total natural gas proved reserves, reserves changes, and production, wet after lease separation, 2014 billion cubic feet Published New Reservoir Proved Revision Revision New Field Discoveries Estimated Proved Reserves Adjustments Increases Decreases Sales Acquisitions Extensions Discoveries in Old Fields Production Reserves State and subdivision 12/31/13 (+,-) (+) (-) (-) (+) (+) (+) (+) (-) 12/31/14 Alaska 7,383 -25 268 690 167 195 146 0 0 305 6,805 Lower 48 States 346,611 4,930 55,060 53,654

  15. Published New Reservoir Proved Revision Revision New Field Discoveries

    Gasoline and Diesel Fuel Update (EIA)

    Nonassociated natural gas proved reserves, reserves changes, and production, wet after lease separation, 2014 billion cubic feet Published New Reservoir Proved Revision Revision New Field Discoveries Estimated Proved Reserves Adjustments Increases Decreases Sales Acquisitions Extensions Discoveries in Old Fields Production Reserves State and Subdivision 12/31/13 (+,-) (+) (-) (-) (+) (+) (+) (+) (-) 12/31/14 Alaska 955 -24 89 137 0 34 138 0 0 101 954 Lower 48 States 294,549 3,533 41,975 44,047

  16. Published New Reservoir Proved Revision Revision New Field Discoveries

    Gasoline and Diesel Fuel Update (EIA)

    Associated-dissolved natural gas proved reserves, reserves changes, and production, wet after lease separation, 2014 billion cubic feet Published New Reservoir Proved Revision Revision New Field Discoveries Estimated Proved Reserves Adjustments Increases Decreases Sales Acquisitions Extensions Discoveries in Old Fields Production Reserves State and Subdivision 12/31/13 (+,-) (+) (-) (-) (+) (+) (+) (+) (-) 12/31/14 Alaska 6,428 -1 179 553 167 161 8 0 0 204 5,851 Lower 48 States 52,062 1,397

  17. Mercury Speciation in Piscivorous Fish from Mining-impacted Reservoirs

    Broader source: All U.S. Department of Energy (DOE) Office Webpages (Extended Search)

    Mercury Speciation in Piscivorous Fish from Mining-impacted Reservoirs Mercury toxicity generates environmental concerns in diverse aquatic systems because methylmercury enters the water column in diverse ways then biomagnifies through food webs. At the apex of many freshwater food webs, piscivorous fish can then extend that trophic transfer and potential for neurotoxicity to wildlife and humans. Mining activities, particularly those associated with the San Francisco Bay region, can generate

  18. Field development options for a waterflooded heavy-oil reservoir

    SciTech Connect (OSTI)

    Kasraie, M. ); Sammon, P.H. ); Jespersen, P.J. )

    1993-09-01

    Battrum Unit 4 is a moderately heavy-oil reservoir in Saskatchewan producing under waterflood from a thin sand. This paper describes a history match of previous field behavior and systematically analyzes through the use of numerical simulation the potential benefits to production of further waterflooding (with and without infill drilling), steamflooding, and horizontal drilling. It is found that the remaining oil recovery potential of a steamflood with horizontal well is significantly higher than that of any of the waterflood options.

  19. A Parallel Stochastic Framework for Reservoir Characterization and History Matching

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Thomas, Sunil G.; Klie, Hector M.; Rodriguez, Adolfo A.; Wheeler, Mary F.

    2011-01-01

    The spatial distribution of parameters that characterize the subsurface is never known to any reasonable level of accuracy required to solve the governing PDEs of multiphase flow or species transport through porous media. This paper presents a numerically cheap, yet efficient, accurate and parallel framework to estimate reservoir parameters, for example, medium permeability, using sensor information from measurements of the solution variables such as phase pressures, phase concentrations, fluxes, and seismic and well log data. Numerical results are presented to demonstrate the method.

  20. Geothermal Reservoir Temperatures in Southeastern Idaho using Multicomponent Geothermometry

    SciTech Connect (OSTI)

    Neupane, Ghanashyam; Mattson, Earl D.; McLing, Travis L.; Palmer, Carl D.; Smith, Robert W.; Wood, Thomas R.; Podgorney, Robert K.

    2015-03-01

    Southeastern Idaho exhibits numerous warm springs, warm water from shallow wells, and hot water within oil and gas test wells that indicate a potential for geothermal development in the area. Although the area exhibits several thermal expressions, the measured geothermal gradients vary substantially (19 61 C/km) within this area, potentially suggesting a redistribution of heat in the overlying ground water from deeper geothermal reservoirs. We have estimated reservoir temperatures from measured water compositions using an inverse modeling technique (Reservoir Temperature Estimator, RTEst) that calculates the temperature at which multiple minerals are simultaneously at equilibrium while explicitly accounting for the possible loss of volatile constituents (e.g., CO2), boiling and/or water mixing. Compositions of a selected group of thermal waters representing southeastern Idaho hot/warm springs and wells were used for the development of temperature estimates. The temperature estimates in the the region varied from moderately warm (59 C) to over 175 C. Specifically, hot springs near Preston, Idaho resulted in the highest temperature estimates in the region.