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Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


1

Property:SanyalTempWellhead | Open Energy Information  

Open Energy Info (EERE)

SanyalTempWellhead SanyalTempWellhead Jump to: navigation, search Property Name SanyalTempWellhead Property Type Page Description see Sanyal_Temperature_Classification Allows Values Extremely Low Temperature;Very Low Temperature;Low Temperature;Moderate Temperature;High Temperature;Ultra High Temperature;Steam Field Pages using the property "SanyalTempWellhead" Showing 25 pages using this property. A Amedee Geothermal Area + Extremely Low Temperature + B Beowawe Hot Springs Geothermal Area + Moderate Temperature + Blue Mountain Geothermal Area + Moderate Temperature + Brady Hot Springs Geothermal Area + Low Temperature + C Chena Geothermal Area + Extremely Low Temperature + Coso Geothermal Area + High Temperature + D Desert Peak Geothermal Area + Moderate Temperature +

2

Property:SanyalTempReservoir | Open Energy Information  

Open Energy Info (EERE)

SanyalTempReservoir SanyalTempReservoir Jump to: navigation, search Property Name SanyalTempReservoir Property Type Page Description see Sanyal_Temperature_Classification Allows Values Extremely Low Temperature;Very Low Temperature;Low Temperature;Moderate Temperature;High Temperature;Ultra High Temperature;Steam Field Pages using the property "SanyalTempReservoir" Showing 16 pages using this property. A Amedee Geothermal Area + Very Low Temperature + B Beowawe Hot Springs Geothermal Area + Moderate Temperature + Blue Mountain Geothermal Area + High Temperature + C Chena Geothermal Area + Very Low Temperature + D Desert Peak Geothermal Area + Moderate Temperature + K Kilauea East Rift Geothermal Area + High Temperature + L Lightning Dock Geothermal Area + High Temperature +

3

Property:MeanReservoirTemp | Open Energy Information  

Open Energy Info (EERE)

MeanReservoirTemp MeanReservoirTemp Jump to: navigation, search Property Name MeanReservoirTemp Property Type Temperature Description Mean estimated reservoir temperature at location based on the USGS 2008 Geothermal Resource Assessment if the United States Pages using the property "MeanReservoirTemp" Showing 25 pages using this property. (previous 25) (next 25) A Abraham Hot Springs Geothermal Area + 363.15 K90 °C 194 °F 653.67 °R + Adak Geothermal Area + 428.15 K155 °C 311 °F 770.67 °R + Akun Strait Geothermal Area + 353.15 K80 °C 176 °F 635.67 °R + Akutan Fumaroles Geothermal Area + 523.15 K250 °C 482 °F 941.67 °R + Alvord Hot Springs Geothermal Area + 408.15 K135 °C 275 °F 734.67 °R + Amedee Geothermal Area + 388.15 K115 °C 239 °F 698.67 °R + Arrowhead Hot Springs Geothermal Area + 388.15 K115 °C

4

Natural Gas Wellhead Prices  

U.S. Energy Information Administration (EIA)

Slide 19 of 27. Price: Wellhead. Natural gas wellhead prices are projected to move up 5 percent this winter, averaging about $2.28 per Mcf during this ...

5

Natural Gas Wellhead Price  

Annual Energy Outlook 2012 (EIA)

Wellhead Price Marketed Production Period: Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By:...

6

Natural Gas Wellhead Price  

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

Quantity of Production Imputed Wellhead Value Wellhead Price Marketed Production Period: Monthly Annual 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 2007 2008 2009 2010 2011 2012 View History U.S. 6.25 7.97 3.67 4.48 3.95 2.66 1922-2012 Alabama 7.44 9.65 4.32 4.46 1967-2010 Alaska 5.63 7.39 2.93 3.17 1967-2010 Arizona 5.98 7.09 3.19 4.11 1967-2010 Arkansas 6.61 8.72 3.43 3.84 1967-2010 California 6.62 8.38 3.96 4.87 1967-2010 Colorado 4.57 6.94 3.21 3.96 1967-2010 Florida NA NA NA NA 1967-2010 Illinois NA NA NA NA 1967-2010 Indiana 5.78 7.58 4.05 4.13 1967-2010

7

Subsea wellhead connector  

SciTech Connect

A pipe connector is described especially suitable for connecting a marine riser to a subsea wellhead. The connector consists of: (a) an annular connector body; (b) means for attaching the connector body to a marine riser; and (c) lockdown screw assemblies extending through radial ports in the connector body, each of the screw assemblies comprising: (1) a lockdown dog; (2) a lockdwon screw movably secured to its respective port in the connector body, the lockdwon screw having a central bore and a counterbore communicating therewith; (3) a dog retainer secured to the lockdown dog and slidably extending through the central bore of the lockdown screw, the dog retainer being bolt-shaped with a shank and head, the shank extending through the bore and the head residing in the counterbore; and (4) a spring system between the lockdown dog and the lockdown screw to bias the dog from the screw.

Coffey, W.M.

1986-08-19T23:59:59.000Z

8

Wellhead prices | OpenEI  

Open Energy Info (EERE)

Wellhead prices Wellhead prices Dataset Summary Description This dataset comes from the Energy Information Administration (EIA), and is part of the 2011 Annual Energy Outlook Report (AEO2011). This dataset is table 133, and contains only the reference case. The data is broken down into Production, lower 48 onshore and lower 48 offshore. Source EIA Date Released April 26th, 2011 (3 years ago) Date Updated Unknown Keywords 2011 AEO EIA Natural Gas Wellhead prices Data application/vnd.ms-excel icon AEO2011: Lower 48 Natural Gas Production and Wellhead Prices by Supply Region- Reference Case (xls, 59.1 KiB) Quality Metrics Level of Review Peer Reviewed Comment Temporal and Spatial Coverage Frequency Annually Time Period 2008-2035 License License Open Data Commons Public Domain Dedication and Licence (PDDL)

9

Wellhead Price Dollars  

Gasoline and Diesel Fuel Update (EIA)

.00 .00 0.50 1.00 1.50 2.00 2.50 3.00 0 20 40 60 80 100 1966 1976 1986 1996 Wellhead Price Dollars per Thousand Cubic Feet Dollars per Thousand Cubic Meters 0 0.5 1 1.5 2 2.5 3 0 10 20 30 40 50 60 70 80 Trillion Cubic Feet Billion Cubic Meters 1966 1976 1986 1996 Net Imports 0 0.2 0.4 0.6 0.8 0 -0.2 -0.4 -0.6 0 10 20 0 -10 -20 Trillion Cubic Feet Billion Cubic Meters 1966 1976 1986 1996 Net Additions to Storage Millions 0 5 10 15 20 25 0 100 200 300 400 500 600 700 Trillion Cubic Feet Billion Cubic Meters Dry Production 1966 1976 1986 1996 Sources: 1960-1975: Bureau of Mines, Minerals Yearbook, "Natural Gas" chapter. 1976-1978: Energy Information Administration (EIA), Energy Data Reports, Natural Gas Annual. 1979: EIA, Natural Gas Production and Consumption, 1979. 1980-1994: EIA, Form EIA-176, "Annual Report of Natural and Supplemental Gas Supply and Disposition"; Forms

10

Utah Quantity of Production Associated with Reported Wellhead...  

Annual Energy Outlook 2012 (EIA)

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Utah Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Decade...

11

Missouri Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Missouri Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

12

Tennessee Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Tennessee Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

13

Illinois Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Illinois Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

14

Arizona Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Arizona Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

15

Florida Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Florida Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

16

Kansas Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Kansas Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

17

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

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

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...

18

Maryland Quantity of Production Associated with Reported Wellhead...  

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

Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet) Maryland Quantity of Production Associated with Reported Wellhead Value (Million Cubic Feet)...

19

South Dakota Natural Gas Wellhead Price (Dollars per Thousand...  

Annual Energy Outlook 2012 (EIA)

View History: Annual Download Data (XLS File) South Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet) South Dakota Natural Gas Wellhead Price (Dollars per...

20

Natural Gas Wellhead Price - Energy Information Administration  

U.S. Energy Information Administration (EIA)

Natural Gas Wellhead Value and Marketed Production ... Pennsylvania: NA: NA: NA: NA : 1967-2010: South Dakota: 7.22: 7.94: NA: NA : 1979-2010: Tennessee: 6.63: 8.85 ...

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


21

Control instrumentation for wellheads and mud-kill systems. [Indonesia  

SciTech Connect

This paper describes the instrumentation and control systems used on the wellheads and mud-kill systems at the Mobil Oil Arun natural gas field, situated onshore in the province of Aceh, North Sumatra, Indonesia. The reservoir is a carbonate reef containing an estimated 15 Tcf (0.42 X 10/sup 12/ m/sup 3/) gas at approximately 7,000 psig (48 263 kPa) and 360/sup 0/F (182/sup 0/C). The wellstream from the field is separated into natural gas, condensate liquid, and water. The gas and condensate are then shipped through separate pipelines to the Arun liquefied natural gas (LNG) facility at Lho' Seumawe, about 40 mi (25 km) away on the northeastern coast of Sumatra. After liquefaction the LNG is shipped by tanker to Japan. The field was discovered in 1971 and became operational in 1977. The LNG delivery contract complied with the Japanese calls for regular delivery; thus continuity of supply to the LNG plant was of paramount importance for meeting transportation and supply schedules. Two actual blowouts in the Arun field have provided valuable experience in evaluating both equipment and systems in terms of design, reliability, and application for this type of field service. This paper concentrates on the design and installation of the control systems associated with the wellhead and mud-kill systems and highlights the problems encountered during the past five years.

Giles, A.J.

1983-08-01T23:59:59.000Z

22

-Injection Technology -Geothermal Reservoir Engineering  

E-Print Network (OSTI)

.A. Hsieh 1e$ Pressure Buildup Monitoring of the Krafla Geothermal Field, . . . . . . . . 1'1 Xceland - 0 Initial Chemical and Reservoir Conditions at Lo6 Azufres Wellhead Power Plant Startup - P. Kruger, LSGP-TR-92 - Injection Technology - Geothermal Reservoir Engineering Research at Stanford Principal

Stanford University

23

Troubleshooting natural gas processing: Wellhead to transmission  

Science Conference Proceedings (OSTI)

This book describes practical, day-to-day problems of natural gas handling. This book combines field experience with technical principles on natural gas production treating and transmission. This volume is dominated by illustrative case histories and rules of thumb. The book also provides a checklist of distillation problems which is a summary of causes and cures of the problems encountered in the fractionation of propane, butane and natural gasoline. A glossary of terms used in natural gas transmission is another good part of this book. The author has avoided complex mechanical details in favor of simple line drawings. Among the topics discussed are; wellhead pressure and gas flow, vapor-liquid separation at the wellhead, wellhead compression, corrosion in gathering systems, gas sweetening using amines, sulfur recovery, dehydration, centrifugal gas compression, reciprocal gas compression, hydrates, gas cooling and condensate recovery.

Lieberman, N.

1987-01-01T23:59:59.000Z

24

California Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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

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...

25

Pennsylvania Natural Gas Wellhead Price (Dollars per Thousand...  

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...

26

California Imputed Wellhead Value of Marketed Production (Cost...  

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

Imputed Wellhead Value of Marketed Production (Cost) California Imputed Wellhead Value of Marketed Production (Cost) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7...

27

Arizona Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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

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...

28

Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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...

29

Illinois Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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

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...

30

Tennessee Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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...

31

Florida Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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

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...

32

North Dakota Natural Gas Wellhead Price (Dollars per Thousand...  

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...

33

Oregon Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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...

34

Nebraska Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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

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...

35

New Mexico Imputed Wellhead Value of Marketed Production (Cost...  

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

Imputed Wellhead Value of Marketed Production (Cost) New Mexico Imputed Wellhead Value of Marketed Production (Cost) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7...

36

Methane extraction from geopressured-geothermal brine at wellhead conditions  

DOE Green Energy (OSTI)

Disposal of geopressured-geothermal brine effluents by injection is expected to be costly, even into shallow aquifers. If injection into the production reservoir becomes necessary to maintain productivity and to minimize subsidence, the injection pumping costs can become overwhelming. An option aimed at reducing injection pump operating costs is to maintain a higher than normal pressure at the production wellhead to reduce the injection pumping load. The crucial element, however, is that a significant portion of CH/sub 4/ remains in solution and must be recovered in order for the pressure maintenance option to be cost effective. A laboratory and field test capability has been established, and several methods for extracting dissolved CH/sub 4/ at high temperature and pressure are being evaluated. Solvent extraction and use of hydraulic motors or turbines coupled to CH/sub 4/ recovery systems are the leading candidate methods.

Quong, R.; Owen, L.B.; Locke, F.E.; Otto, C.H.; Netherton, R.; Lorensen, L.E.

1980-05-29T23:59:59.000Z

37

AcuTemp Expands as Appliances Become More Energy Efficient |...  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

AcuTemp Expands as Appliances Become More Energy Efficient AcuTemp Expands as Appliances Become More Energy Efficient August 9, 2010 - 11:50am Addthis AcuTemp received a 900,000...

38

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

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

ame","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","Nevada Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","9...

39

,"North Dakota Natural Gas Wellhead Price (Dollars per Thousand...  

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

Of Series","Frequency","Latest Data for" ,"Data 1","North Dakota Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","9...

40

,"West Virginia Natural Gas Wellhead Price (Dollars per Thousand...  

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

Of Series","Frequency","Latest Data for" ,"Data 1","West Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","9...

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


41

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

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

Of Series","Frequency","Latest Data for" ,"Data 1","Virginia Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","9...

42

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

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

Of Series","Frequency","Latest Data for" ,"Data 1","New York Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010 ,"Release Date:","9...

43

,"New Mexico Natural Gas Wellhead Price (Dollars per Thousand...  

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

Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","New Mexico Natural Gas Wellhead Price (Dollars per Thousand Cubic Feet)",1,"Annual",2010...

44

South Dakota Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value South Dakota Natural Gas Wellhead Value and Marketed Production

45

Indiana Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value Indiana Natural Gas Wellhead Value and Marketed Production

46

Wellhead Protection Area Act (Nebraska) | Department of Energy  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Wellhead Protection Area Act (Nebraska) Wellhead Protection Area Act (Nebraska) Wellhead Protection Area Act (Nebraska) < Back Eligibility Agricultural Commercial Construction Developer Fed. Government Fuel Distributor General Public/Consumer Industrial Installer/Contractor Institutional Investor-Owned Utility Local Government Low-Income Residential Multi-Family Residential Municipal/Public Utility Nonprofit Residential Retail Supplier Rural Electric Cooperative Schools State/Provincial Govt Systems Integrator Transportation Tribal Government Utility Savings Category Alternative Fuel Vehicles Hydrogen & Fuel Cells Buying & Making Electricity Water Solar Wind Program Info State Nebraska Program Type Environmental Regulations Provider Nebraska Department of Environmental Quality This section regulates activities which can occur on or below the land

47

STATUS OF GEOTHERMAL RESERVOIR ENGINEERING RESEARCH PROJECTS SUPPORTED BY USDOE/DIVISION OF GEOTHERMAL ENERGY  

E-Print Network (OSTI)

the authors. Wairakei geothermal field: Lawrence BerkeleyR. C. , Evaluation of potential geothermal well-head and17, "S"r78" for use in geothermal reservoir 25 p. (LBL-

Howard, J.H.

2011-01-01T23:59:59.000Z

48

West Virginia Natural Gas Wellhead Price (Dollars per ...  

U.S. Energy Information Administration (EIA)

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 ...

49

AEO2011: Lower 48 Natural Gas Production and Wellhead Prices...  

Open Energy Info (EERE)

Natural Gas Production and Wellhead Prices by Supply Region

50

Nevada Natural Gas Wellhead Price (Dollars per Thousand Cubic...  

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

Nevada 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 2000's -- NA NA NA 2010's NA - No...

51

Tempe Transportation Division: LNG Turbine Hybrid Electric Buses  

SciTech Connect

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

Not Available

2002-02-01T23:59:59.000Z

52

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Utah Natural Gas Prices Natural Gas Wellhead

53

West Virginia Quantity of Production Associated with Reported Wellhead  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value West Virginia Natural Gas Wellhead Value and Marketed

54

Virginia Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value Virginia Natural Gas Wellhead Value and Marketed Production

55

Oregon Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value Oregon Natural Gas Wellhead Value and Marketed Production

56

Pennsylvania Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value Pennsylvania Natural Gas Wellhead Value and Marketed

57

Nebraska Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead Value Nebraska Natural Gas Wellhead Value and Marketed Production

58

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Ohio Natural Gas Prices Natural Gas Wellhead

59

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Texas Natural Gas Prices Natural Gas Wellhead

60

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Maryland Natural Gas Prices Natural Gas Wellhead

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


61

Alabama Underground Storage Tank And Wellhead Protection Act (Alabama) |  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Alabama Underground Storage Tank And Wellhead Protection Act Alabama Underground Storage Tank And Wellhead Protection Act (Alabama) Alabama Underground Storage Tank And Wellhead Protection Act (Alabama) < Back Eligibility Commercial Construction Industrial Municipal/Public Utility Savings Category Buying & Making Electricity Water Home Weatherization Program Info State Alabama Program Type Environmental Regulations The department, acting through the commission, is authorized to promulgate rules and regulations governing underground storage tanks and is authorized to seek the approval of the United States Environmental Protection Agency to operate the state underground storage tank program in lieu of the federal program. In addition to specific authorities provided by this chapter, the department is authorized, acting through the commission, to

62

Blackfoot Reservoir Geothermal Area | Open Energy Information  

Open Energy Info (EERE)

Blackfoot Reservoir Geothermal Area Blackfoot Reservoir Geothermal Area (Redirected from Blackfoot Reservoir Area) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Geothermal Resource Area: Blackfoot Reservoir Geothermal Area Contents 1 Area Overview 2 History and Infrastructure 3 Regulatory and Environmental Issues 4 Exploration History 5 Well Field Description 6 Geology of the Area 7 Geofluid Geochemistry 8 NEPA-Related Analyses (0) 9 Exploration Activities (3) 10 References Area Overview Geothermal Area Profile Location: Idaho Exploration Region: Northern Basin and Range Geothermal Region GEA Development Phase: 2008 USGS Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure Operating Power Plants: 0

63

Tempe, Arizona: Energy Resources | Open Energy Information  

Open Energy Info (EERE)

Tempe, Arizona: Energy Resources Tempe, Arizona: Energy Resources Jump to: navigation, search Equivalent URI DBpedia Coordinates 33.414768°, -111.9093095° Loading map... {"minzoom":false,"mappingservice":"googlemaps3","type":"ROADMAP","zoom":14,"types":["ROADMAP","SATELLITE","HYBRID","TERRAIN"],"geoservice":"google","maxzoom":false,"width":"600px","height":"350px","centre":false,"title":"","label":"","icon":"","visitedicon":"","lines":[],"polygons":[],"circles":[],"rectangles":[],"copycoords":false,"static":false,"wmsoverlay":"","layers":[],"controls":["pan","zoom","type","scale","streetview"],"zoomstyle":"DEFAULT","typestyle":"DEFAULT","autoinfowindows":false,"kml":[],"gkml":[],"fusiontables":[],"resizable":false,"tilt":0,"kmlrezoom":false,"poi":true,"imageoverlays":[],"markercluster":false,"searchmarkers":"","locations":[{"text":"","title":"","link":null,"lat":33.414768,"lon":-111.9093095,"alt":0,"address":"","icon":"","group":"","inlineLabel":"","visitedicon":""}]}

64

Michigan Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 153,130 159,400 2010's 151,886 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

65

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Indiana Natural Gas Prices

66

Arkansas Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 2010's 936,600 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

67

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Arkansas Natural Gas Prices

68

A Tool For Assessing Contamination Risk in Wellhead Protection Areas  

Science Conference Proceedings (OSTI)

Facility siting and operation restrictions aimed at groundwater protection can potentially affect a wide range of industrial activities located in or near designated Wellhead Protection Areas (WHPAs). This study provides a simple tool -- EPRI's Health Standard Exceedance (HSE) index -- for assessing the potential groundwater contamination risk associated with organic compounds in a WHPA.

2000-11-29T23:59:59.000Z

69

Alaska Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Alaska Quantity of Production Associated with Reported Wellhead Value (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 189,896 197,735 200,871 199,616 413,667 502,887 494,323 368,344 337,359 397,077 2010's 316,546 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

70

Alabama Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Alabama Quantity of Production Associated with Reported Wellhead Value (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 521,215 376,241 370,753 348,722 304,212 285,237 274,176 259,062 246,747 225,666 2010's 212,769 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

71

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Louisiana Natural Gas Prices

72

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Colorado Natural Gas Prices

73

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Kansas Natural Gas Prices

74

Montana Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 87,539 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

75

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Michigan Natural Gas Prices

76

North Dakota Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

77

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Kentucky Natural Gas Prices

78

California Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 323,864 328,778 309,399 293,691 276,520 274,817 278,933 268,016 263,107 241,916 2010's 251,559 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

79

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Alabama Natural Gas Prices

80

Mississippi Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 97,258 2010's 73,721 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


81

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Wyoming Natural Gas Prices

82

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Oklahoma Natural Gas Prices

83

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Montana Natural Gas Prices

84

Colorado Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 1,280,638 1,436,203 1,409,172 2010's 1,548,576 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

85

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Alaska Natural Gas Prices

86

Kentucky Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

87

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price Mississippi Natural Gas Prices

88

Ohio Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 88,824 2010's 78,122 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

89

New York Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages: Quantity of Natural Gas Production Associated with Reported Wellhead

90

Windows Vista vs Ubuntu Installaci: procs, temps i problemes  

E-Print Network (OSTI)

Windows Vista vs Ubuntu #12;Índex Instal·lació: procés, temps i problemes Aplicacions Temps d·lació: procés, temps i problemes Procés d'instal·lació de Windows Vista Procés d'instal·lació de Linux Ubuntu 7.04 Temps total Problemes #12;Instal·lació Windows Vista (I) #12;Instal·lació Windows Vista (II

Politècnica de Catalunya, Universitat

91

Blackfoot Reservoir Geothermal Area | Open Energy Information  

Open Energy Info (EERE)

Blackfoot Reservoir Geothermal Area Blackfoot Reservoir Geothermal Area Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Geothermal Resource Area: Blackfoot Reservoir Geothermal Area Contents 1 Area Overview 2 History and Infrastructure 3 Regulatory and Environmental Issues 4 Exploration History 5 Well Field Description 6 Geology of the Area 7 Geofluid Geochemistry 8 NEPA-Related Analyses (0) 9 Exploration Activities (3) 10 References Area Overview Geothermal Area Profile Location: Idaho Exploration Region: Northern Basin and Range Geothermal Region GEA Development Phase: 2008 USGS Resource Estimate Mean Reservoir Temp: Estimated Reservoir Volume: Mean Capacity: Click "Edit With Form" above to add content History and Infrastructure Operating Power Plants: 0 No geothermal plants listed.

92

Riser gas eliminators reduce wellhead pressures on offshore satellite platforms  

Science Conference Proceedings (OSTI)

Riser gas eliminators installed on the liquid export risers of five Gulf of Mexico platforms have significantly reduced wellhead pressure by releasing trapped gas. Wellhead pressures on the platforms have been reduced an average of 50 psi. The gas eliminators have been installed on lines in which the oil has undergone primary separation (gas/liquid) only and is being transported to another platform with separator pressure. Gas eliminators should be effective on other liquid lines in water depths of 50 ft or more, especially those with low velocities. The riser gas eliminator is an inverted steam trap installed at the top of the riser. The inverted steam trap has an internal float that allows the gas to vent through an orifice. The vented gas can be used for fuel supply or routed through the vent system.

Conner, S.L.

1994-03-01T23:59:59.000Z

93

Table 7b. Natural Gas Wellhead Prices, Projected vs. Actual  

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

b. Natural Gas Wellhead Prices, Projected vs. Actual" b. Natural Gas Wellhead Prices, Projected vs. Actual" "Projected Price in Nominal Dollars" " (nominal dollars per thousand cubic feet)" ,1993,1994,1995,1996,1997,1998,1999,2000,2001,2002,2003,2004,2005,2006,2007,2008,2009,2010,2011 "AEO 1994",1.983258692,2.124739238,2.26534793,2.409252566,2.585728477,2.727400662,2.854942053,2.980927152,3.13861755,3.345819536,3.591100993,3.849544702,4.184279801,4.510016556,4.915074503,5.29147351,5.56022351,5.960471854 "AEO 1995",,1.891706924,1.998384058,1.952818035,2.064227053,2.152302174,2.400016103,2.569033816,2.897681159,3.160088567,3.556344605,3.869033816,4.267391304,4.561932367,4.848599034,5.157246377,5.413405797,5.660917874 "AEO 1996",,,1.630674532,1.740334763,1.862956911,1.9915856,2.10351261,2.194934146,2.287655669,2.378991658,2.476043002,2.589847464,2.717610782,2.836870306,2.967124845,3.117719429,3.294003735,3.485657428,3.728419409

94

Modular Wellhead Binary Power System: Preliminary Design Results  

Science Conference Proceedings (OSTI)

To provide the utility industry with effective and flexible binary-cycle power plants, preliminary engineering analyses were conducted on a standardized design being developed for a modular wellhead binary-cycle power system. This design will use heat sources, such as geothermal or waste heat, in the 300-450 degrees F temperature range and will meet utility requirements for small geothermal resource capacity needs.

1990-09-13T23:59:59.000Z

95

Wyoming Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 1,811,992 1,916,238 2,116,818 2,239,778 2010's 2,318,486 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014 Referring Pages:

96

New Mexico Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 1,578,773 1,571,920 1,562,754 1,495,615 895,675 1,370,727 2010's 1,287,399 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014

97

Oklahoma Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 1,531,657 1,584,905 1,571,615 1,683,563 1,589,871 1,765,988 1,621,316 2010's 1,408,061 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014

98

Texas Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 5,186,213 5,271,306 5,539,052 5,993,702 6,454,249 7,483,842 7,623,747 2010's 7,470,752 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 12/12/2013 Next Release Date: 1/7/2014

99

Louisiana Quantity of Production Associated with Reported Wellhead Value  

Gasoline and Diesel Fuel Update (EIA)

Quantity of Production Associated with Reported Wellhead Value (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 1,350,399 1,357,366 1,296,048 1,361,119 1,275,806 1,292,478 1,449,809 2010's 2,140,525 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014

100

HGP-A wellhead generator proof-of-feasibility project  

SciTech Connect

The HGP-A Wellhead Generator Proof-of-Feasibility Project consists of a nominal 3 Megawatt geothermal steam turbine electric power generating facility, the first geothermal power plant in Hawaii. The plant is being constructed as a research and development project to evaluate geothermal steam as a viable resource to be considered for larger commercial electric power generating stations in Hawaii. The project facilities include a turbine building, with a contiguous service area for plant operations and maintenance, visitor center, and the power plant equipment.

1978-11-03T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


101

U.S. Natural Gas Wellhead Value and Marketed Production  

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

Area: U.S. Federal Offshore Gulf of Mexico Alabama Alaska Arizona Arkansas California Colorado Florida Illinois Indiana Kansas Kentucky Louisiana Maryland Michigan Mississippi Missouri Montana Nebraska Nevada New Mexico New York North Dakota Ohio Oklahoma Oregon Pennsylvania South Dakota Tennessee Texas Utah Virginia West Virginia Wyoming Period: Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes Show Data By: Data Series Area 2007 2008 2009 2010 2011 2012 View History Quantity of Production Associated with Reported Wellhead Value (Million Cubic Ft.)

102

Property:AvgGeoFluidTemp | Open Energy Information  

Open Energy Info (EERE)

AvgGeoFluidTemp AvgGeoFluidTemp Jump to: navigation, search Property Name AvgGeoFluidTemp Property Type Temperature Description Average temperature of geofluid in a geothermal area. Subproperties This property has the following 15 subproperties: B Beowawe Hot Springs Geothermal Area Brady Hot Springs Geothermal Area C Chena Geothermal Area D Desert Peak Geothermal Area E East Mesa Geothermal Area G Geysers Geothermal Area H Heber Geothermal Area L Lightning Dock Geothermal Area R Roosevelt Hot Springs Geothermal Area S Salton Sea Geothermal Area San Emidio Desert Geothermal Area S cont. Soda Lake Geothermal Area Steamboat Springs Geothermal Area Stillwater Geothermal Area W Wabuska Hot Springs Geothermal Area Pages using the property "AvgGeoFluidTemp" Showing 10 pages using this property.

103

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

DOE Data Explorer (OSTI)

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

Maria Cadeddu

104

Table 7a. Natural Gas Wellhead Prices, Projected vs. Actual  

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

a. Natural Gas Wellhead Prices, Projected vs. Actual" a. Natural Gas Wellhead Prices, Projected vs. Actual" "Projected Price in Constant Dollars" " (constant dollars per thousand cubic feet in ""dollar year"" specific to each AEO)" ,"AEO Dollar Year",1993,1994,1995,1996,1997,1998,1999,2000,2001,2002,2003,2004,2005,2006,2007,2008,2009,2010,2011 "AEO 1994",1992,1.9399,2.029,2.1099,2.1899,2.29,2.35,2.39,2.42,2.47,2.55,2.65,2.75,2.89,3.01,3.17,3.3,3.35,3.47 "AEO 1995",1993,,1.85,1.899,1.81,1.87,1.8999,2.06,2.14,2.34,2.47,2.69,2.83,3.02,3.12,3.21,3.3,3.35,3.39 "AEO 1996",1994,,,1.597672343,1.665446997,1.74129355,1.815978527,1.866241336,1.892736554,1.913619637,1.928664207,1.943216205,1.964540124,1.988652706,2.003382921,2.024799585,2.056392431,2.099974155,2.14731431,2.218094587

105

Imputed Wellhead Value of Natural Gas Marketed Production  

Gasoline and Diesel Fuel Update (EIA)

Thousand Dollars) 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 2006 2007 2008 2009 2010 2011 View History U.S. 124,074,399 1989-2006 Alabama 2,167,627 2,010,736 2,489,704 1,020,599 994,688 0 1989-2011 Alaska 2,576,028 2,439,193 2,944,546 1,163,554 1,185,249 0 1989-2011 Arizona 3,484 3,913 3,710 2,269 753 0 1989-2011 Arkansas 1,739,324 1,782,837 3,891,921 2,330,692 3,556,609 0 1989-2011 California 2,038,915 2,033,054 2,483,126 1,095,181 1,396,916 0 1989-2011 Colorado 7,361,709 5,680,388 9,642,428 4,812,014 6,250,380 0 1989-2011

106

GASCAP: Wellhead Gas Productive Capacity Model documentation, June 1993  

SciTech Connect

The Wellhead Gas Productive Capacity Model (GASCAP) has been developed by EIA to provide a historical analysis of the monthly productive capacity of natural gas at the wellhead and a projection of monthly capacity for 2 years into the future. The impact of drilling, oil and gas price assumptions, and demand on gas productive capacity are examined. Both gas-well gas and oil-well gas are included. Oil-well gas productive capacity is estimated separately and then combined with the gas-well gas productive capacity. This documentation report provides a general overview of the GASCAP Model, describes the underlying data base, provides technical descriptions of the component models, diagrams the system and subsystem flow, describes the equations, and provides definitions and sources of all variables used in the system. This documentation report is provided to enable users of EIA projections generated by GASCAP to understand the underlying procedures used and to replicate the models and solutions. This report should be of particular interest to those in the Congress, Federal and State agencies, industry, and the academic community, who are concerned with the future availability of natural gas.

Not Available

1993-07-01T23:59:59.000Z

107

Table 7a. Natural Gas Wellhead Prices, Projected vs. Actual  

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

a. Natural Gas Wellhead Prices, Projected vs. Actual a. Natural Gas Wellhead Prices, Projected vs. Actual Projected Price in Constant Dollars (constant dollars per thousand cubic feet in "dollar year" specific to each AEO) AEO Dollar Year 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 AEO 1994 1992 1.94 2.03 2.11 2.19 2.29 2.35 2.39 2.42 2.47 2.55 2.65 2.75 2.89 3.01 3.17 3.30 3.35 3.47 AEO 1995 1993 1.85 1.90 1.81 1.87 1.90 2.06 2.14 2.34 2.47 2.69 2.83 3.02 3.12 3.21 3.30 3.35 3.39 AEO 1996 1994 1.60 1.67 1.74 1.82 1.87 1.89 1.91 1.93 1.94 1.96 1.99 2.00 2.02 2.06 2.10 2.15 2.22

108

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sin_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sin_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

109

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sil_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sil_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

110

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_stx_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_stx_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

111

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sor_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sor_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

112

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_smi_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_smi_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

113

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sar_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sar_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

114

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sne_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sne_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

115

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sut_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sut_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

116

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sky_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sky_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

117

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sco_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sco_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

118

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_smo_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_smo_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

119

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sal_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sal_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

120

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_smd_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_smd_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


121

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sok_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sok_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

122

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_spa_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_spa_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

123

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_saz_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_saz_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

124

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sfl_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sfl_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

125

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_ssd_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_ssd_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

126

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sms_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sms_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

127

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sla_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sla_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

128

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sak_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sak_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

129

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_soh_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_soh_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

130

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sca_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sca_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

131

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_swy_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_swy_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

132

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_sks_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_sks_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

133

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_smt_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_smt_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

134

,"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)" 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:","12/12/2013" ,"Next Release Date:","1/7/2014" ,"Excel File Name:","na1140_stn_3a.xls" ,"Available from Web Page:","http://tonto.eia.gov/dnav/ng/hist/na1140_stn_3a.htm" ,"Source:","Energy Information Administration" ,"For Help, Contact:","infoctr@eia.doe.gov"

135

AEO2011: Lower 48 Crude Oil Production and Wellhead Prices by...  

Open Energy Info (EERE)

Lower 48 Crude Oil Production and Wellhead Prices by Supply Region

136

AEO2011: Lower 48 Natural Gas Production and Wellhead Prices by Supply  

Open Energy Info (EERE)

Natural Gas Production and Wellhead Prices by Supply Natural Gas Production and Wellhead Prices by Supply Region Dataset Summary Description This dataset comes from the Energy Information Administration (EIA), and is part of the 2011 Annual Energy Outlook Report (AEO2011). This dataset is table 133, and contains only the reference case. The data is broken down into Production, lower 48 onshore and lower 48 offshore. Source EIA Date Released April 26th, 2011 (3 years ago) Date Updated Unknown Keywords 2011 AEO EIA Natural Gas Wellhead prices Data application/vnd.ms-excel icon AEO2011: Lower 48 Natural Gas Production and Wellhead Prices by Supply Region- Reference Case (xls, 59.1 KiB) Quality Metrics Level of Review Peer Reviewed Comment Temporal and Spatial Coverage Frequency Annually Time Period 2008-2035 License

137

Table 7b. Natural Gas Wellhead Prices, Projected vs. Actual  

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

b. Natural Gas Wellhead Prices, Projected vs. Actual b. Natural Gas Wellhead Prices, Projected vs. Actual Projected Price in Nominal Dollars (nominal dollars per thousand cubic feet) 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 AEO 1994 1.98 2.12 2.27 2.41 2.59 2.73 2.85 2.98 3.14 3.35 3.59 3.85 4.18 4.51 4.92 5.29 5.56 5.96 AEO 1995 1.89 2.00 1.95 2.06 2.15 2.40 2.57 2.90 3.16 3.56 3.87 4.27 4.56 4.85 5.16 5.41 5.66 AEO 1996 1.63 1.74 1.86 1.99 2.10 2.19 2.29 2.38 2.48 2.59 2.72 2.84 2.97 3.12 3.29 3.49 3.73 AEO 1997 2.03 1.82 1.90 1.99 2.06 2.13 2.21 2.32 2.43 2.54 2.65 2.77 2.88 3.00 3.11 3.24 AEO 1998 2.30 2.20 2.26 2.31 2.38 2.44 2.52 2.60 2.69 2.79 2.93 3.06 3.20 3.35 3.48 AEO 1999 1.98 2.15 2.20 2.32 2.43 2.53 2.63 2.76 2.90 3.02 3.12 3.23 3.35 3.47

138

Table 8. Natural Gas Wellhead Prices, Projected vs. Actual  

Gasoline and Diesel Fuel Update (EIA)

Natural Gas Wellhead Prices, Projected vs. Actual Natural Gas Wellhead Prices, Projected vs. Actual (current dollars per thousand cubic feet) 1985 1986 1987 1988 1989 1990 1991 1992 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 AEO 1982 4.32 5.47 6.67 7.51 8.04 8.57 AEO 1983 2.93 3.11 3.46 3.93 4.56 5.26 12.74 AEO 1984 2.77 2.90 3.21 3.63 4.13 4.79 9.33 AEO 1985 2.60 2.61 2.66 2.71 2.94 3.35 3.85 4.46 5.10 5.83 6.67 AEO 1986 1.73 1.96 2.29 2.54 2.81 3.15 3.73 4.34 5.06 5.90 6.79 7.70 8.62 9.68 10.80 AEO 1987 1.83 1.95 2.11 2.28 2.49 2.72 3.08 3.51 4.07 7.54 AEO 1989* 1.62 1.70 1.91 2.13 2.58 3.04 3.48 3.93 4.76 5.23 5.80 6.43 6.98 AEO 1990 1.78 1.88 2.93 5.36 9.2 AEO 1991 1.77 1.90 2.11 2.30 2.42 2.51 2.60 2.74 2.91 3.29 3.75 4.31 5.07 5.77 6.45 7.29 8.09 8.94 9.62 10.27 AEO 1992 1.69 1.85 2.03 2.15 2.35 2.51 2.74 3.01 3.40 3.81 4.24 4.74 5.25 5.78 6.37 6.89 7.50 8.15 9.05 AEO 1993 1.85 1.94 2.09 2.30

139

AcuTemp Expands as Appliances Become More Energy Efficient | Department of  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

AcuTemp Expands as Appliances Become More Energy Efficient AcuTemp Expands as Appliances Become More Energy Efficient AcuTemp Expands as Appliances Become More Energy Efficient August 9, 2010 - 11:50am Addthis 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 courtesy of AcuTemp | Stephen Graff Former Writer & editor for Energy Empowers, EERE "[Refrigerator manufactures] are searching for technologies," says Doug

140

PROCEEDINGS, Thirty-Fifth Workshop on Geothermal Reservoir Engineering Stanford University, Stanford, California, February 1-3, 2010  

E-Print Network (OSTI)

and is in a 250-260 °C range. Under reservoir temperature and pressure conditions the geothermal fluid plant to 15 MWe (GB1+GB2) and was put into service in 2003. The consequent increase in geothermal fluid the geothermal fluid supplied to GB1. Over this period, the well-head pressures were monitored for each well

Stanford University

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


141

AEO2011: Lower 48 Crude Oil Production and Wellhead Prices by Supply Region  

Open Energy Info (EERE)

Crude Oil Production and Wellhead Prices by Supply Region Crude Oil Production and Wellhead Prices by Supply Region Dataset Summary Description This dataset comes from the Energy Information Administration (EIA), and is part of the 2011 Annual Energy Outlook Report (AEO2011). This dataset is table 132, and contains only the reference case. The data is broken down into Production, lower 48 onshore and lower 48 offshore. Source EIA Date Released April 26th, 2011 (3 years ago) Date Updated Unknown Keywords 2011 AEO crude oil EIA prices Data application/vnd.ms-excel icon AEO2011: Lower 48 Crude Oil Production and Wellhead Prices by Supply Region- Reference Case (xls, 54.9 KiB) Quality Metrics Level of Review Peer Reviewed Comment Temporal and Spatial Coverage Frequency Annually Time Period 2008-2035 License License Open Data Commons Public Domain Dedication and Licence (PDDL)

142

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

SciTech Connect

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.

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

1983-12-06T23:59:59.000Z

143

HDR reservoir flow impedance and potentials for impedance reduction  

DOE Green Energy (OSTI)

The data from flow tests which employed two different production zones in a well at Fenton Hill indicates the flow impedance of a wellbore zone damaged by rapid depressurization was altered, possibly by pressure spallation, which appears to have mechanically propped the joint apertures of outlet flow paths intersecting the altered wellbore. The rapid depressurization and subsequent flow test data derived from the damaged well has led to the hypothesis that pressure spallation and the resultant mechanical propping of outlet flow paths reduced the outlet flow impedance of the damaged wellbore. Furthermore, transient pressure data shows the largest pressure drop between the injection and production wellheads occurs near the production wellbore, so lowering the outlet impedance by increasing the apertures of outlet flow paths will have the greatest effect on reducing the overall reservoir impedance. Fenton Hill data also reveals that increasing the overall reservoir pressure dilates the apertures of flow paths, which likewise serves to reduce the reservoir impedance. Data suggests that either pressure dilating the wellbore connected joints with high production wellhead pressure, or mechanically propping open the outlet flow paths will increase the near-wellbore permeability. Finally, a new method for calculating and comparing near-wellbore outlet impedances has been developed. Further modeling, experimentation, and engineered reservoir modifications, such as pressure dilation and mechanical propping, hold considerable potential for significantly improving the productivity of HDR reservoirs.

DuTeau, R.; Brown, D.

1993-06-01T23:59:59.000Z

144

HDR reservoir flow impedance and potentials for impedance reduction  

DOE Green Energy (OSTI)

The data from flow tests which employed two different production zones in a well at Fenton Hill indicates the flow impedance of a wellbore zone damaged by rapid depressurization was altered, possibly by pressure spallation, which appears to have mechanically propped the joint apertures of outlet flow paths intersecting the altered wellbore. The rapid depressurization and subsequent flow test data derived from the damaged well has led to the hypothesis that pressure spallation and the resultant mechanical propping of outlet flow paths reduced the outlet flow impedance of the damaged wellbore. Furthermore, transient pressure data shows the largest pressure drop between the injection and production wellheads occurs near the production wellbore, so lowering the outlet impedance by increasing the apertures of outlet flow paths will have the greatest effect on reducing the overall reservoir impedance. Fenton Hill data also reveals that increasing the overall reservoir pressure dilates the apertures of flow paths, which likewise serves to reduce the reservoir impedance. Data suggests that either pressure dilating the wellbore connected joints with high production wellhead pressure, or mechanically propping open the outlet flow paths will increase the near-wellbore permeability. Finally, a new method for calculating and comparing near-wellbore outlet impedances has been developed. Further modeling, experimentation, and engineered reservoir modifications, such as pressure dilation and mechanical propping, hold considerable potential for significantly improving the productivity of HDR reservoirs.

DuTeau, R.; Brown, D.

1993-01-01T23:59:59.000Z

145

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price New York Natural Gas Prices

146

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

Gasoline and Diesel Fuel Update (EIA)

Wellhead Price (Dollars per Thousand Cubic Feet) 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 Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 1/7/2014 Next Release Date: 1/31/2014 Referring Pages: Natural Gas Wellhead Price New Mexico Natural Gas Prices

147

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

SciTech Connect

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.

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

1984-07-31T23:59:59.000Z

148

Residential Prices Do Not Reflect the Volatility Seen in Wellhead Prices  

Gasoline and Diesel Fuel Update (EIA)

5 5 Notes: A key concern about the level of current wellhead prices is the impact on consumers, especially residential and small-volume commercial customers Using monthly average prices for residential customers and daily Henry Hub spot prices for the past 4 winters: significant price fluctuations are apparent at the Henry Hub, but residential prices respond relatively less. The major reasons for the lesser response in residential prices are: Gas supplies to residential customers generally are arranged prior to delivery, and agreed price terms, while flexible, generally do not fully reflect contemporaneous wellhead price shifts Gas commodity charges are a fraction of the delivery price for small customers-averaging about 33 percent during the heating season. Costs of

149

Market survey of geothermal wellhead power generation systems. Final report, March 1978  

DOE Green Energy (OSTI)

The purpose of this study was to assess the market potential for a portable geothermal wellhead power conversion device (1-10 MW generating capacity). Major study objectives included identifying the most promising applications for such a system, the potential impediments confronting their industrialization, and the various government actions needed to overcome these impediments. The heart of the study was a series of structured interviews with key decision-making individuals in the various disciplines of the geothermal community. In addition, some technical and economic analyses of a candidate system were performed to support the feasibility of the basic concept.

Leeds, M.W.; Evensizer, J.

1979-04-01T23:59:59.000Z

150

Evolution of the Cerro Prieto reservoirs under exploitation  

DOE Green Energy (OSTI)

The Cerro Prieto Geothermal field of Baja California (Mexico) has been under commercial production to generate electricity since 1973. Over the years, the large amount of Geothermal fluids extracted (at present about 12,000 tons per hour) to supply steam to the power plants has resulted in a reduction of pressures, changes in reservoir processes, and increased flow of cooler groundwater into the geothermal system. The groundwater recharging the reservoir moves horizontally through permeable layers, as well as vertically through permeable fault zones. In addition, the supply of deep hot waters has continued unabated, and perhaps has increased as reservoir pressure decreased. Since 1989, this natural fluid recharge has been supplemented by injection which presently amounts to about 20% of the fluid produced. Changes in the chemical and physical characteristics of the reservoir fluids due to the drop in pressures and the inflow of cooler groundwaters and injectate have been detected on the basis of wellhead data. These changes point to reservoir processes like local boiling, phase segregation, steam condensation, mixing and dilution. Finally, the study identified areas where fluids are entering the reservoir, as well as indicated their source (i.e. natural Groundwater recharge versus injectate) and established the controlling geologic structures.

Truesdell, A.H.; Lippmann, M.J. [Lawrence Berkeley National Lab., CA (United States); Puente, H.G. [Comision Federal de Electricidad, Mexicali (Mexico)

1997-07-01T23:59:59.000Z

151

Balloon-borne sounding system (BBSS): Vaisala-processed winds, press., temp, and RH  

DOE Data Explorer (OSTI)

Balloon-borne sounding system (BBSS): Vaisala-processed winds, press., temp, and RH. The balloon-borne sounding system (SONDE) provides in situ measurements (vertical profiles) of both the thermodynamic state of the atmosphere, and the wind speed and direction.

Coulter,Richard; Ritsche,Michael

152

Coalbed Methane Procduced Water Treatment Using Gas Hydrate Formation at the Wellhead  

Science Conference Proceedings (OSTI)

Water associated with coalbed methane (CBM) production is a significant and costly process waste stream, and economic treatment and/or disposal of this water is often the key to successful and profitable CBM development. In the past decade, advances have been made in the treatment of CBM produced water. However, produced water generally must be transported in some fashion to a centralized treatment and/or disposal facility. The cost of transporting this water, whether through the development of a water distribution system or by truck, is often greater than the cost of treatment or disposal. To address this economic issue, BC Technologies (BCT), in collaboration with Oak Ridge National Laboratory (ORNL) and International Petroleum Environmental Consortium (IPEC), proposed developing a mechanical unit that could be used to treat CBM produced water by forming gas hydrates at the wellhead. This process involves creating a gas hydrate, washing it and then disassociating hydrate into water and gas molecules. The application of this technology results in three process streams: purified water, brine, and gas. The purified water can be discharged or reused for a variety of beneficial purposes and the smaller brine can be disposed of using conventional strategies. The overall objectives of this research are to develop a new treatment method for produced water where it could be purified directly at the wellhead, to determine the effectiveness of hydrate formation for the treatment of produced water with proof of concept laboratory experiments, to design a prototype-scale injector and test it in the laboratory under realistic wellhead conditions, and to demonstrate the technology under field conditions. By treating the water on-site, producers could substantially reduce their surface handling costs and economically remove impurities to a quality that would support beneficial use. Batch bench-scale experiments of the hydrate formation process and research conducted at ORNL confirmed the feasibility of the process. However, researchers at BCT were unable to develop equipment suitable for continuous operation and demonstration of the process in the field was not attempted. The significant achievements of the research area: Bench-scale batch results using carbon dioxide indicate >40% of the feed water to the hydrate formation reactor was converted to hydrate in a single pass; The batch results also indicate >23% of the feed water to the hydrate formation reactor (>50% of the hydrate formed) was converted to purified water of a quality suitable for discharge; Continuous discharge and collection of hydrates was achieved at atmospheric pressure. Continuous hydrate formation and collection at atmospheric conditions was the most significant achievement and preliminary economics indicate that if the unit could be made operable, it is potentially economic. However, the inability to continuously separate the hydrate melt fraction left the concept not ready for field demonstration and the project was terminated after Phase Two research.

BC Technologies

2009-12-30T23:59:59.000Z

153

Property:Building/MeanAnnualTempAtSite | Open Energy Information  

Open Energy Info (EERE)

MeanAnnualTempAtSite MeanAnnualTempAtSite Jump to: navigation, search This is a property of type Number. Mean annual temperature at the site1 Pages using the property "Building/MeanAnnualTempAtSite" Showing 25 pages using this property. (previous 25) (next 25) S Sweden Building 05K0001 + 6.6 + Sweden Building 05K0002 + 6.6 + Sweden Building 05K0003 + 6.6 + Sweden Building 05K0004 + 6.6 + Sweden Building 05K0005 + 6.6 + Sweden Building 05K0006 + 6.6 + Sweden Building 05K0007 + 6.6 + Sweden Building 05K0008 + 6.6 + Sweden Building 05K0009 + 6.6 + Sweden Building 05K0010 + 6.6 + Sweden Building 05K0011 + 6.6 + Sweden Building 05K0012 + 6.6 + Sweden Building 05K0013 + 6.6 + Sweden Building 05K0014 + 6.6 + Sweden Building 05K0015 + 6.6 + Sweden Building 05K0016 + 6.6 +

154

Property:Building/MeanAnnualTempCalculationPeriod | Open Energy Information  

Open Energy Info (EERE)

MeanAnnualTempCalculationPeriod MeanAnnualTempCalculationPeriod Jump to: navigation, search This is a property of type Number. Mean annual temperature during the calculation period Pages using the property "Building/MeanAnnualTempCalculationPeriod" Showing 25 pages using this property. (previous 25) (next 25) S Sweden Building 05K0001 + 7.6 + Sweden Building 05K0002 + 7.6 + Sweden Building 05K0003 + 7.142 + Sweden Building 05K0004 + 7.6 + Sweden Building 05K0005 + 7.733 + Sweden Building 05K0006 + 7.733 + Sweden Building 05K0007 + 7.733 + Sweden Building 05K0008 + 7.733 + Sweden Building 05K0009 + 7.733 + Sweden Building 05K0010 + 7.733 + Sweden Building 05K0011 + 7.733 + Sweden Building 05K0012 + 7.6 + Sweden Building 05K0013 + 7.733 + Sweden Building 05K0014 + 7.083 +

155

File:TempCampApplicationWorksheet 2011.pdf | Open Energy Information  

Open Energy Info (EERE)

TempCampApplicationWorksheet 2011.pdf TempCampApplicationWorksheet 2011.pdf Jump to: navigation, search File File history File usage File:TempCampApplicationWorksheet 2011.pdf Size of this preview: 463 × 599 pixels. Other resolution: 464 × 600 pixels. Go to page 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 Go! next page → next page → Full resolution ‎(1,275 × 1,650 pixels, file size: 450 KB, MIME type: application/pdf, 30 pages) File history Click on a date/time to view the file as it appeared at that time. Date/Time Thumbnail Dimensions User Comment current 17:40, 29 October 2012 Thumbnail for version as of 17:40, 29 October 2012 1,275 × 1,650, 30 pages (450 KB) Dklein2012 (Talk | contribs) You cannot overwrite this file. Edit this file using an external application (See the setup

156

Turn Down the Temp, But Don't Let Your Pipes Freeze! | Department of Energy  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Turn Down the Temp, But Don't Let Your Pipes Freeze! Turn Down the Temp, But Don't Let Your Pipes Freeze! Turn Down the Temp, But Don't Let Your Pipes Freeze! November 16, 2009 - 7:42pm Addthis Elizabeth Spencer Communicator, National Renewable Energy Laboratory I can be a strange and particular person at times. So here is a post wherein I will be strangely particular about setting the temperature on your thermostat. You often hear about how you should turn down the thermostat to save energy, and there are a slew of helpful ideas on the subject. I'm sure you've heard some of them right here on this blog: You can turn the thermostat down when you're out, when you're sleeping, and you can save about 1% on your energy bill per degree you turn your thermostat down! This is all very exciting. But before you go crazy with turning down the thermostat really low, I'd

157

Geothermal reservoir assessment: Northern Basin and Range Province, Stillwater prospect, Churchill County, Nevada. Final report, April 1979-July 1981  

DOE Green Energy (OSTI)

Union Oil Company of California drilled two exploratory geothermal wells in the Stillwater geothermal prospect area in northwestern Nevada to obtain new subsurface data for inclusion in the geothermal reservoir assessment program. Existing data from prior investigations, which included the drilling of four earlier deep temperature gradient wells in the Stillwater area, was also provided. The two wells were drilled to total depths of 6946 ft and 10,014 ft with no significant drilling problems. A maximum reservoir temperature of 353 F was measured at 9950 ft. The most productive well flow tested at a rate of 152,000 lbs/hr with a wellhead temperature of 252 F and pressure of 20 psig. Based upon current economics, the Stillwater geothermal prospect is considered to be subcommercial for the generation of electrical power. This synopsis of the exploratory drilling activities and results contains summary drilling, geologic, and reservoir information from two exploratory geothermal wells.

Ash, D.L.; Dondanville, R.F.; Gulati, M.S.

1981-08-01T23:59:59.000Z

158

Stimulation and reservoir engineering of geothermal resources. Second annual report, July 1, 1978-September 30, 1979  

DOE Green Energy (OSTI)

Individual projects are grouped under four main areas of study: energy extraction, bench-scale flow experiments, radon tracer techniques, and well test analysis. The energy extraction experiments concern the efficiency with which the in-place heat and fluids can be produced in the most economical manner. The bench-scale flow experiments cover the results of three models used to examine the properties of flow through porous media at elevated temperature and pressures. Random tracer techniques describe accelerated efforts to field test several geothermal reservoirs by both transient and transect test procedures. The well test analysis section describes several new developments: analysis of earth-tide effects, pressure transient analysis of multilayered systems, interference testing with storage and skin effects, determination of steam-water relative permeability from wellhead data, well test analysis for wells produced at constant pressure, the parallelepiped model, slug test DST analysis, and pressure transient behavior in naturally fractured reservoirs. (MHR)

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

1979-09-01T23:59:59.000Z

159

Business benefits of wellhead protection. Case studies: Dayton, Ohio; Xenia, Ohio; and Pekin, Illinois. Source water protection business and economic series No. 1  

SciTech Connect

Business participation is a critical factor for three succesful local wellhead and ground water protection programs in Dayton and Xenia, Ohio and Pekin, Illinois. They offer three different wellhead and ground water protection models but show common themes for business involvement and benefits. Bottom-line benefits highlighted by several companies include: process changes that saved operating costs not previously anticipated; maintaining water quality that keep industrial water treatment costs down; and knowing the exact storage location of chemicals which keep emergency response costs down and allowed better management of existing chemical stocks. All companies indicated that being within the wellhead protection area (WHPA) caused them to be conscious of chemical use and thereby reduced liability from releases through better chemical management. Early involvement by business minimized local regulatory burden and promoted education and protective activities at the same time.

Job, C.A.

1995-10-27T23:59:59.000Z

160

Status of Norris Reservoir  

DOE Green Energy (OSTI)

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.

Not Available

1990-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


161

Status of Wheeler Reservoir  

DOE Green Energy (OSTI)

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.

Not Available

1990-09-01T23:59:59.000Z

162

Status of Cherokee Reservoir  

DOE Green Energy (OSTI)

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.

Not Available

1990-08-01T23:59:59.000Z

163

HGP-A Wellhead Generator Proof-of-Feasibility Project (Well Test) at HGP-A Site Puna, Hawaii. Volume II. Technical Specifications  

DOE Green Energy (OSTI)

The purpose of this project is to provide and secure the well test system complete and ready for use. The project comprises the construction of a chemical treatment system (including caustic and hydrogen peroxide handling systems), new condensate piping, wellhead steam piping modifications, ancillary electrical systems and equipment, instrumentation, site improvements and utilities distribution.

None

1979-03-01T23:59:59.000Z

164

Hydrothermal Reservoirs | Open Energy Information  

Open Energy Info (EERE)

Hydrothermal Reservoirs Hydrothermal Reservoirs Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Hydrothermal Reservoirs Dictionary.png Hydrothermal Reservoir: Hydrothermal Reservoirs are underground zones of porous rock containing hot water and steam, and can be naturally occurring or human-made. Other definitions:Wikipedia Reegle Natural, shallow hydrothermal reservoirs naturally occurring hot water reservoirs, typically found at depths of less than 5 km below the Earth's surface where there is heat, water and a permeable material (permeability in rock formations results from fractures, joints, pores, etc.). Often, hydrothermal reservoirs have an overlying layer that bounds the reservoir and also serves as a thermal insulator, allowing greater heat retention. If hydrothermal reservoirs

165

Geothermal reservoir technology  

DOE Green Energy (OSTI)

A status report on Lawrence Berkeley Laboratory's Reservoir Technology projects under DOE's Hydrothermal Research Subprogram is presented. During FY 1985 significant accomplishments were made in developing and evaluating methods for (1) describing geothermal systems and processes; (2) predicting reservoir changes; (3) mapping faults and fractures; and (4) field data analysis. In addition, LBL assisted DOE in establishing the research needs of the geothermal industry in the area of Reservoir Technology. 15 refs., 5 figs.

Lippmann, M.J.

1985-09-01T23:59:59.000Z

166

Geothermal Reservoir Dynamics - TOUGHREACT  

E-Print Network (OSTI)

Swelling in a Fractured Geothermal Reservoir, presented atTHC) Modeling Based on Geothermal Field Data, Geothermics,and Silica Scaling in Geothermal Production-Injection Wells

2005-01-01T23:59:59.000Z

167

Geysers reservoir studies  

DOE Green Energy (OSTI)

LBL is conducting several research projects related to issues of interest to The Geysers operators, including those that deal with understanding the nature of vapor-dominated systems, measuring or inferring reservoir processes and parameters, and studying the effects of liquid injection. All of these topics are directly or indirectly relevant to the development of reservoir strategies aimed at stabilizing or increasing production rates of non-corrosive steam, low in non-condensable gases. Only reservoir engineering studies will be described here, since microearthquake and geochemical projects carried out by LBL or its contractors are discussed in accompanying papers. Three reservoir engineering studies will be described in some detail, that is: (a) Modeling studies of heat transfer and phase distribution in two-phase geothermal reservoirs; (b) Numerical modeling studies of Geysers injection experiments; and (c) Development of a dual-porosity model to calculate mass flow between rock matrix blocks and neighboring fractures.

Bodvarsson, G.S.; Lippmann, M.J.; Pruess, K.

1993-04-01T23:59:59.000Z

168

Reservoir characterization of Pennsylvanian sandstone reservoirs. Final report  

SciTech Connect

This final report summarizes the progress during the three years of a project on Reservoir Characterization of Pennsylvanian Sandstone Reservoirs. The report is divided into three sections: (i) reservoir description; (ii) scale-up procedures; (iii) outcrop investigation. The first section describes the methods by which a reservoir can be described in three dimensions. The next step in reservoir description is to scale up reservoir properties for flow simulation. The second section addresses the issue of scale-up of reservoir properties once the spatial descriptions of properties are created. The last section describes the investigation of an outcrop.

Kelkar, M.

1995-02-01T23:59:59.000Z

169

Reservoir Protection (Oklahoma)  

Energy.gov (U.S. Department of Energy (DOE))

The Oklahoma Water Resource Board has the authority to make rules for the control of sanitation on all property located within any reservoir or drainage basin. The Board works with the Department...

170

Geology and Reservoir Simulation  

NLE Websites -- All DOE Office Websites (Extended Search)

Service: 1-800-553-7681 Geology and Reservoir Simulation Background Natural gas from shale is becoming ever more recognized as an abundant and economically viable fuel in the...

171

Session: Reservoir Technology  

DOE Green Energy (OSTI)

This session at the Geothermal Energy Program Review X: Geothermal Energy and the Utility Market consisted of five papers: ''Reservoir Technology'' by Joel L. Renner; ''LBL Research on the Geysers: Conceptual Models, Simulation and Monitoring Studies'' by Gudmundur S. Bodvarsson; ''Geothermal Geophysical Research in Electrical Methods at UURI'' by Philip E. Wannamaker; ''Optimizing Reinjection Strategy at Palinpinon, Philippines Based on Chloride Data'' by Roland N. Horne; ''TETRAD Reservoir Simulation'' by G. Michael Shook

Renner, Joel L.; Bodvarsson, Gudmundur S.; Wannamaker, Philip E.; Horne, Roland N.; Shook, G. Michael

1992-01-01T23:59:59.000Z

172

Preliminary study of discharge characteristics of slim holes compared to production wells in liquid-dominated geothermal reservoirs  

DOE Green Energy (OSTI)

There is current interest in using slim holes for geothermal exploration and reservoir assessment. A major question that must be addressed is whether results from flow or injection testing of slim holes can be scaled to predict large diameter production well performance. This brief report describes a preliminary examination of this question from a purely theoretical point of view. The WELBOR computer program was used to perform a series of calculations of the steady flow of fluid up geothermal boreholes of various diameters at various discharge rates. Starting with prescribed bottomhole conditions (pressure, enthalpy), the WELBOR code integrates the equations expressing conservation of mass, momentum and energy (together with fluid constitutive properties obtained from the steam tables) upwards towards the wellhead using numerical techniques. This results in computed profiles of conditions (pressure, temperature, steam volume fraction, etc.) as functions of depth within the flowing well, and also in a forecast of wellhead conditions (pressure, temperature, enthalpy, etc.). From these results, scaling rules are developed and discussed.

Pritchett, J.W. [S-Cubed, La Jolla, CA (United States)

1993-06-01T23:59:59.000Z

173

A reservoir management study of a mature oil field  

E-Print Network (OSTI)

An integrated geological, petrophysical and reservoir engineering review was performed for a mature, producing oil field. Like many older fields, important data are missing or were not collected. The techniques used in this thesis may be applied to other mature oil fields to make sound engineering and business decisions. I interpreted the geological structure and stratigaphy of the salt dome oil field. Structure, isopach and cross-sectional maps were constructed. Depositional environments of the producing horizons were identified. Potential for additional reserves was assessed. Well logs, core data, water resistivity and produced fluids data were analyzed. Average values of porosity, permeability, and oil saturation were determined for the field. Potential reserves behind casing were identified. Based on the revised geological and petrophysical data, the original oil in place was estimated from volumetrics to be 42.3 MMSTB. Cumulative oil production was determined for the first time since 1963. The field, individual reservoir, and individual well production performances were reviewed. Initial production histories of more than 220 wells were documented. I collected wellhead fluid samples and analyzed oil gravity and viscosity. Other fluid properties were estimated from correlations. Pressure data from the field was collated and analyzed. Primary production mechanisms and aquifer influx were estimated by reviewing early producing history and performing material balance calculations. Water influx was calculated. The performances of analogous salt dome reservoirs were compared to that of the field. All past well stimulations were reviewed and suggestions made for better implementation. Water injection in the field was reviewed. Problems of implementation and reservoir response were identified. The best areas in the field for waterflooding were identified and analyzed with an analytical model. Based on existing development, the oil ultimate recovery is estimated to be 14.4 MMSTB or 34.0 % of original oil in place. To determine whether oil recovery can be improved, incremental, after tax economic analysis was applied to several schemes. Infill drilling, hydraulic fracturing and waterflooding were analyzed. A course of action to maximize economic return is outlined for the field. Hydraulic fracturing appears to be the most viable technique to improve oil production from the field.

Peruzzi, Tave

1995-01-01T23:59:59.000Z

174

GEOTHERMAL RESERVOIR SIMULATIONS WITH SHAFT79  

E-Print Network (OSTI)

that well blocks must geothermal reservoir studies, paperof Califomia. LBL-10066 GEOTHERMAL RESERVOIR SIMULATIONSbe presented at the Fifth Geothermal Reservoir Engineering

Pruess, Karsten

2012-01-01T23:59:59.000Z

175

Real natural gas reservoir data Vs. natural gas reservoir models  

Science Conference Proceedings (OSTI)

The gas reservoir per se model is an exceedingly simple model of a natural gas reservoir designed to develop the physical relationship between ultimate recovery and rate(s) of withdrawal for production regulation policy assessment. To be responsive, ...

Ellis A. Monash; John Lohrenz

1979-03-01T23:59:59.000Z

176

Reinjection into geothermal reservoirs  

DOE Green Energy (OSTI)

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)

Bodvarsson, G.S.; Stefansson, V.

1987-08-01T23:59:59.000Z

177

Geothermal reservoir assessment case study, Northern Basin and Range Province. Final Report, 1 October 1978-30 September 1979  

DOE Green Energy (OSTI)

Campbell E No. 2 well in the Humboldt House geothermal field in central Pershing County, Nevada was drilled to a depth of 8061 ft in order to confirm the existence of a commercial reservoir. This well offsets the field discovery well which was drilled in 1977 and completed to a depth of only 1835 ft. Desert Peak B-23-1 well was likewise drilled in order to help evaluate a previously discovered geothermal field located in northwestern Churchill County, Nevada. The Desert Peak B-23-1 well was drilled to a depth of 9641 ft as compared to the deepest of three earlier wells drilled to 7662 ft. The drilling and completion of both these wells are described, including the daily drilling reports, drill bit records, descriptions of the casing and cementing programs, drilling fluid descriptions including methods of combating lost circulation, wellhead equipment descriptions, and logging programs.

Not Available

1979-10-01T23:59:59.000Z

178

Sourcebook on the production of electricity from geothermal energy. Chapter 2 (draft). Resource characteristics: reservoirs, wellheads and delivery systems. Part 3. Analysis of the flow in the reservoir: well system. [Includes glossary  

DOE Green Energy (OSTI)

This report is a preliminary version of material assembled for insertion in the Sourcebook on the Production of Electricity from Geothermal Energy currently being composed under ERDA (now DOE). An attempt has been made to develop the theory of the geothermal well in an ordered stepwise manner beginning from the three basic continuities and introducing each new idea systematically. A formal textbook approach is used.

Ryley, D.J.

1978-06-01T23:59:59.000Z

179

Geothermal reservoir assessment: Cove Fort-Sulphurdale Unit. Final report, September 1977-July 1979  

DOE Green Energy (OSTI)

Three exploratory geothermal wells were drilled in the Cove Fort-Sulphurdale geothermal resource area in southwestern Utah to obtain new subsurface data for inclusion in the US DOE's geothermal reservoir assessment program. Existing data from prior investigations which included the drilling of an earlier exploratory well at the Cove Fort-Sulphurdale area was also provided. Two of the wells were abandoned before reaching target depth because of severe lost circulation and hole sloughing problems. The two completed holes reached depths of 5221 ft. and 7735 ft., respectively, and a maximum reservoir temperature of 353/sup 0/F at 7320 ft. was measured. The deepest well flow was tested at the rate of 47,000 lbs/h with a wellhead temperature of 200/sup 0/F and pressure of 3 psig. Based upon current economics, the Cove Fort-Sulphurdale geothermal resource is considered to be sub-commercial for the generation of electrical power. A synopsis is given of the exploratory drilling activities and results containing summary drilling, testing, geologic and geochemical information from four exploratory geothermal wells.

Ash, D.L.; Dondanville, R.F.; Gulati, M.S.

1979-12-01T23:59:59.000Z

180

Status of Blue Ridge Reservoir  

DOE Green Energy (OSTI)

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 Blue Ridge 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 and data available, as well as interview with water resource professionals in various federal, state, and local agencies. Blue Ridge Reservoir is a single-purpose hydropower generating project. When consistent with this primary objective, the reservoir is also operated to benefit secondary objectives including water quality, recreation, fish and aquatic habitat, development of shoreline, aesthetic quality, and other public and private uses that support overall regional economic growth and development. 8 refs., 1 fig.

Not Available

1990-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


181

Natural Gas Wellhead Price  

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

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 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 2007 2008 2009 2010 2011 2012 View History U.S. 6.25 7.97 3.67 4.48 3.95 2.66 1922-2012 Alabama 7.44 9.65 4.32 4.46 1967-2010 Alaska 5.63 7.39 2.93 3.17 1967-2010 Arizona 5.98 7.09 3.19 4.11 1967-2010 Arkansas

182

Natural Gas Wellhead Price  

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

included in Prices Electric Power Price Period: Monthly Annual Download Series History Download Series History Definitions, Sources & Notes Definitions, Sources & Notes...

183

Natural Gas Wellhead Price  

Gasoline and Diesel Fuel Update (EIA)

Oklahoma 6.24 7.56 3.53 4.71 1967-2010 Oregon 5.27 5.33 4.00 4.92 1979-2010 Pennsylvania NA NA NA NA 1967-2010 South Dakota 7.22 7.94 NA NA 1979-2010 Tennessee 6.63 8.85...

184

Geothermal reservoir management  

DOE Green Energy (OSTI)

The optimal management of a hot water geothermal reservoir was considered. The physical system investigated includes a three-dimensional aquifer from which hot water is pumped and circulated through a heat exchanger. Heat removed from the geothermal fluid is transferred to a building complex or other facility for space heating. After passing through the heat exchanger, the (now cooled) geothermal fluid is reinjected into the aquifer. This cools the reservoir at a rate predicted by an expression relating pumping rate, time, and production hole temperature. The economic model proposed in the study maximizes discounted value of energy transferred across the heat exchanger minus the discounted cost of wells, equipment, and pumping energy. The real value of energy is assumed to increase at r percent per year. A major decision variable is the production or pumping rate (which is constant over the project life). Other decision variables in this optimization are production timing, reinjection temperature, and the economic life of the reservoir at the selected pumping rate. Results show that waiting time to production and production life increases as r increases and decreases as the discount rate increases. Production rate decreases as r increases and increases as the discount rate increases. The optimal injection temperature is very close to the temperature of the steam produced on the other side of the heat exchanger, and is virtually independent of r and the discount rate. Sensitivity of the decision variables to geohydrological parameters was also investigated. Initial aquifer temperature and permeability have a major influence on these variables, although aquifer porosity is of less importance. A penalty was considered for production delay after the lease is granted.

Scherer, C.R.; Golabi, K.

1978-02-01T23:59:59.000Z

185

Advanced reservoir simulation using soft computing  

Science Conference Proceedings (OSTI)

Reservoir simulation is a challenging problem for the oil and gas industry. A correctly calibrated reservoir simulator provides an effective tool for reservoir evaluation that can be used to obtain essential reservoir information. A long-standing problem ... Keywords: fuzzy control, history matching, parallel processing, reservoir simulation

G. Janoski; F.-S. Li; M. Pietrzyk; A. H. Sung; S.-H. Chang; R. B. Grigg

2000-06-01T23:59:59.000Z

186

Session 4: Geothermal Reservoir Definition  

DOE Green Energy (OSTI)

The study of geothermal reservoir behavior is presently in a state of change brought about by the discovery that reservoir heterogeneity--fractures in particular--is responsible for large scale effects during production. On the other hand, some parts of a reservoir, or some portions of its behavior. may be unaffected by fractures and behave, instead, as if the reservoir were a homogeneous porous medium. Drilling has for many years been guided by geologists prospecting for fractures (which have been recognized as the source of production), but until recently reservoir engineers have not studied the behavior of fractured systems under production. In the last three years research efforts, funded by the Department of Energy and others, have made significant progress in the study of fractures. The investigations into simulation of fracture flow, tracer analysis of fractured systems, and well test analysis of double porosity reservoirs are all advancing. However, presently we are at something of a conceptual impasse in defining a reservoir as fractured or porous. It seems likely that future directions will not continue to attempt to distinguish two separate reservoir types, but will focus instead on defining behavior types. That is, certain aspects of reservoir behavior may be considered to be generally of the porous medium type (for example, field wide decline), while others may be more frequently fracture type (for example, breakthrough of reinjected water). In short, our overall view of geothermal reservoir definition is becoming a little more complex, thereby better accommodating the complexities of the reservoirs themselves. Recent research results already enable us to understand some previously contradictory results, and recognition of the difficulties is encouraging for future progress in the correct direction.

Horne, Roland N.

1983-12-01T23:59:59.000Z

187

Reservoir Modeling for Production Management  

DOE Green Energy (OSTI)

For both petroleum and geothermal resources, many of the reservoirs are fracture dominated--rather than matrix-permeability controlled. For such reservoirs, a knowledge of the pressure-dependent permeability of the interconnected system of natural joints (i.e., pre-existing fractures) is critical to the efficient exploitation of the resource through proper pressure management. Our experience and that reported by others indicates that a reduction in the reservoir pressure sometimes leads to an overall reduction in production rate due to the ''pinching off'' of the joint network, rather than the anticipated increase in production rate. This effect occurs not just in the vicinity of the wellbore, where proppants are sometimes employed, but throughout much of the reservoir region. This follows from the fact that under certain circumstances, the decline in fracture permeability (or conductivity) with decreasing reservoir pressure exceeds the far-field reservoir ''drainage'' flow rate increase due to the increased pressure gradient. Further, a knowledge of the pressure-dependent joint permeability could aid in designing more appropriate secondary recovery strategies in petroleum reservoirs or reinjection procedures for geothermal reservoirs.

Brown, Donald W.

1989-03-21T23:59:59.000Z

188

Reservoir management using streamline simulation  

E-Print Network (OSTI)

Geostatistical techniques can generate fine-scale description of reservoir properties that honor a variety of available data. The differences among multiple geostatistical realizations indicate the presence of uncertainty due to the lack of information and sparsity of data. Quantifying this uncertainty in terms of reservoir performance forecast poses a major reservoir management challenge. One solution to this problem is flow simulation of a large number of these plausible reservoir descriptions. However, this approach is not feasible in practice because of the computational costs associated with multiple detailed flow simulations. Other major reservoir management challenges include the determination of the swept and unswept areas at a particular time of interest in the life of a reservoir. Until now, sweep efficiency correlations have generally been limited to homogeneous 2-D cases. Calculating volumetric sweep efficiency in a 3-D heterogeneous reservoir is difficult due to the inherent complexity of multiple layers and arbitrary well configurations. Identifying the swept and unswept areas is primarily important for making a decision on the infill locations. Most of the mature reservoirs all over the world are under waterflood. Managing a waterflood requires an understanding of how injection wells displace oil to producing wells. By quantifying the fluid movements, the displacement process can be actively managed. Areas that are not being swept can be developed, and inefficiencies, such as water cycling, can be removed. Conventional simulation provides general answers to almost all of these problems, however time constraint prohibits using a detailed model to capture complexities for each well. Three dimensional streamline simulation can meet most of these reservoir management challenges. Moreover use of fast streamline-based simulation technique offers significant potential in terms of computational efficiency. Its high performance simulation speed makes it well suited for describing flow characteristics for high resolution reservoir models and can be used on a routine basis to make effective and efficient reservoir management decisions. In this research, we extend the capability of streamline simulation as an efficient tool for reservoir management purposes. We show its application in terms of swept volume calculations, ranking of stochastic reservoir models, pattern rate allocation and reservoir performance forecasting under uncertainty.

Choudhary, Manoj Kumar

2000-01-01T23:59:59.000Z

189

Tertiary carbonate reservoirs in Indonesia  

Science Conference Proceedings (OSTI)

Hydrocarbon production from Tertiary carbonate reservoirs accounted for ca. 10% of daily Indonesian production at the beginning of 1978. Environmentally, the reservoirs appear as parts of reef complexes and high-energy carbonate deposits within basinal areas situated mainly in the back arc of the archipelago. Good porosities of the reservoirs are represented by vugular/moldic and intergranular porosity types. The reservoirs are capable of producing prolific amounts of hydrocarbons: production tests in Salawati-Irian Jaya reaches maximum values of 32,000 bpd, and in Arun-North Sumatra tests recorded 200 MMCF gas/day. Significant hydrocarbon accumulations are related to good reservoir rocks in carbonates deposited as patch reefs, pinnacle reefs, and platform complexes. Exploration efforts expand continuously within carbonate formations which are extensive horizontally as well as vertically in the Tertiary stratigraphic column.

Nayoan, G.A.S.; Arpandi; Siregar, M.

1981-01-01T23:59:59.000Z

190

Water resources review: Ocoee reservoirs, 1990  

DOE Green Energy (OSTI)

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.

Cox, J.P.

1990-08-01T23:59:59.000Z

191

NETL: Discrete Fracture Reservoir Simulation Software  

NLE Websites -- All DOE Office Websites (Extended Search)

Discrete Fracture Reservoir Simulation FRACGENNFFLOW Shale Gas Flow Simulation Shale Gas Flow Simulation FRACGENNFFLOW, a fractured reservoir modeling software developed by the...

192

ANNOTATED RESEARCH BIBLIOGRAPHY FOR GEOTHERMAL RESERVOIR ENGINEERING  

E-Print Network (OSTI)

Bibliography Definition of Geothermal Reservoir EngineeringDevelopment of Geothermal Reservoir Engineering. * 1.4 DataF i r s t Geopressured Geothermal Energy Conference. Austin,

Sudo!, G.A

2012-01-01T23:59:59.000Z

193

Data requirements and acquisition for reservoir characterization  

Science Conference Proceedings (OSTI)

This report outlines the types of data, data sources and measurement tools required for effective reservoir characterization, the data required for specific enhanced oil recovery (EOR) processes, and a discussion on the determination of the optimum data density for reservoir characterization and reservoir modeling. The two basic sources of data for reservoir characterization are data from the specific reservoir and data from analog reservoirs, outcrops, and modern environments. Reservoir data can be divided into three broad categories: (1) rock properties (the container) and (2) fluid properties (the contents) and (3)interaction between reservoir rock and fluid. Both static and dynamic measurements are required.

Jackson, S.; Chang, Ming Ming; Tham, Min

1993-03-01T23:59:59.000Z

194

Coal bed methane reservoir simulation studies.  

E-Print Network (OSTI)

??The purpose of this study is to perform simulation studies for a specific coal bed methane reservoir. First, the theory and reservoir engineering aspects of (more)

Karimi, Kaveh

2005-01-01T23:59:59.000Z

195

Greenhouse gas cycling in experimental boreal reservoirs.  

E-Print Network (OSTI)

??Hydroelectric reservoirs account for 59% of the installed electricity generating capacity in Canada and 26% in Ontario. Reservoirs also provide irrigation capacity, drinking water, and (more)

Venkiteswaran, Jason James

2009-01-01T23:59:59.000Z

196

ANALYSIS OF PRODUCTION DECLINE IN GEOTHERMAL RESERVOIRS  

E-Print Network (OSTI)

Petroleum Reservoirs. Geothermal Reservoirs IV. DATA1970, Superheating of Geothermal Steam, Proc. of the U.N.the Development & Utilization of Geothermal Resources, Pisa.

Zais, E.J.; Bodvarsson, G.

2008-01-01T23:59:59.000Z

197

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

Science Conference Proceedings (OSTI)

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.

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

2006-11-01T23:59:59.000Z

198

TEXAS A&M UNIVERSITY Reservoir Geophysics Program  

E-Print Network (OSTI)

includes applications to clastic reservoirs, heavy oil reservoirs, gas/oil shale, gas hydrates. Basic

199

Evaluation of the Fenton Hill Hot Dry Rock Geothermal Reservoir. Part I. Heat extraction performance and modeling. Part II. Flow characteristics and geochemistry. Part III. Reservoir characterization using acoustic techniques  

DOE Green Energy (OSTI)

On May 28, 1977, as the production well GT-2 at Fenton Hill was being redrilled along a planned trajectory, it intersected a low-impedance hydraulic fracture in direct communication with the injection well, EE-1. Thus, a necessary prerequisite for a full-scale test of the LASL Hot Dry Rock Concept, that of establishing a high flow rate between wells at low wellhead differential pressures, was satisified. Full-scale operation of the loop occurred for 75 days from January 27 to April 12, 1978. This test is referred to as Phase 1, Segment 2 and was designed to examine the thermal drawdown, flow characteristics, water losses, and fluid geochemistry of the system in detail. Results of these studies are the major topic of this paper which is divided into three separate parts covering first the heat extraction performance, second the flow characteristics and geochemistry and third the use of acoustic techniques to describe the geometry of the fracture system. In the third section, dual-well acoustic measurements used to detect fractures are described. These measurements were made using modified Dresser Atlas logging tools. Signals intersecting hydraulic fractures in the reservoir under both hydrostatic and pressurized conditions were simultaneously detected in both wells. Signal attenuation and characteristic waveforms can be used to describe the extent of fractured rock in the reservoir.

Murphy, H.D.; Grigsby, C.O.; Tester, J.W.; Albright, J.N.

1978-01-01T23:59:59.000Z

200

A reservoir management strategy for multilayered reservoirs in eastern Venezuela  

E-Print Network (OSTI)

A reservoir management strategy has been developed for a field located in eastern Venezuela. The field contains deep, high pressure, multilayer reservoirs. A thorough formation evaluation was accomplished using the log data, core data, PVT data, geologic data, well completion data and the production data. A reservoir simulation model was built to forecast reservoir performance for a variety of exploitation and well completion strategies. Reserve forecasts have been made using the reservoir model. The methodology applied in this research consists of eight tasks: 1) build a data base with existing data, 2) analyze the log and core data, 3) analyze the pressure and production data, 4) analyze the PVT data, 5) analyze the hydraulic fracture treatments, 6) build the reservoir model, 7) determine the possible reservoir management strategies, and 8) perform economic evaluations for the management strategies. While much of the data for the field studied was supplied by PDVSA, we did not receive all of the data we requested. For example, no pressure buildup data were available. When necessary, we used correlations to determine values for reservoir data that we were not supplied. In this research four formations were studied and characterized, determining porosity and permeability values. Also, fracture treatments were analyzed and a reservoir model was developed. Runs for black oil and volatile oil were performed. The results show that the upper zones are the most prospective areas, but fracture treatments must be performed to reduce the damage on the sand face. Lower formations (Cretaceous) have a lower permeability value, but high OOIP that justify performing fracture treatments and completing this zone. Economics were developed to support this conclusion. Optimum well spacing was calculated showing that 960 acres is the optimum well spacing, but also that 640 acres can be maintained for all the reservoirs and dual completions can be performed, first hydraulic fracturing and completing the Cretaceous formation, and then, completing any upper zone. Reservoir simulation results show that up to 31% of OOIP may be incrementally recovered by hydraulic fracturing the Cretaceous formation and 10 or less from the upper zones.

Espinel Diaz, Arnaldo Leopoldo

1998-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


201

Alternate Methods in Reservoir Simulation  

Science Conference Proceedings (OSTI)

As time progresses, more and more oil fields and reservoirs are reaching maturity; consequently, secondary and tertiary methods of oil recovery have become increasingly important in the petroleum industry. This significance has added to the industry's ...

Guadalupe I. Janoski; Andrew H. Sung

2001-05-01T23:59:59.000Z

202

Fracture characterization of multilayered reservoirs  

Science Conference Proceedings (OSTI)

Fracture treatment optimization techniques have been developed using Long-Spaced-Digital-Sonic (LSDS) log, pumpin-flowback, mini-frac, and downhole treating pressure data. These analysis techniques have been successfully applied in massive hydraulic fracturing (MHF) of ''tight gas'' wells. Massive hydraulic fracture stimulations have been used to make many tight gas reservoirs commercially attractive. However, studies have shown that short highly conductive fractures are optimum for the successful stimulation of wells in moderate permeability reservoirs. As a result, the ability to design and place optimal fractures in these reservoirs is critical. This paper illustrates the application of fracture analysis techniques to a moderate permeability multi-layered reservoir. These techniques were used to identify large zonal variations in rock properties and pore pressure which result from the complex geology. The inclusion of geologic factors in fracture treatment design allowed the placement of short highly conductive fractures which were used to improve injectivity and vertical sweep, and therefore, ultimate recovery.

Britt, L.K.; Larsen, M.J.

1986-01-01T23:59:59.000Z

203

Geothermal Reservoir Dynamics - TOUGHREACT  

DOE Green Energy (OSTI)

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.

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

2005-03-15T23:59:59.000Z

204

Chickamauga reservoir embayment study - 1990  

DOE Green Energy (OSTI)

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.

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

1992-12-01T23:59:59.000Z

205

Modeling well performance in compartmentalized gas reservoirs  

E-Print Network (OSTI)

Predicting the performance of wells in compartmentalized reservoirs can be quite challenging to most conventional reservoir engineering tools. The purpose of this research is to develop a Compartmentalized Gas Depletion Model that applies not only to conventional consolidated reservoirs (with constant formation compressibility) but also to unconsolidated reservoirs (with variable formation compressibility) by including geomechanics, permeability deterioration and compartmentalization to estimate the OGIP and performance characteristics of each compartment in such reservoirs given production data. A geomechanics model was developed using available correlation in the industry to estimate variable pore volume compressibility, reservoir compaction and permeability reduction. The geomechanics calculations were combined with gas material balance equation and pseudo-steady state equation and the model was used to predict well performance. Simulated production data from a conventional gas Simulator was used for consolidated reservoir cases while synthetic data (generated by the model using known parameters) was used for unconsolidated reservoir cases. In both cases, the Compartmentalized Depletion Model was used to analyze data, and estimate the OGIP and Jg of each compartment in a compartmentalized gas reservoir and predict the subsequent reservoir performance. The analysis was done by history-matching gas rate with the model using an optimization technique. The model gave satisfactory results with both consolidated and unconsolidated reservoirs for single and multiple reservoir layers. It was demonstrated that for unconsolidated reservoirs, reduction in permeability and reservoir compaction could be very significant especially for unconsolidated gas reservoirs with large pay thickness and large depletion pressure.

Yusuf, Nurudeen

2007-12-01T23:59:59.000Z

206

Rock Physics Based Determination of Reservoir Microstructure for Reservoir Characterization  

E-Print Network (OSTI)

One of the most important, but often ignored, factors affecting the transport and the seismic properties of hydrocarbon reservoir is pore shape. Transport properties depend on the dimensions, geometry, and distribution of pores and cracks. Knowledge of pore shape distribution is needed to explain the often-encountered complex interrelationship between seismic parameters (e.g. seismic velocity) and the independent physical properties (e.g. porosity) of hydrocarbon reservoirs. However, our knowledge of reservoir pore shape distribution is very limited. This dissertation employs a pore structure parameter via a rock physics model to characterize mean reservoir pore shape. The parameter was used to develop a new physical concept of critical clay content in the context of pore compressibility as a function of pore aspect ratio for a better understanding of seismic velocity as a function of porosity. This study makes use of well log dataset from offshore Norway and from North Viking Graben in the North Sea. In the studied North Sea reservoir, porosity and measured horizontal permeability was found to increase with increasing pore aspect ratio (PAR). PAR is relatively constant at 0.23 for volumes of clay (V_cl) less than 32% with a significant decrease to 0.04 for V_cl above 32%. The point of inflexion at 32% in the PAR V_cl plane is defined as the critical clay volume. Much of the scatters in the compressional velocity-porosity cross-plots are observed where V_cl is above this critical value. For clay content higher than the critical value, Hertz-Mindlin (HM) contact theory over-predicts compressional velocity (V_p) by about 69%. This was reduced to 4% when PAR distribution was accounted for in the original HM formulation. The pore structure parameter was also used to study a fractured carbonate reservoir in the Sichuan basin, China. Using the parameter, the reservoir interval can be distinguished from those with no fracture. The former has a pore structure parameter value that is ? 3.8 whereas it was < 3.8 for the latter. This finding was consistent with the result of fracture analysis, which was based on FMI image. The results from this dissertation will find application in reservoir characterization as the industry target more complex, deeper, and unconventional reservoirs.

Adesokan, Hamid 1976-

2013-05-01T23:59:59.000Z

207

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

Science Conference Proceedings (OSTI)

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.

Not Available

1985-07-04T23:59:59.000Z

208

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

Science Conference Proceedings (OSTI)

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.

None

1998-01-01T23:59:59.000Z

209

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

SciTech Connect

Initial drilling of wells on a uniform spacing, without regard to reservoir performance and characterization, must become a process of the past. Such efforts do not optimize reservoir development as they fail to account for the complex nature of reservoir heterogeneities present in many low permeability reservoirs, and carbonate reservoirs in particular. These reservoirs are typically characterized by: o Large, discontinuous pay intervals o Vertical and lateral changes in reservoir properties o Low reservoir energy o High residual oil saturation o Low recovery efficiency

P. K. Pande

1998-10-29T23:59:59.000Z

210

STATUS OF GEOTHERMAL RESERVOIR ENGINEERING MANAGEMENT PROGRAM ("GREMP") -DECEMBER, 1979  

E-Print Network (OSTI)

the characteristics of a geothermal reservoir: Items 2, 6,new data important to geothermal reservoir engineering prac-forecast performance of the geothermal reservoir and bore

Howard, J. H.

2012-01-01T23:59:59.000Z

211

A STOCHASTIC METHOD FOR MODELING FLUID DISPLACEMENT IN PETROLEUM RESERVOIRS  

E-Print Network (OSTI)

FLUID DISPLACEMENT IN PETROLEUM RESERVOIRS C. Anderson andFLUID DISPLACEMENT IN PETROLEUM RESERVOIRS C. Anderson andachieve optimal recovery of petroleum from a reservoir, it

Anderson, C.

2011-01-01T23:59:59.000Z

212

Modeling of Geothermal Reservoirs: Fundamental Processes, Computer  

Open Energy Info (EERE)

Page Page Edit with form History Facebook icon Twitter icon » Modeling of Geothermal Reservoirs: Fundamental Processes, Computer Simulation and Field Applications Jump to: navigation, search OpenEI Reference LibraryAdd to library Journal Article: Modeling of Geothermal Reservoirs: Fundamental Processes, Computer Simulation and Field Applications Abstract This article attempts to critically evaluate the present state of the art of geothermal reservoir simulation. Methodological aspects of geothermal reservoir modeling are briefly reviewed, with special emphasis on flow in fractured media. We then examine some applications of numerical simulation to studies of reservoir dynamics, well test design and analysis, and modeling of specific fields. Tangible impacts of reservoir simulation

213

Reservoir technology research at Lawrence Berkeley Laboratory  

DOE Green Energy (OSTI)

The research being carried out at LBL as part of DOE/GTD's Reservoir Technology Program includes field, theoretical and modeling activities. The purpose is to develop, improve and validate methods and instrumentation to: (1) determine geothermal reservoir parameters, (2) detect and characterize reservoir fractures and boundaries, and (3) identify and evaluate the importance of reservoir processes. The ultimate objective of this work is to advance the state-of-the-art for characterizing geothermal reservoirs and evaluating their productive capacity and longevity under commercial exploitation. LBL's FY1986 accomplishments, FY1987 progress to date, and possible future activities under DOE's Reservoir Technology Program are discussed.

Lippmann, M.J.

1987-04-01T23:59:59.000Z

214

Geotechnical studies of geothermal reservoirs  

DOE Green Energy (OSTI)

It is proposed to delineate the important factors in the geothermal environment that will affect drilling. The geologic environment of the particular areas of interest are described, including rock types, geologic structure, and other important parameters that help describe the reservoir and overlying cap rock. The geologic environment and reservoir characteristics of several geothermal areas were studied, and drill bits were obtained from most of the areas. The geothermal areas studied are: (1) Geysers, California, (2) Imperial Valley, California, (3) Roosevelt Hot Springs, Utah, (4) Bacca Ranch, Valle Grande, New Mexico, (5) Jemez Caldera, New Mexico, (6) Raft River, Idaho, and (7) Marysville, Montona. (MHR)

Pratt, H.R.; Simonson, E.R.

1976-01-01T23:59:59.000Z

215

student_temp  

NLE Websites -- All DOE Office Websites (Extended Search)

loose ends c. Are appropriate for individual student's development level, capability, gender, cultural background, technical skills, interests, language, and learning style d. Are...

216

Reservoir compaction loads on casings and liners  

Science Conference Proceedings (OSTI)

Pressure drawdown due to production from a reservoir causes compaction of the reservoir formation which induces axial and radial loads on the wellbore. Reservoir compaction loads increase during the production life of a well, and are greater for deviated wells. Presented here are casing and liner loads at initial and final pressure drawdowns for a particular reservoir and at well deviation angles of 0 to 45 degrees.

Wooley, G.R.; Prachner, W.

1984-09-01T23:59:59.000Z

217

Optimization Online - Managing Hydroelectric Reservoirs over an ...  

E-Print Network (OSTI)

Jul 7, 2013 ... Managing Hydroelectric Reservoirs over an Extended Planning Horizon using a Benders Decomposition Algorithm Exploiting a Memory Loss...

218

Prevention of Reservoir Interior Discoloration  

SciTech Connect

Contamination is anathema in reservoir production. Some of the contamination is a result of welding and some appears after welding but existed before. Oxygen was documented to be a major contributor to discoloration in welding. This study demonstrates that it can be controlled and that some of the informal cleaning processes contribute to contamination.

Arnold, K.F.

2001-04-03T23:59:59.000Z

219

HIGH TEMPERATURE GEOTHERMAL RESERVOIR ENGINEERING  

E-Print Network (OSTI)

on the Cerro P r i e t o Geothermal F i e l d , Mexicali,e C e r r o P r i e t o Geothermal F i e l d , Baja C a l i1979 HIGH TEMPERATURE GEOTHERMAL RESERVOIR ENGINEERING R.

Schroeder, R.C.

2009-01-01T23:59:59.000Z

220

Nutrient transport model in CHAHNIMEH manmade reservoirs  

Science Conference Proceedings (OSTI)

A Model for predicting nutrient transport to CHAHNIMEH reservoir is developed in this paper. Nitrogen and phosphorous have been simulated as the important parameters in evaluating water quality in the reservoir. Solar radiation and wind flow are considered ... Keywords: CHAHNIMEH, modeling, nutrient, reservoir, transport, water movement

Seyyed Ahmad Mirbagheri; Seyyed Arman Hashemi Monfared

2008-08-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


221

Tenth workshop on geothermal reservoir engineering: proceedings  

DOE Green Energy (OSTI)

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)

Not Available

1985-01-22T23:59:59.000Z

222

Eutrophication modelling of reservoirs in Taiwan  

Science Conference Proceedings (OSTI)

Two reservoirs in Taiwan were modeled to simulate the hydrodynamics and water quality in the water column. The modelling effort was supported with data collected in the field for a 2-year period for both reservoirs. Spatial and temporal distributions ... Keywords: CE-QUAL-W2, Reservoir Eutrophication Modelling, Water quality

Jan-Tai Kuo; Wu-Seng Lung; Chou-Ping Yang; Wen-Cheng Liu; Ming-Der Yang; Tai-Shan Tang

2006-06-01T23:59:59.000Z

223

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

SciTech Connect

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.

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

2001-08-07T23:59:59.000Z

224

4. International reservoir characterization technical conference  

Science Conference Proceedings (OSTI)

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.

NONE

1997-04-01T23:59:59.000Z

225

Differential impact of immediate total deregulation of wellhead prices of natural gas on minority and low-income homeowners: a general review and a case study in the Washington, DC area  

SciTech Connect

In this study, the authors evaluate the impact of total deregulation of wellhead prices of natural gas on various strata of the residential consuming population, and compare it to the baseline impact of a continuation of the Natural Gas Policy Act of 1978. They found that minority and poverty homeowners will suffer greater relative welfare losses than their white and non-poverty counterparts. They developed quantitative estimates of the extent of these differentials, and offered some policy proposals suggested by these findings. 54 refs., 8 figs., 68 tabs.

Green, R.D.; Gilbert, H.R.

1983-01-01T23:59:59.000Z

226

Storage capacity in hot dry rock reservoirs  

DOE Patents (OSTI)

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.

Brown, D.W.

1997-11-11T23:59:59.000Z

227

A virtual company concept for reservoir management  

SciTech Connect

This paper describes how reservoir management problems were pursued with a virtual company concept via the Internet and World Wide Web. The focus of the paper is on the implementation of virtual asset management teams that were assembled with small independent oil companies. The paper highlights the mechanics of how the virtual team transferred data and interpretations, evaluated geological models of complex reservoirs, and used results of simulation studies to analyze various reservoir management strategies.

Martin, F.D. [Dave Martin and Associates, Inc. (United States); Kendall, R.P.; Whitney, E.M. [Los Alamos National Lab., NM (United States)

1998-12-31T23:59:59.000Z

228

Slimholes for geothermal reservoir evaluation - An overview  

DOE Green Energy (OSTI)

The topics covered in this session include: slimhole testing and data acquisition, theoretical and numerical models for slimholes, and an overview of the analysis of slimhole data acquired by the Japanese. The fundamental issues discussed are concerned with assessing the efficacy of slimhole testing for the evaluation of geothermal reservoirs. the term reservoir evaluation is here taken to mean the assessment of the potential of the geothermal reservoir for the profitable production of electrical power. As an introduction to the subsequent presentations and discussions, a brief summary of the more important aspects of the use of slimholes in reservoir evaluation is given.

Hickox, C.E.

1996-08-01T23:59:59.000Z

229

Mapping Diffuse Seismicity for Geothermal Reservoir Management...  

Open Energy Info (EERE)

Facebook icon Twitter icon Mapping Diffuse Seismicity for Geothermal Reservoir Management with Matched Field Processing Geothermal Lab Call Project Jump to: navigation,...

230

Nonisothermal injection tests in fractured reservoirs  

DOE Green Energy (OSTI)

The paper extends the analysis of nonisothermal pressure transient data to fractured reservoirs. Two cases are considered: reservoirs with predominantly horzontal fractures and reservoirs with predominantly vertical fractures. Effects of conductive heat transfer between the fractures and the rock matrix are modeled, and the resulting pressure transients evaluated. Thermal conduction tends to retard the movement of the thermal front in the fractures, which significantly affects the pressure transient data. The purpose of the numerical simulation studies is to provide methods for analyzing nonisothermal injection/falloff data for fractured reservoirs.

Cox, B.L.; Bodvarsson, G.S.

1985-01-01T23:59:59.000Z

231

Injecting Carbon Dioxide into Unconventional Storage Reservoirs...  

NLE Websites -- All DOE Office Websites (Extended Search)

will also be investigated with a targeted CO 2 injection test into a depleted shale gas well. Different reservoir models will be used before, during, and after injection...

232

Naturally fractured tight gas reservoir detection optimization  

SciTech Connect

Research continued on methods to detect naturally fractured tight gas reservoirs. This report discusses 3D-3C seismic acquisition and 3D P-wave alternate processing.

NONE

1995-12-31T23:59:59.000Z

233

Safety of Dams and Reservoirs Act (Nebraska)  

Energy.gov (U.S. Department of Energy (DOE))

This act regulates dams and associated reservoirs to protect health and public safety and minimize adverse consequences associated with potential dam failure. The act describes the responsibilities...

234

Storage capacity in hot dry rock reservoirs  

DOE Patents (OSTI)

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

Brown, Donald W. (Los Alamos, NM)

1997-01-01T23:59:59.000Z

235

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

Science Conference Proceedings (OSTI)

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.

Clarkson, Christopher R [ORNL

2011-01-01T23:59:59.000Z

236

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

Science Conference Proceedings (OSTI)

The objectives of this quarterly report was to summarize the work conducted under each task during the reporting period April - June 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.

Koerner, Roy; Clarke, Don; Walker, Scott

1999-11-09T23:59:59.000Z

237

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

SciTech Connect

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.

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

1997-04-10T23:59:59.000Z

238

River Flow Forecasting for Reservoir management through Neural Networks  

Science Conference Proceedings (OSTI)

In utilities using a mixture of hydroelectric and nonhydroelectric power, the economics of the hydroelectric plants depend upon the reservoir height and the inflow into the reservoir for several months into the future. Accurate forecasts of reservoir ...

Meuser Valenca; Teresa Ludermir; Anelle Valenca

2005-12-01T23:59:59.000Z

239

Unsteady Flow Model for Fractured Gas Reservoirs  

Science Conference Proceedings (OSTI)

Developing low permeability reservoirs is currently a big challenge to the industry. Because low permeability reservoirs are of low quality and are easily damaged, production from a single well is low, and there is unlikely to be any primary recovery. ... Keywords: Low permeability, Fractured well, Orthogonal transformation, Unsteady, Productivity

Li Yongming; Zhao Jinzhou; Gong Yang; Yao Fengsheng; Jiang Youshi

2010-12-01T23:59:59.000Z

240

Water resources review: Wheeler Reservoir, 1990  

DOE Green Energy (OSTI)

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.

Wallus, R.; Cox, J.P.

1990-09-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


241

Geothermal reservoir insurance study. Final report  

DOE Green Energy (OSTI)

The principal goal of this study was to provide analysis of and recommendations on the need for and feasibility of a geothermal reservoir insurance program. Five major tasks are reported: perception of risk by major market sectors, status of private sector insurance programs, analysis of reservoir risks, alternative government roles, and recommendations.

Not Available

1981-10-09T23:59:59.000Z

242

Characterization of oil and gas reservoir heterogeneity  

SciTech Connect

The ultimate oojective of this cooperative research project is to characterize Alaskan petroleum reservoirs in terms of their reserves, physical and chemical properties, geologic configuration in relation to lithofacies and structure, and development potential. The project has two tasks: Task 1 is a geological description of the reservoirs including petrophysical properties, i.e., porosity, permeability, permeability variation, formation depth, temperature, and net pay, facies changes and reservoir structures as drawn from cores, well logs, and other geological data. Task 2 is reservoir fluid characterization--determination of physical properties of reservoir fluids including density, viscosity, phase distributions and composition as well as petrogenesis--source rock identification; and the study of asphaltene precipitation for Alaskan crude oils. This report presents a summary of technical progress of the well log analysis of Kuparuk Field, Northslope, Alaska.

Sharma, G.D.

1992-01-01T23:59:59.000Z

243

Characterization of oil and gas reservoir heterogeneity  

SciTech Connect

The ultimate objective of this cooperative research project is to characterize Alaskan petroleum reservoirs in terms of their reserves, physical and chemical properties, geologic configuration in relation to lithofacies and structure, and development potential. The project has two tasks: Task 1 is a geological description of the reservoirs including petrophysical properties, i.e., porosity, permeability, permeability variation, formation depth, temperature, and net pay, facies changes and reservoir structures as drawn from cores, well logs, and other geological data. Task 2 is reservoir fluid characterization -- determination of physical properties of reservoir fluids including density, viscosity, phase distributions and composition as well as petrogenesis -- source rock identification; and the study of asphaltene precipitation for Alaskan crude oils.

Sharma, G.D.

1991-01-01T23:59:59.000Z

244

Characterization of oil and gas reservoir heterogeneity  

SciTech Connect

The ultimate objective of this cooperative research project is to characterize Alaskan petroleum reservoirs in terms of their reserves, physical and chemical properties, geologic configuration in relation to lithofacies and structure, and development potential. The project has two tasks: Task 1 is a geological description of the reservoirs including petrophysical properties, i.e., porosity, permeability, permeability variation, formation depth, temperature, and net pay, facies changes and reservoir structures as drawn from cores, well logs, and other geological data. Task 2 is reservoir fluid characterization-determination of physical properties of reservoir fluids including density, viscosity, phase distributions and composition as well as petrogenesis-source rock identification; and the study of asphaltene precipitation for Alaskan crude oils. Results are discussed.

Sharma, G.D.

1992-01-01T23:59:59.000Z

245

Utah Natural Gas, Wet After Lease Separation New Reservoir Discoveries...  

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

New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Utah Natural Gas, Wet After Lease Separation New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0...

246

Utah Coalbed Methane Proved Reserves New Reservoir Discoveries...  

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

New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Utah Coalbed Methane Proved Reserves New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0 Year-1...

247

Utah Nonassociated Natural Gas, Reserves in Nonproducing Reservoirs...  

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

Reserves in Nonproducing Reservoirs, Wet (Billion Cubic Feet) Utah Nonassociated Natural Gas, Reserves in Nonproducing Reservoirs, Wet (Billion Cubic Feet) Decade Year-0 Year-1...

248

A New Method for Treating Wells in Reservoir Simulation.  

E-Print Network (OSTI)

??A new method for formulating finite difference equations for reservoir simulation has been developed. It can be applied throughout the entire simulated reservoir or to (more)

Gessel, Gregory M 1980-

2007-01-01T23:59:59.000Z

249

Louisiana--North Crude Oil Reserves in Nonproducing Reservoirs...  

Annual Energy Outlook 2012 (EIA)

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...

250

The Influence of Reservoir Heterogeneity on Geothermal Fluid...  

NLE Websites -- All DOE Office Websites (Extended Search)

Alliance for Sustainable Energy, LLC. THE INFLUENCE OF RESERVOIR HETEROGENEITY ON GEOTHERMAL FLUID AND METHANE RECOVERY FROM A GEOPRESSURED GEOTHERMAL RESERVOIR Ariel Esposito...

251

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

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

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

252

Wyoming Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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...

253

Illinois Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

254

Arkansas Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

255

Florida Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

256

Montana Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

257

Kentucky Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

258

Michigan Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

259

Pennsylvania Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

260

Oklahoma Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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...

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


261

Colorado Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

262

Louisiana--South Onshore Crude Oil Reserves in Nonproducing Reservoirs...  

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

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...

263

Effect of matrix shrinkage on permeability of coalbed methane reservoirs .  

E-Print Network (OSTI)

??The dynamic nature of coalbed methane reservoir permeability makes the continuous modeling of the flow process difficult. Knowledge of conventional reservoir modeling is of little (more)

Tandon, Rohit, 1966-

1991-01-01T23:59:59.000Z

264

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

Open Energy Info (EERE)

reservoir, Idaho Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Journal Article: Borehole geophysics evaluation of the Raft River geothermal reservoir, Idaho Details...

265

California Federal Offshore Dry Natural Gas New Reservoir Discoveries...  

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

New Reservoir Discoveries in Old Fields (Billion Cubic Feet) California Federal Offshore Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0...

266

Statistical study of seismicity associated with geothermal reservoirs...  

Open Energy Info (EERE)

reservoirs in California Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Report: Statistical study of seismicity associated with geothermal reservoirs in California...

267

Lower 48 States Crude Oil Reserves in Nonproducing Reservoirs...  

Gasoline and Diesel Fuel Update (EIA)

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...

268

Miscellaneous States Crude Oil Reserves in Nonproducing Reservoirs...  

Annual Energy Outlook 2012 (EIA)

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...

269

New Mexico - East Dry Natural Gas New Reservoir Discoveries in...  

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

Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) New Mexico - East Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade...

270

New Mexico - West Dry Natural Gas New Reservoir Discoveries in...  

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

Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) New Mexico - West Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade...

271

Texas--State Offshore Crude Oil Reserves in Nonproducing Reservoirs...  

Annual Energy Outlook 2012 (EIA)

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...

272

Integrated reservoir characterization for the Mazari oil field, Pakistan  

E-Print Network (OSTI)

This thesis describes a field study performed on the Mazari oil field located in Sind province, Pakistan. We used an integrated reservoir characterization technique to incorporate the geological, petrophysical, and reservoir performance data to interpret historical reservoir performance, to assess and refine reservoir management activities, and to make plans for future reservoir developments. We used a modified approach to characterize within the mappable geological facies. Our approach is based on the Kozeny-Carmen equation and uses the concept of mean hydraulic radius. As part of our objective to characterize the reservoir, we tabulated reservoir characteristics for each hydraulic flow unit, and we presented estimates of in-place reserves. We evaluated reservoir performance potential using the production history, well tests and cased-hole well log surveys. Suggestions for reservoir management activities in conjunction with the evaluation of the reservoir performance are discussed in detail. Finally, we give recommendations for activities in reservoir development particularly infill drilling considerations and secondary recovery efforts.

Ashraf, Ejaz

1994-01-01T23:59:59.000Z

273

Optimizing reservoir management through fracture modeling  

DOE Green Energy (OSTI)

Fracture flow will become increasingly important to optimal reservoir management as exploration of geothermal reservoirs continues and as injection of spent fluid increases. The Department of Energy conducts research focused on locating and characterizing fractures, modeling the effects of fractures on movement of fluid, solutes, and heat throughout a reservoir, and determining the effects of injection on long-term reservoir production characteristics in order to increase the ability to predict with greater certainty the long-term performance of geothermal reservoirs. Improvements in interpreting and modeling geophysical techniques such as gravity, self potential, and aeromagnetics are yielding new information for the delineation of active major conduits for fluid flow. Vertical seismic profiling and cross-borehole electromagnetic techniques also show promise for delineating fracture zones. DOE funds several efforts for simulating geothermal reservoirs. Lawrence Berkeley Laboratory has adopted a continuum treatment for reservoirs with a fracture component. Idaho National Engineering Laboratory has developed simulation techniques which utilize discrete fractures and interchange of fluid between permeable matrix and fractures. Results of these research projects will be presented to industry through publications and appropriate public meetings. 9 refs.

Renner, J.L.

1988-01-01T23:59:59.000Z

274

Adsorption of water vapor on reservoir rocks  

DOE Green Energy (OSTI)

Progress is reported on: adsorption of water vapor on reservoir rocks; theoretical investigation of adsorption; estimation of adsorption parameters from transient experiments; transient adsorption experiment -- salinity and noncondensible gas effects; the physics of injection of water into, transport and storage of fluids within, and production of vapor from geothermal reservoirs; injection optimization at the Geysers Geothermal Field; a model to test multiwell data interpretation for heterogeneous reservoirs; earth tide effects on downhole pressure measurements; and a finite-difference model for free surface gravity drainage well test analysis.

Not Available

1993-07-01T23:59:59.000Z

275

Dispersivity as an oil reservoir rock characteristic  

Science Conference Proceedings (OSTI)

The main objective of this research project is to establish dispersivity, {alpha}{sub d}, as an oil reservoir rock characteristic and to use this reservoir rock property to enhance crude oil recovery. A second objective is to compare the dispersion coefficient and the dispersivity of various reservoir rocks with other rock characteristics such as: porosity, permeability, capillary pressure, and relative permeability. The dispersivity of a rock was identified by measuring the physical mixing of two miscible fluids, one displacing the other in a porous medium. 119 refs., 27 figs., 12 tabs.

Menzie, D.E.; Dutta, S.

1989-12-01T23:59:59.000Z

276

A structurally complex and dynamic reservoir description for reservoir simulation, Kuparuk River Field, Alaska  

SciTech Connect

The Kupanuk River Field is a structurally complex giant oil field adjacent to the Prudhoe Bay Field on Alaska`s North Slope. Oil is reservoired within two Early Cretaceous shallow marine sandstone formations, separated stratigraphically by an erosionally truncated marine silt/shale. Subjected to several phases of tectonism, this highly compartmentalized reservoir has been developed on regular 160 acre direct line drive patterns. An integrated team of geoscientists and engineers from BP Exploration (Alaska) Inc. and ARCO Alaska Inc. is presently quantifying the benefits of infill drilling at Kuparuk, and identifying the best locations for well placement. The two primary reservoir characteristics believed to impact the effectiveness of infill drilling are large-scale reservoir heterogeneity, and reservoir comparmentation due to faulting. Multiple thin pay zones within the two reservoir intervals are isolated laterally by faults with magnitudes greater than pay zone thickness. A process and tools designed to construct and maintain a structurally complex reservoir description, shared by the geoscientists and reservoir engineers, are described. Cross-discipline integration is aided by the use of Tech*Logic`s IREX 3-D reservoir modeling and visualization application. The unique architecture of the IREX model allows for representation of very complex structural geometries, and facilitates iteration between reservoir description and simulation, along the seismic to simulation continuum. Modifications to the reservoir description are guided by well-level history matching within the constraints of all available geoscience information. The techniques described will be of particular interest to those working on reservoir description and simulation of structurally complex fields.

Walsh, T.P. [Alaska Petrotechnical Services Inc., Anchorage, AK (United States); Leander, M.H.; Wilcox, T.C. [BP Exploration (Alaska) Inc., Anchorage, AK (United States)] [and others

1995-08-01T23:59:59.000Z

277

Installation of a Devonian Shale Reservoir Testing Facility and acquisition of reservoir property measurements  

SciTech Connect

In October, a contract was awarded for the Installation of a Devonian Shale Reservoir Testing Facility and Acquisition of Reservoir Property measurements from wells in the Michigan, Illinois, and Appalachian Basins. Geologic and engineering data collected through this project will provide a better understanding of the mechanisms and conditions controlling shale gas production. This report summarizes the results obtained from the various testing procedures used at each wellsite and the activities conducted at the Reservoir Testing Facility.

Locke, C.D.; Salamy, S.P.

1991-09-01T23:59:59.000Z

278

Installation of a Devonian Shale Reservoir Testing Facility and acquisition of reservoir property measurements. Final report  

SciTech Connect

In October, a contract was awarded for the Installation of a Devonian Shale Reservoir Testing Facility and Acquisition of Reservoir Property measurements from wells in the Michigan, Illinois, and Appalachian Basins. Geologic and engineering data collected through this project will provide a better understanding of the mechanisms and conditions controlling shale gas production. This report summarizes the results obtained from the various testing procedures used at each wellsite and the activities conducted at the Reservoir Testing Facility.

Locke, C.D.; Salamy, S.P.

1991-09-01T23:59:59.000Z

279

Low-to-moderate-temperature hydrothermal reservoir engineering handbook  

DOE Green Energy (OSTI)

Guidelines are provided for evaluating reservoir characteristics containing setions on reservoir classification, conceptual modeling, testing during drilling, current theory of testing, test planning and methodology, instrumentation, and a sample computer program. Sections on test planning and methodology, geochemistry, reservoir monitoring, and the appendixes, containing technical detail, are included. Background information needed to monitor the program of reservoir evaluation is provided.

Not Available

1982-06-01T23:59:59.000Z

280

Improved energy recovery from geothermal reservoirs  

DOE Green Energy (OSTI)

Numerical simulation methods are used to study how the exploitation of different horizons affects the behavior of a liquid-dominated geothermal reservoir. The reservoir model is a schematic representation of the Olkaria field in Kenya. The model consists of a two-phase vapor-dominated zone overlying the main liquid dominated reservoir. Four different cases were studied, with fluid produced from: 1) the vapor zone only, 2) the liquid zone only, 3) both zones and 4) both zones, but assuming lower values for vertical permeability and porosity. The results indicate that production from the shallow two-phase zone, although resulting in higher enthalpy fluids, may not be advantageous in the long run. Shallow production gives rise to a rather localized depletion of the reservoir, whereas production from deeper horizons may yield a more uniform depletion proces, if vertical permeability is sufficiently large.

Boedvarsson, G.S.; Pruess, K.; Lippmann, M.; Bjoernsson, S.

1981-06-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
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We encourage you to perform a real-time search of NLEBeta
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281

Definition: Hydrothermal Reservoir | Open Energy Information  

Open Energy Info (EERE)

Hydrothermal Reservoirs are underground zones of porous rock containing hot water and steam, and can be naturally occurring or human-made.1 References x Ret LikeLike...

282

Heat deliverability of homogeneous geothermal reservoirs  

DOE Green Energy (OSTI)

For the last two decades, the petroleum industry has been successfully using simple inflow performance relationships (IPR's) to predict oil deliverability. In contrast, the geothermal industry lacked a simple and reliable method to estimate geothermal wells' heat deliverability. To address this gap in the standard geothermal-reservoir-assessment arsenal, we developed generalized dimensionless geothermal inflow performance relationships (GIPR's). These ''reference curves'' may be regarded as an approximate general solution of the equations describing the practically important case of radial 2-phase inflow. Based on this approximate solution, we outline a straightforward approach to estimate the reservoir contribution to geothermal wells heat and mass deliverability for 2-phase reservoirs. This approach is far less costly and in most cases as reliable as numerically modeling the reservoir, which is the alternative for 2-phase inflow.

Iglesias, Eduardo R.; Moya, Sara L.

1991-01-01T23:59:59.000Z

283

Reservoir response to tidal and barometric effects  

DOE Green Energy (OSTI)

Solid earth tidal strain and surface loading due to fluctuations in barometric pressure have the effect, although extremely minute, of dilating or contracting the effective pore volume in a porous reservoir. If a well intersects the formation, the change in pore pressure can be measured with sensitive quartz pressure gauges. Mathematical models of the relevant fluid dynamics of the well-reservoir system have been generated and tested against conventional well pumping results or core data at the Salton Sea Geothermal Field (SSGF), California and at the Raft River, Geothermal Field (RRGF), Idaho. Porosity-total compressibility product evaluation based on tidal strain response compares favorably with results based on conventional pumping techniques. Analysis of reservoir response to barometric loading using Auto Regressive Integrated Moving Average (ARIMA) stochastic modeling appears also to have potential use for the evaluation of reservoir parameters.

Hanson, J.M.

1980-05-29T23:59:59.000Z

284

Heat deliverability of homogeneous geothermal reservoirs  

SciTech Connect

For the last two decades, the petroleum industry has been successfully using simple inflow performance relationships (IPR's) to predict oil deliverability. In contrast, the geothermal industry lacked a simple and reliable method to estimate geothermal wells' heat deliverability. To address this gap in the standard geothermal-reservoir-assessment arsenal, we developed generalized dimensionless geothermal inflow performance relationships (GIPR's). These ''reference curves'' may be regarded as an approximate general solution of the equations describing the practically important case of radial 2-phase inflow. Based on this approximate solution, we outline a straightforward approach to estimate the reservoir contribution to geothermal wells heat and mass deliverability for 2-phase reservoirs. This approach is far less costly and in most cases as reliable as numerically modeling the reservoir, which is the alternative for 2-phase inflow.

Iglesias, Eduardo R.; Moya, Sara L.

1991-01-01T23:59:59.000Z

285

Reservoir performance characterized in mature steam pattern  

Science Conference Proceedings (OSTI)

A detailed reservoir description provided new insight in an investigation of a ten-year-old steam flood. Mobil Oil Corporation conducted this study of the Pleistocene upper Tulare sands in South Belridge field, located in the San Joaquin basin, Kern County, California. The study area is on the gently dipping (6/degrees/) southwestern flank of the South Belridge anticline. Wireline logs from 19 wells in a 10-ac (660 ft x 660 ft) pattern were correlated in detail. Seven post-steam conventional cores (1523 ft) aided (1) the evaluation of vertical and lateral steam-sweep efficiency, (2) evaluation of reservoir and fluid changes due to steam, (3) influence of lithofacies in reservoir quality, and (4) provided insight to the three-dimensional reservoir flow-unit geometries.

Miller, D.D.; McPherson, J.G.; Covington, T.E.

1989-04-01T23:59:59.000Z

286

PROCEEDINGS TWENTIETH WORKSHOP GEOTHERMAL RESERVOIR ENGINEERING  

NLE Websites -- All DOE Office Websites (Extended Search)

a global reservoir value of the amount of adsorbed liquid water per kg of rock (called ADS in the present paper). We simulated the natural state with different values of ADS,...

287

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. Author(s): Lou, M.; Rial, J.A. Published: Geophysics,...

288

Reservoir screening criteria for underbalanced drilling  

Science Conference Proceedings (OSTI)

Properly designed and executed underbalanced drilling operations can eliminate or significantly reduce formation damage, mud or drill solids invasion, lost circulation, fluid entrainment and trapping effects, and potential adverse reactions of drilling fluids with the reservoir matrix or in-situ reservoir fluids. The key to selecting appropriate reservoir candidates is achieving a balance of technical, safety and economic factors. Not every reservoir is an ideal candidate for an underbalanced drilling operation and in some cases distinct disadvantages may exist in trying to execute an underbalanced drilling operation in comparison to a simpler more conventional overbalanced application. Extensive field experience has played an important role in determining the following key criteria and design considerations that should be examined when evaluating a well. Screening criteria are also provided to help operators ascertain if a given formation is, in fact, a viable underbalanced drilling candidate.

Bennion, D.B. [Hycal Energy Research Labs. Ltd., Calgary, Alberta (Canada)

1997-02-01T23:59:59.000Z

289

Optimizing injected solvent fraction in stratified reservoirs  

E-Print Network (OSTI)

Waterflooding has become standard practice for extending the productive life of many solution gas drive reservoirs, but has the disadvantage of leaving a substantial residual oil volume in the reservoir. Solvent flooding has been offered as a method whereby oil may be completely displaced from the reservoir, leaving no residual volume. Field results have demonstrated that solvent floods suffer from early solvent breakthrough and considerable oil by-passing owing to high solvent mobility. The injection of both water and solvent has been demonstrated to offer advantages. Water partially mitigates both the adverse mobility and high cost of solvent floods, while solvent mobilizes oil which would be left in the reservoir by water alone. The process is equally applicable to reservoirs currently at residual oil saturation (tertiary floods) and to reservoirs at maximum oil saturation (secondary floods). In stratified reservoirs high permeability layers may be preferentially swept by solvent floods, while low permeability layers may be scarcely swept at all. Presence or absence of transverse communication between layers can modify overall sweep efficiency. This work is a study of water-solvent injection in stratified reservoirs based on computer simulation results. Fractional oil recovery as a function of injected solvent fraction, permeability contrast between layers, initial oil saturation, and presence or absence of transverse communication between strata has been determined. Results are presented as a series of optimization curves. Permeability contrast between layers is shown to be the dominant control on fractional oil recovery. Transverse communicating reservoirs are shown to require a higher solvent-water ratio in order to attain recoveries comparable to transverse noncommunicating reservoirs. In actual field projects, water and solvent are injected alternately as discrete slugs. This process is known as "WAG" for "water-alternating-gas". In the simulations used in this study, continuous water-solvent injection at a fixed fraction rather than true WAG was employed. It is demonstrated that the two methods give equivalent results. In summary, this work is the first comprehensive study of the behavior of stratified reservoirs undergoing water-solvent injection.

Moon, Gary Michael

1993-01-01T23:59:59.000Z

290

The LBL geothermal reservoir technology program  

DOE Green Energy (OSTI)

The main objective of the DOE/GD-funded Geothermal Reservoir Technology Program at Lawrence Berkeley Laboratory is the development and testing of new and improved methods and tools needed by industry in its effort to delineate, characterize, evaluate, and exploit hydrothermal systems for geothermal energy. This paper summarizes the recent and ongoing field, laboratory, and theoretical research activities being conducted as part of the Geothermal Reservoir Technology Program. 28 refs., 4 figs.

Lippmann, M.J.

1991-03-01T23:59:59.000Z

291

Stanford Geothermal Program, reservoir and injection technology  

DOE Green Energy (OSTI)

This annual report of the Stanford Geothermal Program presents major projects in reservoir and injection technology. The four include: (1) an application of the boundary element method to front tracking and pressure transient testing; (2) determination of fracture aperture, a multi-tracer approach; (3) an analysis of tracer and thermal transients during reinjection; and, (4) pressure transient modeling of a non-uniformly fractured reservoir. (BN)

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

1988-12-01T23:59:59.000Z

292

Reservoir assessment of The Geysers Geothermal field  

DOE Green Energy (OSTI)

Big Sulphur Creek fault zone, in The Geysers Geothermal field, may be part of a deep-seated, wrench-style fault system. Hydrothermal fluid in the field reservoir may rise through conduits beneath the five main anomalies associated with the Big Sulphur Creek wrench trend. Some geophysical anomalies (electrical resistivity and audio-magnetotelluric) evidently are caused by the hot water geothermal field or zones of altered rocks; others (gravity, P-wave delays, and possibly electrical resistivity) probably respresent the underlying heat source, a possible magma chamber; and others (microearthquake activity) may be related to the steam reservoir. A large negative gravity anomaly and a few low-resistivity anomalies suggest areas generally favorable for the presence of steam zones, but these anomalies apparently do not directly indicate the known steam reservoir. At the current generating capacity of 930 MWe, the estimated life of The Geysers Geothermal field reservoir is 129 years. The estimated reservoir life is 60 years for the anticipated maximum generating capacity of 2000 MWe as of 1990. Wells at The Geysers are drilled with conventional drilling fluid (mud) until the top of the steam reservoir is reached; then, they are drilled with air. Usually, mud, temperature, caliper, dual induction, and cement bond logs are run on the wells.

Thomas, R.P.; Chapman, R.H.; Dykstra, H.

1981-01-01T23:59:59.000Z

293

Integrated reservoir study of the 8 reservoir of the Green Canyon 18 field  

E-Print Network (OSTI)

The move into deeper waters in the Gulf of Mexico has produced new opportunities for petroleum production, but it also has produced new challenges as different reservoir problems are encountered. This integrated reservoir characterization effort has provided useful information about the behavior and characteristics of a typical unconsolidated, overpressured, fine-grained, turbidite reservoir, which constitutes the majority of the reservoirs present in the Outer Continental Shelf of the Gulf of Mexico. Reservoirs in the Green Canyon 18 (GC 18) field constitute part of a turbidite package with reservoir quality typically increasing with depth. Characterization of the relatively shallow 8 reservoir had hitherto been hindered by the difficulty in resolving its complex architecture and stratigraphy. Furthermore, the combination of its unconsolidated rock matrix and abnormal pore pressure has resulted in severe production-induced compaction. The reservoir's complex geology had previously obfuscated the delineation of its hydrocarbon accumulation and determination of its different resource volumes. Geological and architectural alterations caused by post-accumulation salt tectonic activities had previously undermined the determination of the reservoir's active drive mechanisms and their chronology. Seismic interpretation has provided the reservoir geometry and topography. The reservoir stratigraphy has been defined using log, core and seismic data. With well data as pilot points, the spatial distribution of the reservoir properties has been defined using geostatistics. The resulting geological model was used to construct a dynamic flow model that matched historical production and pressure data.. The reservoir's pressure and production behavior indicates a dominant compaction drive mechanism. The results of this work show that the reservoir performance is influenced not only by the available drive energy, but also by the spatial distribution of the different facies relative to well locations. The study has delineated the hydrocarbon bearing reservoir, quantified the different resource categories as STOIIP/GIIP = 19.8/26.2 mmstb/Bscf, ultimate recovery = 9.92/16.01 mmstb/Bscf, and reserves (as of 9/2001) = 1.74/5.99 mmstb/Bscf of oil and gas, respectively. There does not appear to be significant benefit to infill drilling or enhanced recovery operations.

Aniekwena, Anthony Udegbunam

2003-08-01T23:59:59.000Z

294

Third workshop on geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

The Third Workshop on Geothermal Reservoir Engineering convened at Stanford University on December 14, 1977, with 104 attendees from six nations. In keeping with the recommendations expressed by the participants at the Second Workshop, the format of the Workshop was retained, with three days of technical sessions devoted to reservoir physics, well and reservoir testing, field development, and mathematical modeling of geothermal reservoirs. The program presented 33 technical papers, summaries of which are included in these Proceedings. Although the format of the Workshop has remained constant, it is clear from a perusal of the Table of Contents that considerable advances have occurred in all phases of geothermal reservoir engineering over the past three years. Greater understanding of reservoir physics and mathematical representations of vapor-dominated and liquid-dominated reservoirs are evident; new techniques for their analysis are being developed, and significant field data from a number of newer reservoirs are analyzed. The objectives of these workshops have been to bring together researchers active in the various physical and mathematical disciplines comprising the field of geothermal reservoir engineering, to give the participants a forum for review of progress and exchange of new ideas in this rapidly developing field, and to summarize the effective state of the art of geothermal reservoir engineering in a form readily useful to the many government and private agencies involved in the development of geothermal energy. To these objectives, the Third Workshop and these Proceedings have been successfully directed. Several important events in this field have occurred since the Second Workshop in December 1976. The first among these was the incorporation of the Energy Research and Development Administration (ERDA) into the newly formed Department of Energy (DOE) which continues as the leading Federal agency in geothermal reservoir engineering research. The Third Workshop under the Stanford Geothermal Program was supported by a grant from DOE through a subcontract with the Lawrence Berkeley Laboratory of the University of California. A second significant event was the first conference under the ERDA (DOE)-ENEL cooperative program where many of the results of well testing in both nations were discussed. The Proceedings of that conference should be an important contribution to the literature. These Proceedings of the Third Workshop should also make an important contribution to the literature on geothermal reservoir engineering. Much of the data presented at the Workshop were given for the first time, and full technical papers on these subjects will appear in the professional journals. The results of these studies will assist markedly in developing the research programs to be supported by the Federal agencies, and in reducing the costs of research for individual developers and utilities. It is expected that future workshops of the Stanford Geothermal Program will be as successful as this third one. Planning and execution of the Workshop... [see file; ljd, 10/3/2005] The Program Committee recommended two novel sessions for the Third Workshop, both of which were included in the program. The first was the three overviews given at the Workshop by George Pinder (Princeton) on the Academic aspect, James Bresee (DOE-DGE) on the Government aspect, and Charles Morris (Phillips Petroleum) on the Industry aspect. These constituted the invited slate of presentations from the several sectors of the geothermal community. The Program Committee acknowledges their contributions with gratitude. Recognition of the importance of reservoir assurance in opting for geothermal resources as an alternate energy source for electric energy generation resulted in a Panel Session on Various Definitions of Geothermal Reservoirs. Special acknowledgments are offered to Jack Howard and Werner Schwarz (LBL) and to Jack Howard as moderator; to the panelists: James Leigh (Lloyd's Bank of California), Stephen Lipman (Union Oil), Mark Mathisen (PG&E), Patrick M

Ramey, H.J. Jr.; Kruger, P. (eds.)

1977-12-15T23:59:59.000Z

295

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

SciTech Connect

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.

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

2000-03-16T23:59:59.000Z

296

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

Science Conference Proceedings (OSTI)

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.

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

1999-04-28T23:59:59.000Z

297

Seismic imaging of reservoir flow properties: Resolving waterinflux and reservoir permeability  

SciTech Connect

Methods for geophysical model assessment, in particuale thecomputation of model parameter resolution, indicate the value and thelimitations of time-lapse data in estimating reservoir flow properties. Atrajectory-based method for computing sensitivities provides an effectivemeans to compute model parameter resolutions. We examine the commonsituation in which water encroaches into a resrvoir from below, as due tothe upward movement of an oil-water contact. Using straight-forwardtechniques we find that, by inclusing reflections off the top and bottomof a reservoir tens of meters thick, we can infer reservoir permeabilitybased upon time-lapse data. We find that, for the caseof water influxfrom below, using multiple time-lapse 'snapshots' does not necessarilyimprove the resolution of reservoir permeability. An application totime-lapse data from the Norne field illustrates that we can resolve thepermeability near a producing well using reflections from threeinterfaces associated with the reservoir.

Vasco, D.W.; Keers, Henk

2006-11-27T23:59:59.000Z

298

An Updated Conceptual Model Of The Los Humeros Geothermal Reservoir  

Open Energy Info (EERE)

Humeros Geothermal Reservoir Humeros Geothermal Reservoir (Mexico) Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Journal Article: An Updated Conceptual Model Of The Los Humeros Geothermal Reservoir (Mexico) Details Activities (0) Areas (0) Regions (0) Abstract: An analysis of production and reservoir engineering data of 42 wells from the Los Humeros geothermal field (Mexico) allowed obtaining the pressure and temperature profiles for the unperturbed reservoir fluids and developing 1-D and 2-D models for the reservoir. Results showed the existence of at least two reservoirs in the system: a relatively shallow liquid-dominant reservoir located between 1025 and 1600 m above sea level (a.s.l.) the pressure profile of which corresponds to a 300-330°C boiling water column and a deeper low-liquid-saturation reservoir located between

299

Fractured shale reservoirs: Towards a realistic model  

Science Conference Proceedings (OSTI)

Fractured shale reservoirs are fundamentally unconventional, which is to say that their behavior is qualitatively different from reservoirs characterized by intergranular pore space. Attempts to analyze fractured shale reservoirs are essentially misleading. Reliance on such models can have only negative results for fractured shale oil and gas exploration and development. A realistic model of fractured shale reservoirs begins with the history of the shale as a hydrocarbon source rock. Minimum levels of both kerogen concentration and thermal maturity are required for effective hydrocarbon generation. Hydrocarbon generation results in overpressuring of the shale. At some critical level of repressuring, the shale fractures in the ambient stress field. This primary natural fracture system is fundamental to the future behavior of the fractured shale gas reservoir. The fractures facilitate primary migration of oil and gas out of the shale and into the basin. In this process, all connate water is expelled, leaving the fractured shale oil-wet and saturated with oil and gas. What fluids are eventually produced from the fractured shale depends on the consequent structural and geochemical history. As long as the shale remains hot, oil production may be obtained. (e.g. Bakken Shale, Green River Shale). If the shale is significantly cooled, mainly gas will be produced (e.g. Antrim Shale, Ohio Shale, New Albany Shale). Where secondary natural fracture systems are developed and connect the shale to aquifers or to surface recharge, the fractured shale will also produce water (e.g. Antrim Shale, Indiana New Albany Shale).

Hamilton-Smith, T. [Applied Earth Science, Lexington, KY (United States)

1996-09-01T23:59:59.000Z

300

Gas network model allows full reservoir coupling  

Science Conference Proceedings (OSTI)

The gas-network flow model (Gasnet) developed for and added to an existing Qatar General Petroleum Corp. (OGPC) in-house reservoir simulator, allows improved modeling of the interaction among the reservoir, wells, and pipeline networks. Gasnet is a three-phase model that is modified to handle gas-condensate systems. The numerical solution is based on a control volume scheme that uses the concept of cells and junctions, whereby pressure and phase densities are defined in cells, while phase flows are defined at junction links. The model features common numerical equations for the reservoir, the well, and the pipeline components and an efficient state-variable solution method in which all primary variables including phase flows are solved directly. Both steady-state and transient flow events can be simulated with the same tool. Three test cases show how the model runs. One case simulates flow redistribution in a simple two-branch gas network. The second simulates a horizontal gas well in a waterflooded gas reservoir. The third involves an export gas pipeline coupled to a producing reservoir.

Methnani, M.M. [Qatar General Petroleum Corp., Doha (Qatar)

1998-02-23T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


301

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

SciTech Connect

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.

Riley, Ronald; Wicks, John; Perry, Christopher

2009-12-30T23:59:59.000Z

302

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

Science Conference Proceedings (OSTI)

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.

Ronald Riley; John Wicks; Christopher Perry

2009-12-30T23:59:59.000Z

303

Producing Gas-Oil Ratio Performance of Conventional and Unconventional Reservoirs.  

E-Print Network (OSTI)

?? This study presents a detailed analysis of producing gas-oil ratio performance characteristics from conventional reservoir to unconventional reservoir. Numerical simulations of various reservoir fluid (more)

Lei, Guowen

2012-01-01T23:59:59.000Z

304

Numerical investigations into the formation of a high temperature reservoir''  

DOE Green Energy (OSTI)

This paper summarizes an ongoing numerical modeling effort aimed at describing some of the thermodynamic conditions observed in vapor- dominated reservoirs, including the formation of a high temperature reservoir (HTR) beneath the typical'' reservoir. The modeled system begins as a hot water geothermal reservoir, and evolves through time into a vapor-dominated reservoir with a HTR at depth. This approach taken here to develop a vapor-dominated system is similar to that of Pruess (1985), and involves induced boiling through venting. The reservoir description is intentionally generic, but serves to describe a means of evolution of conditions observed (in particular) The Geysers.

Shook, M.

1993-01-01T23:59:59.000Z

305

Numerical investigations into the formation of a ``high temperature reservoir``  

DOE Green Energy (OSTI)

This paper summarizes an ongoing numerical modeling effort aimed at describing some of the thermodynamic conditions observed in vapor- dominated reservoirs, including the formation of a high temperature reservoir (HTR) beneath the ``typical`` reservoir. The modeled system begins as a hot water geothermal reservoir, and evolves through time into a vapor-dominated reservoir with a HTR at depth. This approach taken here to develop a vapor-dominated system is similar to that of Pruess (1985), and involves induced boiling through venting. The reservoir description is intentionally generic, but serves to describe a means of evolution of conditions observed (in particular) The Geysers.

Shook, M.

1993-04-01T23:59:59.000Z

306

Magic Reservoir Geothermal Area | Open Energy Information  

Open Energy Info (EERE)

Magic Reservoir Geothermal Area Magic Reservoir Geothermal Area Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Geothermal Resource Area: Magic Reservoir Geothermal Area Contents 1 Area Overview 2 History and Infrastructure 3 Regulatory and Environmental Issues 4 Exploration History 5 Well Field Description 6 Geology of the Area 7 Geofluid Geochemistry 8 NEPA-Related Analyses (0) 9 Exploration Activities (0) 10 References Loading map... {"minzoom":false,"mappingservice":"googlemaps3","type":"TERRAIN","zoom":6,"types":["ROADMAP","SATELLITE","HYBRID","TERRAIN"],"geoservice":"google","maxzoom":false,"width":"500px","height":"300px","centre":false,"title":"","label":"","icon":"","visitedicon":"","lines":[],"polygons":[],"circles":[],"rectangles":[],"copycoords":false,"static":false,"wmsoverlay":"","layers":[],"controls":["pan","zoom","type","scale","streetview"],"zoomstyle":"DEFAULT","typestyle":"DEFAULT","autoinfowindows":false,"kml":[],"gkml":[],"fusiontables":[],"resizable":false,"tilt":0,"kmlrezoom":false,"poi":true,"imageoverlays":[],"markercluster":false,"searchmarkers":"","locations":[{"text":"","title":"","link":null,"lat":43.32833333,"lon":-114.3983333,"alt":0,"address":"","icon":"","group":"","inlineLabel":"","visitedicon":""}]}

307

Prediction of reservoir compaction and surface subsidence  

SciTech Connect

A new loading-rate-dependent compaction model for unconsolidated clastic reservoirs is presented that considerably improves the accuracy of predicting reservoir rock compaction and surface subsidence resulting from pressure depletion in oil and gas fields. The model has been developed on the basis of extensive laboratory studies and can be derived from a theory relating compaction to time-dependent intergranular friction. The procedure for calculating reservoir compaction from laboratory measurements with the new model is outlined. Both field and laboratory compaction behaviors appear to be described by one single normalized, nonlinear compaction curve. With the new model, the large discrepancies usually observed between predictions based on linear compaction models and actual (nonlinear) field behavior can be explained.

De Waal, J.A.; Smits, R.M.M.

1988-06-01T23:59:59.000Z

308

Shale Reservoir Characterization | Department of Energy  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Oil & Gas » Shale Gas » Shale Reservoir Oil & Gas » Shale Gas » Shale Reservoir Characterization Shale Reservoir Characterization Geologist examining the base of the Marcellus Shale at an outcrop near Bedford, PA. Geologist examining the base of the Marcellus Shale at an outcrop near Bedford, PA. Gas-producing shales are predominantly composed of consolidated clay-sized particles with a high organic content. High subsurface pressures and temperatures convert the organic matter to oil and gas, which may migrate to conventional petroleum traps and also remains within the shale. However, the clay content severely limits gas and fluid flow within the shales. It is, therefore, necessary to understand the mineral and organic content, occurrence of natural fractures, thermal maturity, shale volumes, porosity

309

Second workshop geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

The Arab oil embargo of 1973 focused national attention on energy problems. A national focus on development of energy sources alternative to consumption of hydrocarbons led to the initiation of research studies of reservoir engineering of geothermal systems, funded by the National Science Foundation. At that time it appeared that only two significant reservoir engineering studies of geothermal reservoirs had been completed. Many meetings concerning development of geothermal resources were held from 1973 through the date of the first Stanford Geothermal Reservoir Engineering workshop December 15-17, 1975. These meetings were similar in that many reports dealt with the objectives of planned research projects rather than with results. The first reservoir engineering workshop held under the Stanford Geothermal Program was singular in that for the first time most participants were reporting on progress inactive research programs rather than on work planned. This was true for both laboratory experimental studies and for field experiments in producing geothermal systems. The Proceedings of the December 1975 workshop (SGP-TR-12) is a remarkable document in that results of both field operations and laboratory studies were freely presented and exchanged by all participants. With this in mind the second reservoir engineering workshop was planned for December 1976. The objectives were again two-fold. First, the workshop was designed as a forum to bring together researchers active in various physical and mathematical branches of the developing field of geothermal reservoir engineering, to give participants a current and updated view of progress being made in the field. The second purpose was to prepare this Proceedings of Summaries documenting the state of the art as of December 1976. The proceedings will be distributed to all interested members of the geothermal community involved in the development and utilization of the geothermal resources in the world. Many notable occurrences took place between the first workshop in December 1975 and this present workshop in December 1976. For one thing, the newly formed Energy Research and Development Administration (ERDA) has assumed the lead role in geothermal reservoir engineering research. The second workshop under the Stanford Geothermal Program was supported by a grant from ERDA. In addition, two significant meetings on geothermal energy were held in Rotarua, New Zealand and Taupo, New Zealand. These meetings concerned geothermal reservoir engineering, and the reinjection of cooled geothermal fluids back into a geothermal system. It was clear to attendees of both the New Zealand and the December workshop meetings that a great deal of new information had been developed between August and December 1976. Another exciting report made at the meeting was a successful completion of a new geothermal well on the big island of Hawaii which produces a geothermal fluid that is mainly steam at a temperature in excess of 600 degrees F. Although the total developed electrical power generating capacity due to all geothermal field developments in 1976 is on the order of 1200 megawatts, it was reported that rapid development in geothermal field expansion is taking place in many parts of the world. Approximately 400 megawatts of geothermal power were being developed in the Philippine Islands, and planning for expansion in production in Cerro Prieto, Mexico was also announced. The Geysers in the United States continued the planned expansion toward the level of more than 1000 megawatts. The Second Workshop on Geothermal Reservoir Engineering convened at Stanford December 1976 with 93 attendees from 4 nations, and resulted in the presentation of 44 technical papers, summaries of which are included in these Proceedings. The major areas included in the program consisted of reservoir physics, well testing, field development, well stimulation, and mathematical modeling of geothermal reservoirs. The planning forth is year's workshop and the preparation of the proceedings was carried out mainly by my associate Paul

Kruger, P.; Ramey, H.J. Jr. (eds.)

1976-12-03T23:59:59.000Z

310

Characterization of oil and gas reservoir heterogeneity  

SciTech Connect

Research described In this report addresses the internal architecture of two specific reservoir types: restricted-platform carbonates and fluvial-deltaic sandstones. Together, these two reservoir types contain more than two-thirds of the unrecovered mobile oil remaining ill Texas. The approach followed in this study was to develop a strong understanding of the styles of heterogeneity of these reservoir types based on a detailed outcrop description and a translation of these findings into optimized recovery strategies in select subsurface analogs. Research targeted Grayburg Formation restricted-platform carbonate outcrops along the Algerita Escarpment and In Stone Canyon In southeastern New Mexico and Ferron deltaic sandstones in central Utah as analogs for the North Foster (Grayburg) and Lake Creek (Wilcox) units, respectively. In both settings, sequence-stratigraphic style profoundly influenced between-well architectural fabric and permeability structure. It is concluded that reservoirs of different depositional origins can therefore be categorized Into a heterogeneity matrix'' based on varying intensity of vertical and lateral heterogeneity. The utility of the matrix is that it allows prediction of the nature and location of remaining mobile oil. Highly stratified reservoirs such as the Grayburg, for example, will contain a large proportion of vertically bypassed oil; thus, an appropriate recovery strategy will be waterflood optimization and profile modification. Laterally heterogeneous reservoirs such as deltaic distributary systems would benefit from targeted infill drilling (possibly with horizontal wells) and improved areal sweep efficiency. Potential for advanced recovery of remaining mobile oil through heterogeneity-based advanced secondary recovery strategies In Texas is projected to be an Incremental 16 Bbbl. In the Lower 48 States this target may be as much as 45 Bbbl at low to moderate oil prices over the near- to mid-term.

Tyler, N.; Barton, M.D.; Bebout, D.G.; Fisher, R.S.; Grigsby, J.D.; Guevara, E.; Holtz, M.; Kerans, C.; Nance, H.S.; Levey, R.A.

1992-10-01T23:59:59.000Z

311

Quantification of Libby Reservoir Water Levels Needed to Maintain or Enhance Reservoir Fisheries, 1983 Final Report.  

DOE Green Energy (OSTI)

The first six months of the fishery investigations in Libby Reservoir were aimed at developing suitable methodology for sampling physical-chemical limnology, fish food availability, fish food habits, and seasonal distribution and abundance of fish populations. Appropriate methods have been developed for all aspects with minor modification of original proposed methodologies. Purse seining has yet to be tested. Physical-chemical limnologic sampling could be reduced or subcontracted with the U.S. Geologic Survey to allow for more intensive sampling of fish food or fish distribution portions of the investigation. Final sample design will be determined during 1983-84. Future directions of the study revolve around two central issues, the potential for flexibility in reservoir operation and determination of how reservoir operation affects fish populations. Simulated maximum drawdown levels during a 40-year period were controlled by power in seven out of eight years. Drawdowns were generally within 10 feet of the flood control rule curve, however. There may be more flexibility with regards to timing of refill and evacuation. This aspect needs to be evaluated further. Production and availability of fish food, suitability of reservoir habitat, and accessibility of off-reservoir spawning and rearing habitat were identified as components of fish ecology which reservoir operation could potentially impact. Two models based on trophic dynamics and habitat suitabilities were suggested as a framework for exploring the relationship of reservoir operation on the fish community.

Shepard, Bradley B.

1984-07-01T23:59:59.000Z

312

Characterization of oil and gas reservoir heterogeneity  

SciTech Connect

The objective of the cooperative research program is to characterize Alaskan reservoirs in terms of their reserves, physical and chemical properties, geologic configuration and structure, and the development potential. The tasks completed during this period include: (1) geologic reservoir description of Endicott Field; (2) petrographic characterization of core samples taken from selected stratigraphic horizons of the West Sak and Ugnu (Brookian) wells; (3) development of a polydispersed thermodynamic model for predicting asphaltene equilibria and asphaltene precipitation from crude oil-solvent mixtures, and (4) preliminary geologic description of the Milne Point Unit.

Not Available

1991-01-01T23:59:59.000Z

313

Geothermal reservoir engineering code: comparison and validation  

DOE Green Energy (OSTI)

INTERCOMP has simulated six geothermal reservoir problems. INTERCOMP's geothermal reservoir model was used for all problems. No modifications were made to this model except to provide tabular output of the simulation results in the units used in RFP No. DE-RP03-80SF-10844. No difficulty was encountered in performing the problems described herein, although setting up the boundary and grid conditions exactly as specified were sometimes awkward, and minor modifications to the grid system were necessitated. The results of each problem are presented in tabular and (for many) graphical form.

Not Available

1981-02-27T23:59:59.000Z

314

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

Science Conference Proceedings (OSTI)

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.

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

2002-02-28T23:59:59.000Z

315

Geothermal reservoir engineering computer code comparison and validation calculations using MUSHRM and CHARGR geothermal reservoir simulators  

DOE Green Energy (OSTI)

The essential features of the reservoir codes CHARGR and MUSHRM are described. Solutions obtained for the problem set posed by DOE are presented. CHARGR was used for all six problems; MUSHRM was used for one. These problems are: the 1-D Avdonin solution, the 1-D well test analysis, 2-D flow to a well in fracture/block media, expanding two-phase system with drainage, flow in a 2-D areal reservoir, and flow in a 3-D reservoir. Results for the last problem using both codes are compared. (MHR)

Pritchett, J.W.

1980-11-01T23:59:59.000Z

316

SEISMIC DETERMINATION OF RESERVOIR HETEROGENEITY; APPLICATION TO THE CHARACTERIZATION OF HEAVY OIL RESERVOIRS  

SciTech Connect

The objective of the project is to examine how seismic and geologic data can be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study is performed at West Coalinga Field in California. We continued our investigation on the nature of seismic reactions from heterogeneous reservoirs. We began testing our algorithm to infer parameters of object-based reservoir models from seismic data. We began integration of seismic and geologic data to determine the deterministic limits of conventional seismic data interpretation. Lastly, we began integration of seismic and geologic heterogeneity using stochastic models conditioned both on wireline and seismic data.

Matthias G. Imhof; James W. Castle

2003-11-01T23:59:59.000Z

317

A petrophysics and reservoir performance-based reservoir characterization of Womack Hill (Upper Smackover) Field (Alabama)  

E-Print Network (OSTI)

Womack Hill is one of the 57 Smackover fields throughout the Gulf Coast region. Since its discovery in 1970, Womack Hill Field has produced 30 million STB from the Upper Smackover sequence of carbonate reservoirs. Since production reached its peak in 1977, oil and gas rates have declined substantially. During the last ten years, the production decline has accelerated despite an increase in the water injection rate. This production decline along with the increase in the operating costs has caused a considerable drop in profitability of the field. The field currently produces 640 STB/D of oil and 330 MSCF/D of gas, along with 6,700 STB/D of water, which implies a water cut of over 90 percent. In order to optimize the reservoir management strategies for Womack Hill Field, we need to develop an integrated reservoir study. This thesis addresses the creation of an integrated reservoir study and specifically provides a detailed reservoir description that represents the high level of heterogeneity that exists within this field. Such levels of heterogeneity are characteristic of carbonate reservoirs. This research should serve as a guide for future work in reservoir simulation and can be used to evaluate various scenarios for additional development as well as to optimize the operating practices in the field. We used a non-parametric regression algorithm (ACE) to develop correlations between the core and well log data. These correlations allow us to estimate reservoir permeability at the "flow unit" scale. We note that our efforts to reach an overall correlation were unsuccessful. We generated distributions of porosity and permeability throughout the reservoir area using statistically derived estimates of porosity and permeability. The resulting reservoir description indicates a clear contrast in reservoir permeability between the western and eastern areas - and in particular, significant variability in the reservoir. We do note that we observed an essentially homogenous porosity distribution. We provided analysis of the production and injection data using various techniques (history plots, EUR plots, and decline type curve analysis) and we note this effort yielded a remaining recoverable oil of 1.9 MMSTB (under the current operating conditions). This analysis suggests a moderate flow separation between the western and eastern areas and raised some questions regarding the suitability of the hydraulic "jet pumps" (the water rate increased coincidentally with the installation of the jet pumps).

Avila Urbaneja, Juan Carlos

2002-01-01T23:59:59.000Z

318

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

319

Evaluating human fecal contamination sources in Kranji Reservoir Catchment, Singapore  

E-Print Network (OSTI)

Singapore government through its Public Utilities Board is interested in opening Kranji Reservoir to recreational use. However, water courses within the Kranji Reservoir catchment contain human fecal indicator bacteria ...

Nshimyimana, Jean Pierre

2010-01-01T23:59:59.000Z

320

California Dry Natural Gas New Reservoir Discoveries in Old Fields...  

Annual Energy Outlook 2012 (EIA)

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

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


321

Ohio Dry Natural Gas New Reservoir Discoveries in Old Fields...  

Annual Energy Outlook 2012 (EIA)

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

322

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...

323

New Mexico--East Crude Oil Reserves in Nonproducing Reservoirs...  

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

Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) New Mexico--East Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3...

324

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...

325

Kansas Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

326

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

327

U.S. Coalbed Methane Proved Reserves New Reservoir Discoveries...  

Annual Energy Outlook 2012 (EIA)

New Reservoir Discoveries in Old Fields (Billion Cubic Feet) U.S. Coalbed Methane Proved Reserves New Reservoir Discoveries in Old Fields (Billion Cubic Feet) Decade Year-0 Year-1...

328

Colorado Dry Natural Gas New Reservoir Discoveries in Old Fields...  

Gasoline and Diesel Fuel Update (EIA)

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

329

New Mexico Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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...

330

West Virginia Crude Oil Reserves in Nonproducing Reservoirs ...  

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

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...

331

North Dakota Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

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...

332

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

Gasoline and Diesel Fuel Update (EIA)

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...

333

Geolocation of man-made reservoirs across terrains of varying complexity using GIS  

Science Conference Proceedings (OSTI)

The Reservoir Sedimentation Survey Information System (RESIS) is one of the world's most comprehensive databases of reservoir sedimentation rates, comprising nearly 6000 surveys for 1819 reservoirs across the continental United States. Sediment surveys ... Keywords: DEM, GIS, Reservoir sedimentation, Terrain complexity

David M. Mixon; David A. Kinner; Robert F. Stallard; James P. M. Syvitski

2008-10-01T23:59:59.000Z

334

Fractured reservoir characterization through injection, falloff, and flowback tests  

SciTech Connect

This paper presents the development of a multiphase pressure-transient-analysis technique for naturally fractured reservoirs and the analysis of a series of field tests performed to evaluate the water injection potential and the reservoir characteristics of a naturally fractured reservoir. These included step-rate, water-injectivity, pressure-falloff, and flowback tests. Through these tests, a description of the reservoir was obtained.

Peng, C.P.; Singh, P.K. (Amoco Production Co., Tulsa, OK (United States)); Halvorsen, H. (Amoco Norway Oil Co., Stavanger (NO)); York, S.D. (Amoco Production Co., Houston, TX (United States))

1992-09-01T23:59:59.000Z

335

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...

336

Underground natural gas storage reservoir management  

SciTech Connect

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.

Ortiz, I.; Anthony, R.

1995-06-01T23:59:59.000Z

337

Fourteenth workshop geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

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.

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

1989-01-01T23:59:59.000Z

338

Fourteenth workshop geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

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.

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

1989-12-31T23:59:59.000Z

339

Intake Operation for Deep Cooling Reservoirs  

Science Conference Proceedings (OSTI)

Use of a submerged intake, rather than a conventional surface intake, would improve the thermal performance of most cooling reservoirs in the United States. Projected operating cost savings at a typical plant would range from $1 million to $10 million because of decreased intake temperatures during the summer.

1987-04-21T23:59:59.000Z

340

Hydroelectric reservoir optimization in a pool market  

Science Conference Proceedings (OSTI)

For a price-taking generator operating a hydro-electric reservoir in a pool electricity market, the optimal stack to offer in each trading period over a planning horizon can be computed using dynamic programming. However, the market trading period (usually ...

G. Pritchard; A. B. Philpott; P. J. Neame

2005-07-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


341

Physical processes of subsidence in geothermal reservoirs  

DOE Green Energy (OSTI)

The objectives of this project were to acquire core and fluid from producing geothermal reservoirs (East Mesa, United States, and Cerro Prieto, Mexico); to test specimens of this core for their short-term and long-term (creep) compaction response; and to develop a compaction constitutive model that would allow future analysis of reservoir compaction and a surface subsidence. A total of approximately two hundred feet of core was obtained from eleven wells in the two geothermal fields. Depths and porosities ranged from 3500 to 11,000 feet and 15 to 40 percent, respectively. Several samples of geothermal fluids were also obtained. After geologically and geochemically describing the materials obtained, selected specimens were tested for their response to the pressures and temperatures of the geothermal environment and to simulated changes in those conditions that would be caused by production. Short-term tests (for example, tests for compressibility extending over a time interval of an hour or less in the laboratory) indicated that these sedimentary materials behaved normally with respect to the expected behavior of reservoir sandstones of these depths and porosities. Compressibilities were of the order 1 x 10/sup 6/ psi. Long-term tests, extending up to several weeks in duration, indicated that pore pressure reduction, simulating reservoir production, tended to cause creep compaction at an initial rate of about 1 x 10/sup -7/ percent porosity reduction per second.

Schatz, J.F.

1982-06-01T23:59:59.000Z

342

Innovative MIOR Process Utilizing Indigenous Reservoir Constituents  

Science Conference Proceedings (OSTI)

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 nutrient amendments to increase oil recovery. This microbial technology has the capability of producing multiple oil-releasing agents.

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

2003-02-11T23:59:59.000Z

343

Waterflood surveillance techniques; A reservoir management approach  

SciTech Connect

The reservoir management aspects of waterflooding span the time before the start of waterflood to the time when the secondary recovery either is uneconomic or is changed to an enhanced recovery. This paper reviews waterflood techniques and reports on surveillance techniques in the management of waterflooding of oil wells.

Thakur, G.C. (Chevron USA Inc. (US))

1991-10-01T23:59:59.000Z

344

Seismic Determination of Reservoir Heterogeneity: Application to the Characterization of Heavy Oil Reservoirs  

Science Conference Proceedings (OSTI)

The objective of the project was to examine how seismic and geologic data could be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study was performed at West Coalinga Field in California.

Imhof, Matthias G.; Castle, James W.

2003-03-12T23:59:59.000Z

345

Automatic history matching in petroleum reservoirs using the TSVD method  

Science Conference Proceedings (OSTI)

History matching is an important inverse problem extensively used to estimate petrophysical properties of an oil reservoir by matching a numerical simulation to the reservoir's history of oil production. In this work, we present a method for the ... Keywords: TSVD, adjoint formulation, history matching, optimization, reservoir simulation

Elisa Portes dos Santos Amorim; Paulo Goldfeld; Flavio Dickstein; Rodrigo Weber dos Santos; Carolina Ribeiro Xavier

2010-03-01T23:59:59.000Z

346

Intelligent seismic inversion workflow for high-resolution reservoir characterization  

Science Conference Proceedings (OSTI)

Developing a geological model is the first and a very important step during the reservoir simulation and modeling process. The geological model usually represents our best interpretation of the reservoir characteristics that extends beyond the well where ... Keywords: Buffalo Valley Field, Neural networks, Reservoir characterization, Seismic inversion

E. Artun; S. Mohaghegh

2011-02-01T23:59:59.000Z

347

Radon as an In Situ Tracer in Geothermal Reservoirs  

Science Conference Proceedings (OSTI)

By measuring trace amounts of radon in geothermal steam, utilities can estimate changes in the properties of the fluid produced from a reservoir. These measurements provide a method to monitor the transition from a liquid-dominated reservoir to a boiling reservoir.

1987-08-26T23:59:59.000Z

348

EOR (enhanced oil recovery): the reservoir and its contents  

SciTech Connect

Factors in commitment to enhanced oil recovery of any type are discussed with relation to reservoir characteristics. Core analysis, well logging, reservoir engineering studies, well transient testing, and chemical tracer testing are recommended in order to ascertain the dimensions and conditions of the potentially hydrocarbon bearing reservoir. The calculated risk that is necessary even after conducting the recommended practices is emphasized.

Frederick, R.O.

1982-08-01T23:59:59.000Z

349

Advanced Reservoir Characterization and Evaluation of CO(2) Gravity Drainage in the Naturally Fractured Spraberry Reservoir  

SciTech Connect

Progress has been made in the area of laboratory analysis of Spraberry oil/brine/rock interactions during this quarter. Water imbibition experiments were conducted under ambient conditions, using cleaned Spraberry cores, synthetic Spraberry reservoir brine, and Spraberry oil. It has been concluded that the Spraberry reservoir cores are weakly water-wet. The average Amott wettability index to water is about 0.55. The average oil recovery due to spontaneous water imbibition is about 50% of original oil in place.

Schechter, David

1996-12-01T23:59:59.000Z

350

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

Science Conference Proceedings (OSTI)

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.

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

1999-04-05T23:59:59.000Z

351

Improved recovery from Gulf of Mexico reservoirs  

Science Conference Proceedings (OSTI)

The Gulf of Mexico Basin offers the greatest near-term potential for reducing the future decline in domestic oil and gas production. The Basin is less mature than productive on-shore areas, large unexplored areas remain, and there is great potential for reducing bypassed oil in known fields. Much of the remaining oil in the offshore is trapped in formations that are extremely complex due to intrusions Of salt domes. Recently, however, significant innovations have been made in seismic processing and reservoir simulation. In addition, significant advances have been made in deviated and horizontal drilling technologies. Effective application of these technologies along with improved integrated resource management methods offer opportunities to significantly increase Gulf of Mexico production, delay platform abandonments, and preserve access to a substantial remaining oil target for both exploratory drilling and advanced recovery processes. On February 18, 1992, Louisiana State University (the Prime Contractor) with two technical subcontractors, BDNL Inc. and ICF, Inc., began a research program to estimate the potential oil and gas reserve additions that could result from the application of advanced secondary and enhanced oil recovery technologies and the exploitation of undeveloped and attic oil zones in the Gulf of Mexico oil fields that are related to piercement salt dornes. This project is a one year continuation of this research and will continue work in reservoir description, extraction processes, and technology transfer. Detailed data will be collected for two previously studied reservoirs: a South Marsh Island reservoir operated by Taylor Energy and a South Pelto reservoir operated by Mobil. This data will include reprocessed 2-D seismic data, newly acquired 3-D data, fluid data, fluid samples, pressure data, well test data, well logs, and core data/samples. Geologic data is being compiled; extraction research has not begun.

Schenewerk, P.

1995-07-30T23:59:59.000Z

352

Horizontal Well Placement Optimization in Gas Reservoirs Using Genetic Algorithms  

E-Print Network (OSTI)

Horizontal well placement determination within a reservoir is a significant and difficult step in the reservoir development process. Determining the optimal well location is a complex problem involving many factors including geological considerations, reservoir and fluid properties, economic costs, lateral direction, and technical ability. The most thorough approach to this problem is that of an exhaustive search, in which a simulation is run for every conceivable well position in the reservoir. Although thorough and accurate, this approach is typically not used in real world applications due to the time constraints from the excessive number of simulations. This project suggests the use of a genetic algorithm applied to the horizontal well placement problem in a gas reservoir to reduce the required number of simulations. This research aims to first determine if well placement optimization is even necessary in a gas reservoir, and if so, to determine the benefit of optimization. Performance of the genetic algorithm was analyzed through five different case scenarios, one involving a vertical well and four involving horizontal wells. The genetic algorithm approach is used to evaluate the effect of well placement in heterogeneous and anisotropic reservoirs on reservoir recovery. The wells are constrained by surface gas rate and bottom-hole pressure for each case. This project's main new contribution is its application of using genetic algorithms to study the effect of well placement optimization in gas reservoirs. Two fundamental questions have been answered in this research. First, does well placement in a gas reservoir affect the reservoir performance? If so, what is an efficient method to find the optimal well location based on reservoir performance? The research provides evidence that well placement optimization is an important criterion during the reservoir development phase of a horizontal-well project in gas reservoirs, but it is less significant to vertical wells in a homogeneous reservoir. It is also shown that genetic algorithms are an extremely efficient and robust tool to find the optimal location.

Gibbs, Trevor Howard

2010-05-01T23:59:59.000Z

353

Geotechnical studies of geothermal reservoirs | Open Energy Information  

Open Energy Info (EERE)

Geotechnical studies of geothermal reservoirs Geotechnical studies of geothermal reservoirs Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Report: Geotechnical studies of geothermal reservoirs Details Activities (7) Areas (7) Regions (0) Abstract: It is proposed to delineate the important factors in the geothermal environment that will affect drilling. The geologic environment of the particular areas of interest are described, including rock types, geologic structure, and other important parameters that help describe the reservoir and overlying cap rock. The geologic environment and reservoir characteristics of several geothermal areas were studied, and drill bits were obtained from most of the areas. The geothermal areas studied are: (1) Geysers, California, (2) Imperial Valley, California, (3) Roosevelt Hot

354

Method of extracting heat from dry geothermal reservoirs  

DOE Patents (OSTI)

Hydraulic fracturing is used to interconnect two or more holes that penetrate a previously dry geothermal reservoir, and to produce within the reservoir a sufficiently large heat-transfer surface so that heat can be extracted from the reservoir at a usefully high rate by a fluid entering it through one hole and leaving it through another. Introduction of a fluid into the reservoir to remove heat from it and establishment of natural (unpumped) convective circulation through the reservoir to accomplish continuous heat removal are important and novel features of the method. (auth)

Potter, R.M.; Robinson, E.S.; Smith, M.C.

1974-01-22T23:59:59.000Z

355

Reservoir technology research at the Idaho National Engineering Laboratory  

DOE Green Energy (OSTI)

The Idaho National Engineering Laboratory (INEL) has been conducting geothermal reservoir research and testing sponsored by the US Department of Energy (DOE) since 1983. The INEL research program is primarily aimed at the development of reservoir engineering techniques for fractured geothermal reservoirs. Numerical methods have been developed which allow the simulation of fluid flow and heat transfer in complex fractured reservoirs. Sensitivity studies have illustrated the importance of incorporating the influence of fractures in reservoir simulations. Related efforts include fracture characterization, geochemical reaction kinetics and field testing.

Stiger, S.G.; Renner, J.L.

1987-01-01T23:59:59.000Z

356

Heavy oil reservoirs recoverable by thermal technology. Annual report  

SciTech Connect

This volume contains reservoir, production, and project data for target reservoirs which contain heavy oil in the 8 to 25/sup 0/ API gravity range and are susceptible to recovery by in situ combustion and steam drive. The reservoirs for steam recovery are less than 2500 feet deep to comply with state-of-the-art technology. In cases where one reservoir would be a target for in situ combustion or steam drive, that reservoir is reported in both sections. Data were collectd 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.

Kujawa, P.

1981-02-01T23:59:59.000Z

357

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

Science Conference Proceedings (OSTI)

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.

Malcolm Pitts; Ron Damm; Bev Seyler

2003-03-01T23:59:59.000Z

358

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

Science Conference Proceedings (OSTI)

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.

Malcolm Pitts; Ron Damm; Bev Seyler

2003-04-01T23:59:59.000Z

359

Reducing long-term reservoir performance uncertainty  

DOE Green Energy (OSTI)

Reservoir performance is one of the key issues that have to be addressed before going ahead with the development of a geothermal field. In order to select the type and size of the power plant and design other surface installations, it is necessary to know the characteristics of the production wells and of the produced fluids, and to predict the changes over a 10--30 year period. This is not a straightforward task, as in most cases the calculations have to be made on the basis of data collected before significant fluid volumes have been extracted from the reservoir. The paper describes the methodology used in predicting the long-term performance of hydrothermal systems, as well as DOE/GTD-sponsored research aimed at reducing the uncertainties associated with these predictions. 27 refs., 1 fig.

Lippmann, M.J.

1988-04-01T23:59:59.000Z

360

Thermodynamic behaviour of simplified geothermal reservoirs  

DOE Green Energy (OSTI)

Starting from the basic laws of conservation of mass and energy, the differential equations that represent the thermodynamic behavior of a simplified geothermal reservoir are derived. Its application is limited to a reservoir of high permeability as it usually occurs in the central zone of a geothermal field. A very practical method to solve numerically the equations is presented, based on the direct use of the steam tables. The method, based in one general equation, is extended and illustrated with a numerical example to the case of segregated mass extraction, variable influx and heat exchange between rock and fluid. As it is explained, the method can be easily coupled to several influx models already developed somewhere else. The proposed model can become an important tool to solve practical problems, where like in Los Azufres Mexico, the geothermal field can be divided in an inner part where flashing occurs and an exterior field where storage of water plays the main role.

Hiriart, G.; Sanchez, E.

1985-01-22T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


361

Enhancing Reservoir Management in the Appalach  

NLE Websites -- All DOE Office Websites (Extended Search)

Reservoir Management in the Appalachian Basin by Identifying Technical Reservoir Management in the Appalachian Basin by Identifying Technical Barrier and Preferred Practices Final Report Reporting Period Start Date: September 1, 2001 Reporting Period End Date: September 15, 2003 Principal Author(s): Ronald R. McDowell Khashayar Aminian Katharine L. Avary John M. Bocan Michael Ed. Hohn Douglas G. Patchen September 2003 DE-FC26-01BC15273 West Virginia University Research Corporation West Virginia Geological and Economic Survey (subcontractor) ii DISCLAIMER This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or responsibility for the accuracy, completeness, or usefulness of any information, apparatus,

362

Injection into a fractured geothermal reservoir  

DOE Green Energy (OSTI)

A detailed study is made on the movement of the thermal fronts in the fracture and in the porous medium when 100{sup 0}C water is injected into a 300{sup 0}C geothermal reservoir with equally spaced horizontal fractures. Numerical modeling calculations were made for a number of thermal conductivity values, as well as different values of the ratio of fracture and rock medium permeabilities. One important result is an indication that although initially, the thermal front in the fracture moves very fast relative to the front in the porous medium as commonly expected, its speed rapidly decreases. At some distance from the injection well the thermal fronts in the fracture and the porous medium coincide, and from that point they advance together. The implication of this result on the effects of fractures on reinjection into geothermal reservoirs is discussed.

Bodvarsson, G.S.; Tsang, C.F.

1980-05-01T23:59:59.000Z

363

Innovative MIOR Process Utilizing Indigenous Reservoir Constituents  

Science Conference Proceedings (OSTI)

This research program is directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal is to identify 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 is underway. Microbial cultures have been 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 with cultures and conditions representative of oil reservoirs. Field pilot studies are underway.

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

2003-03-31T23:59:59.000Z

364

Application of stress corrosion to geothermal reservoirs  

DOE Green Energy (OSTI)

There are several alternative equations which describe slow crack growth by stress corrosion. Presently available data suggest that an alternative form may be preferable to the form which is most often used, but the issue cannot be clearly decided. Presently available stress corrosion data on glasses and ceramics suggest that rocks in a proposed geothermal reservoir will crack readily over long time periods, thus seriously limiting the operation of this type of power source. However, in situ hydrofracturing measurements together with a theoretical treatment suggest that such a reservoir will contain a relatively high pressure over a long period of time without further cracking. Further experimentation is desirable to measure directly the critical stresses for crack growth rates on the order of 10/sup -7/ m/sec.

Demarest, H.H. Jr.

1975-10-01T23:59:59.000Z

365

Hot dry rock Phase II reservoir engineering  

DOE Green Energy (OSTI)

Early attempts to hydraulically fracture and connect two wells drilled at the Hot Dry Rock site at Fenton Hill in New Mexico failed. Microearthquakes triggered by hydraulic fracturing indicated that the fracture zones grew in unexpected directions. Consequently one of the wells was sidetracked at a depth of 2.9 km; was redrilled into the zones of most intense microseismic activity; and a flow connection was achieved. Hydraulic communication was improved by supplemental fracturing using recently developed high temperature and high pressure open hole packers. Preliminary testing indicates a reservoir with stimulated joint volume which already surpasses that attained in the earlier phase I reservoir after several years of development. 12 refs., 6 figs.

Murphy, H.D.

1985-01-01T23:59:59.000Z

366

Pressure transient analysis for naturally fractured reservoirs  

Science Conference Proceedings (OSTI)

New ideas are presented for the interpretation of pressure transient tests for wells in naturally fractured reservoirs. This work is based on the transient matrix flow model formulated by de Swaan. The differences between this model and the Warren and Root model occur during the transition flow period. It is demonstrated that the behavior of a naturally fractured reservoir can be correlated by using three dimensionless parameters. It is established that regardless of matrix geometry the transition period might exhibit a straight line whose slope is equal to half the slope of the classical parallel semilog straight lines, provided the transient matrix linear flow is present. In addition, information is provided on the estimation of fracture area per unit matrix volume or matrix parameters from the transition period semilog straight line. It is shown that matrix geometry might be identified when pressure data are smooth. Field examples are included to illustrate the application and the validity of the theoretical results of this study.

Cinco-ley, H.; Samaniego, F.V.

1982-09-01T23:59:59.000Z

367

Innovative MIOR Process Utilizing Indigenous Reservoir Constituents  

SciTech Connect

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.

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

2003-02-11T23:59:59.000Z

368

Quantification of Libby Reservoir Levels Needed to Maintain or Enhance Reservoir Fisheries, 1983-1987 Methods and Data Summary.  

DOE Green Energy (OSTI)

Libby Reservoir was created under an International Columbia River Treaty between the United States and Canada for cooperative water development of the Columbia River Basin. The authorized purpose of the dam is to provide power, flood control, and navigation and other benefits. Research began in May 1983 to determine how operations of Libby dam impact the reservoir fishery and to suggest ways to lessen these impacts. This study is unique in that it was designed to accomplish its goal through detailed information gathering on every trophic level in the reservoir system and integration of this information into a quantitative computer model. The specific study objectives are to: quantify available reservoir habitat, determine abundance, growth and distribution of fish within the reservoir and potential recruitment of salmonids from Libby Reservoir tributaries within the United States, determine abundance and availability of food organisms for fish in the reservoir, quantify fish use of available food items, develop relationships between reservoir drawdown and reservoir habitat for fish and fish food organisms, and estimate impacts of reservoir operation on the reservoir fishery. 115 refs., 22 figs., 51 tabs.

Chisholm, Ian

1989-12-01T23:59:59.000Z

369

A better understanding of a Uinta Basin channelized analog reservoir through geostatistics and reservoir simulation  

E-Print Network (OSTI)

The Green River Formation is located in the Uinta basin of northeastern Utah. It contains several reservoirs that can be classified as lacustrine such as the Altamont-Bluebell and Red Wash. Lacustrine reservoirs are abundant in other provinces in the world such as China, Southeast Asia, Brazil, West Africa, and the Caspian Sea. Even though they can contain important accumulations of hydrocarbons, our understanding of the primary controls on fluid flow within these systems is still not clear. This ambiguity leads in some cases to inefficient recovery of hydrocarbons in such reservoirs. This study is aimed at clarifying the effects of heterogeneities in channelized reservoirs on fluid flow. It uses a multidisciplinary approach combining geologic knowledge with reservoir engineering. It involves the geologic modeling and fluid flow simulation of a channelized outcrop of the Green River formation. The study of this outcrop provides insights for modeling, understanding, and possibly predicting the behavior of channelized oil and gas reservoirs. Results show that the number of channels in the model can have a significant effect on performance. The rock properties in these channels and the channel paths are also important factors that determine the recovery efficiency. Other findings include the effect on performance of vertical anisotropy in a channelized reservoir. We discovered that an isotropic reservoir performs better than an anisotropic one and that the well perforation interval is extremely important when comparing the performance of several anisotropic cases. Finally, we investigated the effects of the recovery strategy on performance in a channelized setting. We found that waterflooding yields better results than any of the other recovery techniques analyzed. Sensitivity runs with different waterflood patterns indicated that a staggered line drive results in the best performance in the analog channelized reservoir we modeled, as it allows for the best recovery factor in the least amount of time. The results of this work can be used qualitatively to predict performance in a channelized setting but their use is limited quantitatively because of the issue of scale, i.e. the outcrop width is much less than typical interwell scale.

Robbana, Enis

2002-01-01T23:59:59.000Z

370

History match simulation of Serrazzano geothermal reservoir  

DOE Green Energy (OSTI)

The simulator SHAFT79 of Lawrence Berkeley Laboratory has been applied to field-wide distributed parameter simulation of the vapor-dominated geothermal reservoir at Serrazzano, Italy. Using a three-dimensional geologically accurate mesh and detailed flow rate data from 19 producing wells, a period of 15.5 years (from 1959 to 1975) has been simulated. The reservoir model used is based on field measurements of temperatures and pressures, laboratory data for core samples, and available geological and hydrological information. The main parameters determined (adjusted) during development of the simulation are permeabilities and much of the initial conditions. Simulated patterns of pressure decline show semi-quantitative agreement with field observations. The simulation suggests that there is cold water recharge and/or incomplete heat transfer from he rock due to fractures in the margins of the reservoir, and some steam flowing to the main well field originates from deep fractures rather than from boiling in the two-phase zones modeled. Simulation methodology and ambiguity of parameter determination is discussed.

Pruess, K.; Weres, O.; Schroeder, R.; Marconcini, R.; Neri, G.

1980-08-01T23:59:59.000Z

371

SEISMIC DETERMINATION OF RESERVOIR HETEROGENEITY: APPLICATION TO THE CHARACTERIZATION OF HEAVY OIL RESERVOIRS  

SciTech Connect

The objective of the project was to examine how seismic and geologic data can be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study focused on West Coalinga Field in California. The project initially attempted to build reservoir models based on different geologic and geophysical data independently using different tools, then to compare the results, and ultimately to integrate them all. We learned, however, that this strategy was impractical. The different data and tools need to be integrated from the beginning because they are all interrelated. This report describes a new approach to geostatistical modeling and presents an integration of geology and geophysics to explain the formation of the complex Coalinga reservoir.

Matthias G. Imhof; James W. Castle

2005-02-01T23:59:59.000Z

372

SEISMIC DETERMINATION OF RESERVOIR HETEROGENEITY: APPLICATION TO THE CHARACTERIZATION OF HEAVY OIL RESERVOIRS  

SciTech Connect

The objective of the project was to examine how seismic and geologic data can be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. The study focused on West Coalinga Field in California. The project initially attempted to build reservoir models based on different geologic and geophysical data independently using different tools, then to compare the results, and ultimately to integrate them all. Throughout the project, however, we learned that this strategy was impractical because the different data and model are complementary instead of competitive. For the complex Coalinga field, we found that a thorough understanding of the reservoir evolution through geologic times provides the necessary framework which ultimately allows integration of the different data and techniques.

Matthias G. Imhof; James W. Castle

2005-02-01T23:59:59.000Z

373

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

DOE Green Energy (OSTI)

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.

Chisholm, Ian

1985-01-01T23:59:59.000Z

374

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)  

DOE Green Energy (OSTI)

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

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

1988-02-01T23:59:59.000Z

375

Borehole geophysics evaluation of the Raft River geothermal reservoir |  

Open Energy Info (EERE)

reservoir reservoir Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Book: Borehole geophysics evaluation of the Raft River geothermal reservoir Details Activities (1) Areas (1) Regions (0) Abstract: Borehole geophysics techniques were used in evaluating the Raft River geothermal reservoir to establish a viable model for the system. The assumed model for the hot water (145/sup 0/C) 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 water would cause alteration producing these effects. With this model in mind, cross-plots of the above parameters were made to attempt to delineate the reservoir. It appears that the most meaningful data include smoothed and

376

FLUID STRATIGRAPHY OF THE COSO GEOTHERMAL RESERVOIR | Open Energy  

Open Energy Info (EERE)

FLUID STRATIGRAPHY OF THE COSO GEOTHERMAL RESERVOIR FLUID STRATIGRAPHY OF THE COSO GEOTHERMAL RESERVOIR Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference Proceedings: FLUID STRATIGRAPHY OF THE COSO GEOTHERMAL RESERVOIR Details Activities (1) Areas (1) Regions (0) Abstract: A fluid model for the Coso geothermal reservoir is developed from Fluid Inclusion Stratigraphy (FIS) analyses. Fluid inclusion gas chemistry in well cuttings collected at 20 ft intervals is analyzed and plotted on well log diagrams. The working hypothesis is that select gaseous species and species ratios indicate areas of groundwater and reservoir fluid flow, fluid processes and reservoir seals. Boiling and condensate zones are distinguished. Models are created using cross-sections and fence diagrams. A thick condensate and boiling zone is indicated across the western portion

377

Fluid Stratigraphy and Permeable Zones of the Coso Geothermal Reservoir |  

Open Energy Info (EERE)

Stratigraphy and Permeable Zones of the Coso Geothermal Reservoir Stratigraphy and Permeable Zones of the Coso Geothermal Reservoir Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference Proceedings: Fluid Stratigraphy and Permeable Zones of the Coso Geothermal Reservoir Details Activities (1) Areas (1) Regions (0) Abstract: A fence-diagram for the Coso geothermal reservoir is developed from Fluid Inclusion Stratigraphy (FIS) analyses. Fluid inclusion gas chemistry in well cuttings collected at 20 ft intervals is analyzed and plotted on well log diagrams. The working hypothesis is that select gaseous species and species ratios indicate areas of groundwater and reservoir fluid flow, fluid processes and reservoir seals. Boiling and condensate zones are distinguished. Permeable zones are indicated by a large change in

378

Geothermal Reservoir Technology Research Program: Abstracts of selected research projects  

DOE Green Energy (OSTI)

Research projects are described in the following areas: geothermal exploration, mapping reservoir properties and reservoir monitoring, and well testing, simulation, and predicting reservoir performance. The objectives, technical approach, and project status of each project are presented. The background, research results, and future plans for each project are discussed. The names, addresses, and telephone and telefax numbers are given for the DOE program manager and the principal investigators. (MHR)

Reed, M.J. (ed.)

1993-03-01T23:59:59.000Z

379

Seventeenth workshop on geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

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

Ramey, H.J. Jr.; Kruger, P.; Miller, F.G.; Horne, R.N.; Brigham, W.E.; Cook, J.W. (Stanford Geothermal Program) [Stanford Geothermal Program

1992-01-31T23:59:59.000Z

380

Fractured geothermal reservoir growth induced by heat extraction  

DOE Green Energy (OSTI)

Field testing of a hydraulically-stimulated, hot dry rock geothermal system at the Fenton Hill site in northern New Mexico has indicated that significant reservoir growth occurred as energy was extracted. Tracer, microseismic, and geochemical measurements provided the primary quantitative evidence for documenting the increases in accessible reservoir volume and fractured rock surface area that were observed during energy extraction operations which caused substantial thermal drawdown in portions of the reservoir. These temporal increases suggest that augmentation of reservoir heat production capacity in hot dry rock systems may be possible.

Tester, J.W.; Murphy, H.D.; Grigsby, C.O.; Robinson, B.A.; Potter, R.M.

1986-01-01T23:59:59.000Z

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
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they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


381

Hot dry rock geothermal reservoir testing: 1978 to 1980  

DOE Green Energy (OSTI)

Experimental results and re-evaluation of the Phase I Hot Dry Rock Geothermal Energy reservoirs at the Fenton Hill field site are summarized. This report traces reservoir growth as demonstrated during Run Segments 2 through 5 (January 1978 to December 1980). Reservoir growth was caused not only by pressurization and hydraulic fracturing, but also by heat extraction and thermal contraction effects. Reservoir heat-transfer area grew from 8000 to 50,000 m/sup 2/ and reservoir fracture volume grew from 11 to 266 m/sup 3/. Despite this reservoir growth, the water loss rate increased only 30%, under similar pressure environments. For comparable temperature and pressure conditions, the flow impedance (a measure of the resistance to circulation of water through the reservoir) remained essentially unchanged, and if reproduced in the Phase II reservoir under development, could result in self pumping. Geochemical and seismic hazards have been nonexistent in the Phase I reservoirs. The produced water is relatively low in total dissolved solids and shows little tendency for corrosion or scaling. The largest microearthquake associated with heat extraction measures less than -1 on the extrapolated Richter scale.

Dash, Z.V.; Murphy, H.D.; Cremer, G.M. (eds.)

1981-11-01T23:59:59.000Z

382

Scales of geologic reservoir description for engineering applications  

SciTech Connect

A consequence of the increased interaction between geologists and engineers in resolving reservoir problems has been an awareness on the part of geologists of the need to vary the scale of their geologic description according to particular engineering applications. Conventional geological descriptions are normally too detailed for reservoir engineering simulations and often are not in an appropriate form for relating to reservoir performance. An example is presented of two scales of description of a North Sea oil field for two different applications. The field is a Tertiary submarine slope-fan deposit consisting of thick unconsolidated channel sand facies, a lobe sand facies, and a slope claystone facies, all arranged into 12 stratigraphic units and several subunits. Permeability of the channel sands is about twice that of lobe sands, demonstrating a facies control on reservoir quality. For the purpose of calculating reservoir volumetrics, it was possible to scale up the stratigraphy, by combining similar stratigraphic units, into a simple four-layer reservoir model. Average porosity and permeability vary among the layers in this geologically based model. For the purpose of improving understanding of the reservoir, a more complex flow unit model was developed according to geological and petrophysical properties that would influence the flow of fluids in the reservoir. This model is partly based upon sedimentary facies distribution, but differs from a geologic facies model and is in a more suitable form for relating to reservoir performance.

Slatt, R.M.; Hopkins, G.L.

1988-01-01T23:59:59.000Z

383

Numerical simulation of water injection into vapor-dominated reservoirs  

DOE Green Energy (OSTI)

Water injection into vapor-dominated reservoirs is a means of condensate disposal, as well as a reservoir management tool for enhancing energy recovery and reservoir life. We review different approaches to modeling the complex fluid and heat flow processes during injection into vapor-dominated systems. Vapor pressure lowering, grid orientation effects, and physical dispersion of injection plumes from reservoir heterogeneity are important considerations for a realistic modeling of injection effects. An example of detailed three-dimensional modeling of injection experiments at The Geysers is given.

Pruess, K.

1995-01-01T23:59:59.000Z

384

,"Shale 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","Shale Natural Gas New Reservoir Discoveries in Old Fields ",36,"Annual",2011,"6302009"...

385

Miscellaneous States Shale Gas Proved Reserves New Reservoir...  

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

to avoid disclosure of individual company data. Release Date: 812013 Next Release Date: 812014 Referring Pages: Shale Natural Gas New Reservoir Discoveries in Old Fields...

386

INJECTION AND THERMAL BREAKTHROUGH IN FRACTURED GEOTHERMAL RESERVOIRS  

E-Print Network (OSTI)

and Pruess, K. , Analysis of injection testing of geothermalreservoirs: Geothermal Resoures Council, Vol. 4. , (into a fractured geothermal reservoir: Transactions, Vol. 4,

Bodvarsson, Gudmundur S.

2012-01-01T23:59:59.000Z

387

,"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",2011 ,"Release...

388

,"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",2011 ,"Release...

389

,"New Mexico Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","New Mexico Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)",1,"Annual",2011 ,"Release...

390

,"New York Crude Oil Reserves in Nonproducing Reservoirs (Million...  

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

Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description"," Of Series","Frequency","Latest...

391

,"Miscellaneous States Crude Oil Reserves in Nonproducing Reservoirs...  

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

Of Series","Frequency","Latest Data for" ,"Data 1","Miscellaneous States Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)",1,"Annual",2011 ,"Release...

392

FRACSTIM/I: An Integrated Fracture Stimulation and Reservoir...  

Open Energy Info (EERE)

An Integrated Fracture Stimulation and Reservoir Flow and Transport Simulator Geothermal Lab Call Project Jump to: navigation, search Last modified on July 22, 2011. Project Title...

393

An Integrated Study Method For Exploration Of Gas Hydrate Reservoirs...  

Open Energy Info (EERE)

Login | Sign Up Search Page Edit with form History Facebook icon Twitter icon An Integrated Study Method For Exploration Of Gas Hydrate Reservoirs In Marine Areas Jump to:...

394

Field Algae Measurements Using Empirical Correlations at Deer Creek Reservoir.  

E-Print Network (OSTI)

??Deer Creek Reservoir in Utah has a history of high algae concentrations. Despite recent nutrient reduction efforts, seasonal algae continue to present problems. Cost effective, (more)

Stephens, Ryan A

2011-01-01T23:59:59.000Z

395

Carbonation Mechanism of Reservoir Rock by Supercritical Carbon...  

Open Energy Info (EERE)

Technologies Project Type Topic 2 Supercritical Carbon Dioxide Reservoir Rock Chemical Interactions Project Description Supercritical CO2 is currently becoming a more...

396

Modeling Of Hydraulic Fracture Network Propagation In Shale Gas Reservoirs.  

E-Print Network (OSTI)

??The most effective method for stimulating shale gas reservoirs is massive hydraulic fracture treatments. Recent fracture diagnostic technologies such as microseismic technology have shown that (more)

Ahn, Chong

2012-01-01T23:59:59.000Z

397

Optimizing Development Strategies to Increase Reserves in Unconventional Gas Reservoirs  

E-Print Network (OSTI)

The ever increasing energy demand brings about widespread interest to rapidly, profitably and efficiently develop unconventional resources, among which tight gas sands hold a significant portion. However, optimization of development strategies in tight gas fields is challenging, not only because of the wide range of depositional environments and large variability in reservoir properties, but also because the evaluation often has to deal with a multitude of wells, limited reservoir information, and time and budget constraints. Unfortunately, classical full-scale reservoir evaluation cannot be routinely employed by small- to medium-sized operators, given its timeconsuming and expensive nature. In addition, the full-scale evaluation is generally built on deterministic principles and produces a single realization of the reservoir, despite the significant uncertainty faced by operators. This work addresses the need for rapid and cost-efficient technologies to help operators determine optimal well spacing in highly uncertain and risky unconventional gas reservoirs. To achieve the research objectives, an integrated reservoir and decision modeling tool that fully incorporates uncertainty was developed. Monte Carlo simulation was used with a fast, approximate reservoir simulation model to match and predict production performance in unconventional gas reservoirs. Simulation results were then fit with decline curves to enable direct integration of the reservoir model into a Bayesian decision model. These integrated tools were applied to the tight gas assets of Unconventional Gas Resources Inc. in the Berland River area, Alberta, Canada.

Turkarslan, Gulcan

2010-08-01T23:59:59.000Z

398

Synchrotron X-ray Studies of Supercritical Carbon Dioxide/ Reservoir...  

Open Energy Info (EERE)

Edit with form History Facebook icon Twitter icon Synchrotron X-ray Studies of Supercritical Carbon Dioxide Reservoir Rock Interfaces Geothermal Lab Call Project Jump to:...

399

Application of thermal depletion model to geothermal reservoirs...  

Open Energy Info (EERE)

of thermal depletion model to geothermal reservoirs with fracture and pore permeability Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference Proceedings:...

400

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

Open Energy Info (EERE)

and Analysis of Reservoir Data from Testing and Operation of the Raft River 5 MW Power Plant Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference...

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


401

Geothermal Reservoir Assessment Case Study, Northern Basin and...  

Open Energy Info (EERE)

GLO2386 DOI Not Provided Check for DOI availability: http:crossref.org Online Internet link for Geothermal Reservoir Assessment Case Study, Northern Basin and Range...

402

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

Open Energy Info (EERE)

NA, 2002 DOI Not Provided Check for DOI availability: http:crossref.org Online Internet link for FMI Borehole Geology, Geomechanics and 3D Reservoir Modeling Citation...

403

Numerical Modeling of Gas Recovery from Methane Hydrate Reservoirs.  

E-Print Network (OSTI)

??ABSTRACTClass 1 hydrate deposits are characterized by a hydrate bearing layer underlain by a two phase, free-gas and water, zone. A Class 1 hydrate reservoir (more)

Silpngarmlert, Suntichai

2007-01-01T23:59:59.000Z

404

AN ADVISORY SYSTEM FOR THE DEVELOPMENT OF UNCONVENTIONAL GAS RESERVOIRS.  

E-Print Network (OSTI)

??With the rapidly increasing demand for energy and the increasing prices for oil and gas, the role of unconventional gas reservoirs (UGRs) as energy sources (more)

Wei, Yunan

2010-01-01T23:59:59.000Z

405

Evaluation of testing and reservoir parameters in geothermal...  

Open Energy Info (EERE)

testing and reservoir parameters in geothermal wells at Raft River and Boise, Idaho Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference Proceedings: Evaluation...

406

,"U.S. Coalbed Methane Proved Reserves New Reservoir Discoveries...  

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

ame","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","U.S. Coalbed Methane Proved Reserves New Reservoir Discoveries in Old Fields (Billion Cubic...

407

Evaluation of Fluid Transport Properties of Coal Bed Methane Reservoirs.  

E-Print Network (OSTI)

??Determination of petro-physical properties of coal bed methane (CBM) reservoirs is essential in evaluating a potential prospect for commercial exploitation. In particular, permeability is the (more)

Alexis, Dennis Arun

2013-01-01T23:59:59.000Z

408

Use Of Electrical Surveys For Geothermal Reservoir Characterization...  

Open Energy Info (EERE)

Use Of Electrical Surveys For Geothermal Reservoir Characterization- Beowawe Geothermal Field Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference Paper: Use Of...

409

Steamflooding as an alternative EOR process for light oil reservoirs  

Science Conference Proceedings (OSTI)

This paper seeks to stimulate consideration of steamflooding as a viable alternative to chemical enhanced oil recovery (EOR) techniques in shallow, light-oil reservoirs. A highly implicit steamflood reservoir simulator was used to predict steamflood performance of a typical shallow oil reservoir. For this study, non-uniform oil saturations were created by simulating a waterflood prior to initiating each steam injection case. The effects of final waterflood water-oil ratio, reservoir thickness, and amount of distillable component in the crude were examined. 10 refs.

Hanzlik, E.J.

1981-01-01T23:59:59.000Z

410

,"California 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","California Dry Natural Gas New Reservoir Discoveries in Old Fields (Billion Cubic...

411

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:...

412

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

Open Energy Info (EERE)

and wells. (SINDA-3G program) Details Activities (1) Areas (1) Regions (0) Abstract: Computer models describing both the transient reservoir pressure behavior and the time...

413

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

Annual Energy Outlook 2012 (EIA)

Aquifer Storage Reservoir Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 20072008 with selected updates Aquifer Underground...

414

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

Annual Energy Outlook 2012 (EIA)

Depleted Reservoir Storage Configuration About U.S. Natural Gas Pipelines - Transporting Natural Gas based on data through 20072008 with selected updates Depleted Production...

415

,"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...

416

The Optimization of Well Spacing in a Coalbed Methane Reservoir  

E-Print Network (OSTI)

Numerical reservoir simulation has been used to describe mechanism of methane gas desorption process, diffusion process, and fluid flow in a coalbed methane reservoir. The reservoir simulation model reflects the response of a reservoir system and the relationship among coalbed methane reservoir properties, operation procedures, and gas production. This work presents a procedure to select the optimum well spacing scenario by using a reservoir simulation. This work uses a two-phase compositional simulator with a dual porosity model to investigate well-spacing effects on coalbed methane production performance and methane recovery. Because of reservoir parameters uncertainty, a sensitivity and parametric study are required to investigate the effects of parameter variability on coalbed methane reservoir production performance and methane recovery. This thesis includes a reservoir parameter screening procedures based on a sensitivity and parametric study. Considering the tremendous amounts of simulation runs required, this work uses a regression analysis to replace the numerical simulation model for each wellspacing scenario. A Monte Carlo simulation has been applied to present the probability function. Incorporated with the Monte Carlo simulation approach, this thesis proposes a well-spacing study procedure to determine the optimum coalbed methane development scenario. The study workflow is applied in a North America basin resulting in distinct Net Present Value predictions between each well-spacing design and an optimum range of well-spacing for a particular basin area.

Sinurat, Pahala Dominicus

2010-12-01T23:59:59.000Z

417

,"New Mexico--West Crude Oil Reserves in Nonproducing Reservoirs...  

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

Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description"," Of Series","Frequency","Latest...

418

,"New Mexico--East Crude Oil Reserves in Nonproducing Reservoirs...  

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

Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description"," Of Series","Frequency","Latest...

419

,"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...

420

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

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

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

Note: This page contains sample records for the topic "wellhead reservoir temp" from the National Library of EnergyBeta (NLEBeta).
While these samples are representative of the content of NLEBeta,
they are not comprehensive nor are they the most current set.
We encourage you to perform a real-time search of NLEBeta
to obtain the most current and comprehensive results.


421

Transient pressure analysis in composite reservoirs  

Science Conference Proceedings (OSTI)

The problem of fluid flow in a radially composite reservoir is discussed. Recently published was the most general analytic solution available thus far. That analytic solution is analyzed, and the results are presented. The solution is dependent upon the following dimensionless parameters (if well-bore storage and skin effect are neglected): (1) dimensionless time based on the discontinuity radius, (2) the dimensionless discontinuity radius, (3) the mobility ratio, and (4) the diffusivity ratio. The range of parameters used in generating the results include dimensionless radius time of 0.01 t

Tang, R.W.K.; Brigham, W.E.

1982-08-01T23:59:59.000Z

422

Geothermal Reservoir Well Stimulation Program: technology transfer  

DOE Green Energy (OSTI)

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)

Not Available

1980-05-01T23:59:59.000Z

423

APPLICATION OF RESERVOIR CHARACTERIZATION AND ADVANCED TECHNOLOGY TO IMPROVE RECOVERY AND ECONOMICS IN A LOWER QUALITY SHALLOW SHELF SANANDRES RESERVOIR  

Science Conference Proceedings (OSTI)

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; (7) Mobility control agents.

Unknown

2003-01-15T23:59:59.000Z

424

Seismic Determination of Reservoir Heterogeneity: Application to the Characterization of Heavy Oil Reservoirs  

SciTech Connect

The objective of the project was to examine how seismic and geologic data could be used to improve characterization of small-scale heterogeneity and their parameterization in reservoir models. Performed a theoretical and numerical study to examine which subsurface features the surface seismic method actually resolves.

Imhof, Matthias G.; Castle, James W.

2003-03-12T23:59:59.000Z

425

Modelling the propagation of turbid density inflows into a stratified lake: Daecheong Reservoir, Korea  

Science Conference Proceedings (OSTI)

Many reservoirs and associated downstream ecosystems located in the Asian monsoon climate region are under increased pressure from the long-term negative effects of turbid flood runoff. Despite the ubiquitous use of turbidity (C"T) as a barometer of ... Keywords: Daecheong Reservoir, ELCOM-CAEDYM, Real-time reservoir management, Reservoir density flow, Stratified reservoir, Turbidity modelling

S. W. Chung; M. R. Hipsey; J. Imberger

2009-12-01T23:59:59.000Z

426

Use of TOUGHREACT to Simulate Effects of Fluid Chemistry on Injectivity in Fractured Geothermal Reservoirs with High Ionic Strength Fluids  

E-Print Network (OSTI)

be close to the produced reservoir water without surfaceof directly using the produced reservoir water, the Pitzerusing the produced reservoir and the mixing waters for each

Xu, Tianfu; Zhang, Guoxiang; Pruess, Karsten

2005-01-01T23:59:59.000Z

427

DESCRIPTION OF THE THREE-DIMENSIONAL TWO-PHASE SIMULATOR SHAFT78 FOR USE IN GEOTHERMAL RESERVOIR STUDIES  

E-Print Network (OSTI)

i n Vapor-Dominated Geothermal Reservoirs, I' Report No. 76-G. : Three- . Dimensional Geothermal Reservoir Simulation,f1161. Coats, K. H. : "Geothermal Reservoir Modeling," paper

Pruess, K.

2011-01-01T23:59:59.000Z

428

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

DOE Green Energy (OSTI)

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)

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

1985-09-01T23:59:59.000Z

429

Application of integrated reservoir management and reservoir characterization to optimize infill drilling. Annual report, June 13, 1994--June 12, 1995  

SciTech Connect

This project has used a multi-disciplinary approach employing geology, geophysics, and engineering to conduct advanced reservoir characterization and management activities to design and implement an optimized infill drilling program at the North Robertson (Clearfork) Unit in Gaines County, Texas. The activities during the first Budget Period have consisted of developing an integrated reservoir description from geological, engineering, and geostatistical studies, and using this description for reservoir flow simulation. Specific reservoir management activities are being identified and tested. The geologically targeted infill drilling program will be implemented using the results of this work. A significant contribution of this project is 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 shallow-shelf carbonate (SSC) reservoirs. The techniques that are outlined for the formulation of an integrated reservoir description apply to all oil and gas reservoirs, but are specifically tailored for use in the heterogeneous, low permeability carbonate reservoirs of West Texas.

Pande, P.K.

1996-11-01T23:59:59.000Z

430

Multigrid methods with applications to reservoir simulation  

Science Conference Proceedings (OSTI)

Multigrid methods are studied for solving elliptic partial differential equations. Focus is on parallel multigrid methods and their use for reservoir simulation. Multicolor Fourier analysis is used to analyze the behavior of standard multigrid methods for problems in one and two dimensions. Relation between multicolor and standard Fourier analysis is established. Multiple coarse grid methods for solving model problems in 1 and 2 dimensions are considered; at each coarse grid level we use more than one coarse grid to improve convergence. For a given Dirichlet problem, a related extended problem is first constructed; a purification procedure can be used to obtain Moore-Penrose solutions of the singular systems encountered. For solving anisotropic equations, semicoarsening and line smoothing techniques are used with multiple coarse grid methods to improve convergence. Two-level convergence factors are estimated using multicolor. In the case where each operator has the same stencil on each grid point on one level, exact multilevel convergence factors can be obtained. For solving partial differential equations with discontinuous coefficients, interpolation and restriction operators should include information about the equation coefficients. Matrix-dependent interpolation and restriction operators based on the Schur complement can be used in nonsymmetric cases. A semicoarsening multigrid solver with these operators is used in UTCOMP, a 3-D, multiphase, multicomponent, compositional reservoir simulator. The numerical experiments are carried out on different computing systems. Results indicate that the multigrid methods are promising.

Xiao, Shengyou

1994-05-01T23:59:59.000Z

431

INNOVATIVE MIOR PROCESS UTILIZING INDIGENOUS RESERVOIR CONSTITUENTS  

Science Conference Proceedings (OSTI)

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.

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

2003-09-01T23:59:59.000Z

432

Twentieth workshop on geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

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

None

1995-01-26T23:59:59.000Z

433

INNOVATIVE MIOR PROCESS UTILIZING INDIGENOUS RESERVOIR CONSTITUENTS  

SciTech Connect

This research program is directed at improving the knowledge of reservoir ecology and developing practical microbial solutions for improving oil production. The goal is 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. Research has begun on the program and experimental laboratory work is underway. Polymer-producing cultures have been isolated from produced water samples and initially characterized. Concurrently, a microcosm scale sand-packed column has been designed and developed for testing cultures of interest, including polymer-producing strains. In research that is planned to begin in future work, comparative laboratory studies demonstrating in situ production of microbial products as oil recovery agents will be conducted in sand pack and cores with synthetic and natural field waters at concentrations, flooding rates, and with cultures and conditions representative of oil reservoirs.

D.O. Hitzman; S.A. Bailey

2000-01-01T23:59:59.000Z

434

Controls on reservoir development in Devonian Chert: Permian Basin, Texas  

SciTech Connect

Chert reservoirs of the Lower Devonian Thirtyone Formation contain a significant portion of the hydrocarbon resource in the Permian basin. More than 700 million bbl of oil have been produced from these rocks, and an equivalent amount of mobile oil remains. Effective exploitation of this sizable remaining resource, however, demands a comprehensive appreciation of the complex factors that have contributed to reservoir development. Analysis of Thirtyone Formation chert deposits in Three Bar field and elsewhere in the Permian basin indicates that reservoirs display substantial heterogeneity resulting from depositional, diagenetic, and structural processes. Large-scale reservoir geometries and finer scale, intra-reservoir heterogeneity are primarily attributable to original depositional processes. Despite facies variations, porosity development in these cherts is principally a result of variations in rates and products of early silica diagenesis. Because this diagenesis was in part a function of depositional facies architecture, porosity development follows original depositional patterns. In reservoirs such as Three Bar field, where the Thirtyone Formation has been unroofed by Pennsylvanian deformation, meteoric diagenesis has created additional heterogeneity by causing dissolution of chert and carbonate, especially in areas of higher density fracturing and faulting and along truncated reservoir margins. Structural deformation also has exerted direct controls on heterogeneity that are particularly noteworthy in reservoirs under waterflood. High-density fracture zones create preferred flow paths that result in nonuniform sweep through the reservoir. Faulting locally creates compartments by offsetting reservoir flow units. As such, the processes and models defined here improve understanding of the causes of heterogeneity in all Thirtyone chert reservoirs in the Permian basin and aid recovery of the sizable hydrocarbon resource remaining in these rocks.

Ruppel, S.C.; Hovorka, S.D. [Univ. of Texas, Austin, TX (United States)

1995-12-01T23:59:59.000Z

435

Sixth workshop on geothermal reservoir engineering: Proceedings  

SciTech Connect

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

Ramey, H.J. Jr.; Kruger, P. (eds.)

1980-12-18T23:59:59.000Z

436

Sixth workshop on geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

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

Ramey, H.J. Jr.; Kruger, P. (eds.)

1980-12-18T23:59:59.000Z

437

Natural Gas Wellhead Price - Energy Information Administration  

U.S. Energy Information Administration (EIA)

... electric power price data are for regulated electric ... Gas volumes delivered for vehicle fuel are included in the State monthly totals from January 2011 ...

438

Natural Gas Wellhead Price - Energy Information Administration  

U.S. Energy Information Administration (EIA)

-No Data Reported; --= Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Notes: Prices are in ...

439

Reservoir description breathes new life into an old fireflood  

SciTech Connect

The MOCO T reservoir is a Miocene-age (''Stevens equivalent,'' Monterey Formation) unconsolidated sand reservoir in the Midway-Sunset field, Kern County, California. This reservoir was discovered in 1957 as a deeper pay beneath the Monarch and Webster reservoirs. Due to low prices for heavy oil (14/sup 0/ API), the MOCO T was only partially developed and remained essentially shut-in until initiation of in-situ combustion in 1960. Exploitation of the MOCO T by the combustion process continues today, with cumulative production to date of approximately 14 million bbl of oil. The MOCO T reservoir is approximately 500 ft thick and lies at an average drill depth of 2,100-2,700 ft. Based on modern core data and sand distribution maps, these sands were probably deposited by channelized turbidity currents that flowed southwest to northwest in this area. Detailed recorrelation of wireline logs, stratigraphic zonation, and description of individual zones of the MOCO T reservoir in the context of a channelized turbidite system have led to: (1) determination of probable flow paths, vertically and laterally, between injectors and producers by zone, (2) control for workovers to optimize conformance between injection and production intervals, and (3) identification of previously unrecognized and undeveloped reserves. Integration of this geologic model with an understanding of how the combustion front has advanced through the MOCO T reservoir has led to successful placement of infill wells to produce the reservoir more efficiently and completely.

Hall, B.R.

1988-01-01T23:59:59.000Z

440

Application of horizontal wells in steeply dipping reservoirs  

E-Print Network (OSTI)

A three-dimensional reservoir simulation study is performed to evaluate the impact of horizontal well applications on oil recovery from steeply dipping reservoirs. The Provincia field, located in Colombia, provided the basic reservoir information for the study. Reservoir simulation results indicate that for reservoir dip angles greater than about 40', this parameter has little or no effect on the primary recovery performance for homogeneous high-permeability reservoirs, The initial gascap size and the anisotropy of permeability (kv/kh ratio) are the dominant parameters affecting the oil recovery. For thin reservoirs, the location of the horizontal injector will not significantly affect the oil recovery. Simultaneous gas and water injection through horizontal wells can increase the oil recovery factor from almost 35% under primary production to 40%. A significant incremental oil recovery could be expected by employing horizontal wells for simultaneous gas and water injection. A comparison of the production performance of horizontal and vertical producers shows that a horizontal well can produce oil up to 2.5 times the oil rate of a vertical well, without a high rate of gas production. Also, the use of horizontal producers significantly accelerates the oil recovery. For the case of a homogeneous reservoir under simultaneous gas and water injection, the horizontal well system does not give a significant increment in the oil recovery compared to the vertical well system.

Lopez Navarro, Jose David

1995-01-01T23:59:59.000Z

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441

Reservoir and injection technology and Heat Extraction Project  

DOE Green Energy (OSTI)

For the Stanford Geothermal Program in the fiscal year 1989, the task areas include predictive modeling of reservoir behavior and tracer test interpretation and testing. Major emphasis is in reservoir technology, reinjection technology, and heat extraction. Predictive modeling of reservoir behavior consists of a multi-pronged approach to well test analysis under a variety of conditions. The efforts have been directed to designing and analyzing well tests in (1) naturally fractured reservoirs; (2) fractured wells; (3) complex reservoir geometries; and, (4) gas reservoirs including inertial and other effects. The analytical solutions for naturally fractured reservoirs are determined using fracture size distribution. In the study of fractured wells, an elliptical coordinate system is used to obtain semi-analytical solutions to finite conductivity fractures. Effort has also been directed to the modeling and creation of a user friendly computer program for steam/gas reservoirs including wellbore storage, skin and non-Darcy flow effects. This work has a complementary effort on modeling high flow rate wells including inertial effects in the wellbore and fractures. In addition, work on gravity drainage systems is being continued.

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

1989-12-31T23:59:59.000Z

442

Resolution of reservoir scale electrical anisotropy from marine CSEM data  

Science Conference Proceedings (OSTI)

A combination of 1D and 3D forward and inverse solutions is used to quantify the sensitivity and resolution of conventional controlled source electromagnetic (CSEM) data collected using a horizontal electric dipole source to transverse electrical anisotropy located in a deep-water exploration reservoir target. Since strongly anisotropic shale layers have a vertical resistivity that can be comparable to many reservoirs, we examine how CSEM can discriminate confounding shale layers through their characteristically lower horizontal resistivity. Forward modeling demonstrates that the sensitivity to reservoir level anisotropy is very low compared to the sensitivity to isotropic reservoirs, especially when the reservoir is deeper than about 2 km below the seabed. However, for 1D models where the number of inversion parameters can be fixed to be only a few layers, both vertical and horizontal resistivity of the reservoir can be well resolved using a stochastic inversion. We find that the resolution of horizontal resistivity increases as the horizontal resistivity decreases. We show that this effect is explained by the presence of strong horizontal current density in anisotropic layers with low horizontal resistivity. Conversely, when the reservoir has a vertical to horizontal resistivity ratio of about 10 or less, the current density is vertically polarized and hence has little sensitivity to the horizontal resistivity. Resistivity anisotropy estimates from 3D inversion for 3D targets suggest that resolution of reservoir level anisotropy for 3D targets will require good a priori knowledge of the background sediment conductivity and structural boundaries.

Brown, V.; Hoversten, G.M.; Key, K.; Chen, J.

2011-10-01T23:59:59.000Z

443

Water reservoir control under economic, social and environmental constraints  

Science Conference Proceedings (OSTI)

Although great progress has been made in the last 40 years, efficient operation of water reservoir systems still remains a very active research area. The combination of multiple water uses, non-linearities in the model and in the objectives, strong uncertainties ... Keywords: Multiobjective optimisation, Multipurpose water reservoirs, Nonlinear control, Stochastic control, Uncertain dynamic systems

Andrea Castelletti; Francesca Pianosi; Rodolfo Soncini-Sessa

2008-06-01T23:59:59.000Z

444

Research to understand and predict geopressured reservoir characteristics with confidence  

DOE Green Energy (OSTI)

The Department of Energy's Geopressured Geothermal Program has sponsored a series of geoscience studies to resolve key uncertainties in the performance of geopressured reservoirs. The priority areas for research include improving the ability to predict reservoir size and flow capabilities, understanding the role of oil and gas in reservoir depletion and evaluating mechanisms for reservoir pressure maintenance. Long-term production from the Gladys McCall well has provided the basis for most of the current research efforts. The well was shut-in on October 29, 1987, for pressure recovery after producing over 27 million barrels of brine with associated gas. Geologic investigations are evaluating various mechanisms for pressure maintenance in this reservoir, including recharge from adjacent reservoirs or along growth faults, shale dewatering, and laterally overlapping and connected sandstone layers. Compaction studies using shale and sandstone core samples have provided data on the relationship between rock compression and reservoir pressure decline and the correlation to changes in porosity and permeability. The studies support the use of a porosity-coupled reservoir simulation model which has provided an excellent match to the well's production history. 10 refs., 3 figs.

Stiger, S.G.; Prestwich, S.M.

1988-01-01T23:59:59.000Z

445

Feasibility of waterflooding Soku E7000 gas-condensate reservoir  

E-Print Network (OSTI)

We performed a simple 3D compositional reservoir simulation study to examine the possibility of waterflooding the Soku E7 gas-condensate reservoir. This study shows that water injection results in higher condensate recovery than natural depletion. To achieve this recovery, the reservoir should return to natural depletion after four years of water injection, before water invades the producing wells. Factors that affect the effectiveness of water injection in this reservoir include aquifer strength, reservoir property distribution, timing of the start of injection, and intra-reservoir shale thickness and continuity. Sensitivity analyses used to quantify the effects of these factors on condensate recovery indicate the need to acquire more production, pressure and log data to reduce the present large uncertainty on aquifer strength before proceeding on waterflooding this reservoir. The study also shows that the injection scheme should be implemented as soon as possible to avoid further loss of condensate recovery. The result of this study is applicable to other gas condensate reservoirs in the Niger delta with similar depositional environments.

Ajayi, Arashi

2002-01-01T23:59:59.000Z

446

Analysis of reservoir performance and forecasting for the eastern area of the C-2 Reservoir, Lake Maracaibo, Venezuela  

E-Print Network (OSTI)

This research developed a numerical simulation based on the latest reservoir description to evaluate the feasibility of new infill wells to maximize the recovery specifically in the eastern region of the reservoir operated by Petroleos de Venezuela S.A. (PDVSA). This research provides a full-field numerical simulation that predicts performance and aids in planning future development with infill wells for a reservoir located at the south of Block V, Lamar in Lake Maracaibo. The simulation is especially promising for the eastern region, which has the current highest oil production behavior. The final model achieved an acceptable history match for pressure and fluids for the entire reservoir, especially for the eastern area. On the basis of this model and an opportunity index, the best six infill wells should be located in the eastern area of the reservoir, which would increased the cumulated production in 44.5 MMSTB. This work is important because it provides the first numerical simulation for the entire reservoir that considers the new geological model developed during reservoir description. Furthermore, it provides PDVSA with a powerful tool for planning and reservoir management decisions, especially in the eastern area of the reservoir. Predictions resulting from this area show an important increment in the final reservoir recovery over the base case, production depletion under current conditions without any change. On the basis of these results, I strongly recommend starting a new infill drilling campaign in the eastern area as indicated by the simulation results to increase the oil rate reservoir productions and to improve total ultimate recovery.

Urdaneta Anez, Jackeline C

2001-01-01T23:59:59.000Z

447

Geothermal Reservoir Assessment Case Study, Northern Basin and Range  

Open Energy Info (EERE)

Reservoir Assessment Case Study, Northern Basin and Range Reservoir Assessment Case Study, Northern Basin and Range Province, Northern Dixie Valley, Nevada Jump to: navigation, search OpenEI Reference LibraryAdd to library Report: Geothermal Reservoir Assessment Case Study, Northern Basin and Range Province, Northern Dixie Valley, Nevada Abstract N/A Authors Elaine J. Bell, Lawrence T. Larson and Russell W. Juncal Published U.S. Department of Energy, 1980 Report Number GLO2386 DOI Not Provided Check for DOI availability: http://crossref.org Online Internet link for Geothermal Reservoir Assessment Case Study, Northern Basin and Range Province, Northern Dixie Valley, Nevada Citation Elaine J. Bell,Lawrence T. Larson,Russell W. Juncal. 1980. Geothermal Reservoir Assessment Case Study, Northern Basin and Range Province,

448

Decline curve derivative analysis for homogeneous and composite reservoirs  

DOE Green Energy (OSTI)

In this study, the rate decline and rate decline derivatives of a constant pressure well are presented for infinite, constant pressure outer boundary, and closed outer boundary homogeneous reservoirs. A rate derivative type curve is provided for these cases as well. The effects of the dimensionless reservoir exterior radius are discussed. Rate decline and rate decline derivatives of a constant pressure well in an infinite composite reservoir are also presented. For composite reservoirs, the effects of mobility ratios and discontinuity distance on both rate decline and rate decline derivatives are presented. Type curves for dimensionless wellbore flow rate derivatives for infinite composite reservoirs are provided. A new correlating group for the derivative type curve is provided, and is different than the correlating group for the rate type curve presented in the past. Finally, an analysis method that comprises type curve and derivative type curve matching to determine the dimensionless variables is proposed and demonstrated with a simulated example.

Demski, J.A.

1987-06-01T23:59:59.000Z

449

Transient well testing in two-phase geothermal reservoirs  

DOE Green Energy (OSTI)

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.

Aydelotte, S.R.

1980-03-01T23:59:59.000Z

450

Physical model of a fractured reservoir | Open Energy Information  

Open Energy Info (EERE)

model of a fractured reservoir model of a fractured reservoir Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Conference Proceedings: Physical model of a fractured reservoir Details Activities (1) Areas (1) Regions (0) Abstract: The objectives of the physical modeling effort are to: (1) evaluate injection-backflow testing for fractured reservoirs under conditions of known reservoir parameters (porosity, fracture width, etc.); (2) study the mechanisms controlling solute transport in fracture systems; and (3) provide data for validation of numerical models that explicitly simulate solute migration in fracture systems. The fracture network is 0.57-m wide, 1.7-m long, and consists of two sets of fractures at right angles to one another with a fracture spacing of 10.2 cm. A series of

451

Characterization of geothermal reservoir crack patterns using shear-wave  

Open Energy Info (EERE)

geothermal reservoir crack patterns using shear-wave geothermal reservoir crack patterns using shear-wave splitting Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Journal Article: Characterization of geothermal reservoir crack patterns using shear-wave splitting Details Activities (1) Areas (1) Regions (0) Abstract: Microearthquakes recorded by a downhole, three-component seismic network deployed around the Coso, California, geothermal reservoir since 1992 display distinctive shear-wave splitting and clear polarization directions. From the polarizations the authors estimated three predominant subsurface fracture directions, and from the time delays of the split waves they determined tomographically the 3-D fracture density distribution in the reservoir. Author(s): Lou, M.; Rial, J.A. Published: Geophysics, 3/1/1997

452

Tectonic setting of the Coso geothermal reservoir | Open Energy Information  

Open Energy Info (EERE)

Tectonic setting of the Coso geothermal reservoir Tectonic setting of the Coso geothermal reservoir Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Journal Article: Tectonic setting of the Coso geothermal reservoir Details Activities (1) Areas (1) Regions (0) Abstract: The Coso geothermal reservoir is being developed in Sierran-type crystalline bedrock of the Coso Mountains, a small desert mountain range just to the east of the Sierra Nevada and Rose Valley, which is the southern extension of the Owens Valley of eastern California Optimum development of this reservoir requires an understanding of the fracture hydrology of the Coso Mountains crystalline terrain and its hydrologic connection to regional groundwater and thermal sources. An interpreted, conceptually balanced regional cross section that extends from the Sierra

453

Dams and Reservoirs Safety Act (South Carolina) | Department of Energy  

Energy.gov (U.S. Department of Energy (DOE)) Indexed Site

Dams and Reservoirs Safety Act (South Carolina) Dams and Reservoirs Safety Act (South Carolina) Dams and Reservoirs Safety Act (South Carolina) < Back Eligibility Utility Commercial Agricultural Investor-Owned Utility Industrial Construction Municipal/Public Utility Local Government Installer/Contractor Rural Electric Cooperative Tribal Government Institutional Savings Category Water Buying & Making Electricity Program Info State South Carolina Program Type Siting and Permitting Provider South Carolina Department of Health and Environmental Control The Dams and Reservoirs Safety Act provides for the certification and inspection of dams in South Carolina and confers regulatory authority on the Department of Health and Environmental Control. Owners of dams and reservoirs are responsible for maintaining the safety of the structures,

454

Integrated Seismic Studies At The Rye Patch Geothermal Reservoir, Nevada |  

Open Energy Info (EERE)

Seismic Studies At The Rye Patch Geothermal Reservoir, Nevada Seismic Studies At The Rye Patch Geothermal Reservoir, Nevada Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Book: Integrated Seismic Studies At The Rye Patch Geothermal Reservoir, Nevada Details Activities (2) Areas (1) Regions (0) Abstract: A 3-D surface seismic reflection survey, covering an area of over 3 square miles, was conducted at the Rye Patch geothermal reservoir (Nevada) to explore the structural features that may control geothermal production in the area. In addition to the surface sources and receivers, a high-temperature three-component seismometer was deployed in a borehole at a depth of 3900 ft within the basement below the reservoir, which recorded the waves generated by all surface sources. A total of 1959 first-arrival travel times were determined out of 2134 possible traces. Two-dimensional

455

Opportunities to improve oil productivity in unstructured deltaic reservoirs  

SciTech Connect

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.

Not Available

1991-01-01T23:59:59.000Z

456

Heat Extraction Project, geothermal reservoir engineering research at Stanford  

DOE Green Energy (OSTI)

The main objective of the SGP Heat Extraction Project is to provide a means for estimating the thermal behavior of geothermal fluids produced from fractured hydrothermal resources. The methods are based on estimated thermal properties of the reservoir components, reservoir management planning of production and reinjection, and the mixing of reservoir fluids: geothermal, resource fluid cooled by drawdown and infiltrating groundwater, and reinjected recharge heated by sweep flow through the reservoir formation. Several reports and publications, listed in Appendix A, describe the development of the analytical methods which were part of five Engineer and PhD dissertations, and the results from many applications of the methods to achieve the project objectives. The Heat Extraction Project is to evaluate the thermal properties of fractured geothermal resource and forecasted effects of reinjection recharge into operating reservoirs.

Kruger, P.

1989-01-01T23:59:59.000Z

457

Technical feasibility of chemical flooding in California reservoirs  

SciTech Connect

A study of the applicability of chemical flooding to California is presented. It is shown that the five processes reviewed (CO/sub 2/), micellar-polymer, polymer, caustic and hydrocarbon miscible can increase oil recovery from California reservoirs. Over one half of the 435 California reservoirs on which DOE has crude oil data contain oils with quantities of 25/degree/API or higher and viscosities of less than 20 cp. These reservoirs include sands in the large Wilmington, Belridge, Coalinga, Ventura and Midway Sunset fields. Based on crude oil properties, these reservoirs are candidates for all of the chemical flooding processes (Miscible and non-miscible. Economic success will depend on how well the problems of reservoir geology, CO/sub 2/ availability and mobility control, and surfactant and polymer quality are handled in the design and operation of each project. 40 refs.

Holm, L.W.

1982-01-01T23:59:59.000Z

458

Property:AvgReservoirDepth | Open Energy Information  

Open Energy Info (EERE)

AvgReservoirDepth AvgReservoirDepth Jump to: navigation, search Property Name AvgReservoirDepth Property Type Quantity Description Average depth to reservoir Use this type to express a quantity of length. The default unit is the meter (m). Acceptable units (and their conversions) are: Meters - 1 m, meter, meters Meter, Meters, METER, METERS Kilometers - 0.001 km, kilometer, kilometers, Kilometer, Kilometers, KILOMETERS, KILOMETERS Miles - 0.000621371 mi, mile, miles, Mile, Miles, MILE, MILES Feet - 3.28084 ft, foot, feet, Foot, Feet, FOOT, FEET Yards - 1.09361 yd, yard, yards, Yard, Yards, YARD, YARDS Pages using the property "AvgReservoirDepth" Showing 24 pages using this property. A Amedee Geothermal Area + 213 m0.213 km 0.132 mi 698.819 ft 232.939 yd + B Beowawe Hot Springs Geothermal Area + 850 m0.85 km

459

Lithology and alteration mineralogy of reservoir rocks at Coso Geothermal  

Open Energy Info (EERE)

Lithology and alteration mineralogy of reservoir rocks at Coso Geothermal Lithology and alteration mineralogy of reservoir rocks at Coso Geothermal Area, California Jump to: navigation, search GEOTHERMAL ENERGYGeothermal Home Journal Article: Lithology and alteration mineralogy of reservoir rocks at Coso Geothermal Area, California Details Activities (1) Areas (1) Regions (0) Abstract: Coso is one of several high-temperature geothermal systems associated with recent volcanic activity in the Basin and Range province. Chemical and fluid inclusion data demonstrate that production is from a narrow, asymmetric plume of thermal water that originates from a deep reservoir to the south and then flows laterally to the north. Geologic controls on the geometry of the upwelling plume were investigated using petrographic and analytical analyses of reservoir rock and vein material.

460

Computational Intelligence for Deepwater Reservoir Depositional Environments Interpretation  

E-Print Network (OSTI)

Predicting oil recovery efficiency of a deepwater reservoir is a challenging task. One approach to characterize a deepwater reservoir and to predict its producibility is by analyzing its depositional information. This research proposes a deposition-based stratigraphic interpretation framework for deepwater reservoir characterization. In this framework, one critical task is the identification and labeling of the stratigraphic components in the reservoir, according to their depositional environments. This interpretation process is labor intensive and can produce different results depending on the stratigrapher who performs the analysis. To relieve stratigrapher's workload and to produce more consistent results, we have developed a novel methodology to automate this process using various computational intelligence techniques. Using a well log data set, we demonstrate that the developed methodology and the designed workflow can produce finite state transducer models that interpret deepwater reservoir depositional...

Yu, Tina; Clark, Julian; Sullivan, Morgan; 10.1016/j.jngse.2011.07.014

2013-01-01T23:59:59.000Z

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461

Ninth workshop on geothermal reservoir engineering: Proceedings  

SciTech Connect

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

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

1983-12-15T23:59:59.000Z

462

Ninth workshop on geothermal reservoir engineering: Proceedings  

DOE Green Energy (OSTI)

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

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

1983-12-15T23:59:59.000Z

463

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

Science Conference Proceedings (OSTI)

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.

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

2006-09-30T23:59:59.000Z

464

Comparison of two hot dry rock geothermal reservoirs  

DOE Green Energy (OSTI)

Two hot dry rock (HDR) geothermal energy reservoirs were created by hydraulic fracturing of granite at 2.7 to 3.0 km (9000 to 10,000 ft) at the Fenton Hill site, near the Valles Caldera in northern New Mexico. Both reservoirs are research reservoirs, in the sense that both are fairly small, generally yielding 5 MWt or less, and are intended to serve as the basic building blocks of commercial-sized reservoirs, consisting of 10 to 15 similar fractures that would yield approximately 35 MWt over a 10 to 20 yr period. Both research reservoirs were created in the same well-pair, with energy extraction well number 1 (EE-1) serving as the injection well, and geothermal test well number 2 (GT-2) serving as the extraction, or production, well. The first reservoir was created in the low permeability host rock by fracturing EE-1 at a depth of 2.75 km (9020 ft) where the indigenous temperature was 185/sup 0/C (364/sup 0/F). A second, larger reservoir was formed by extending a small, existing fracture at 2.93 km (9620 ft) in the injection well about 100 m deeper and 10/sup 0/C hotter than the first reservoir. The resulting large fracture propagated upward to about 2.6 km (8600 ft) and appeared to Rave an inlet-to-outlet spacing of 300m (1000 ft), more then three times that of the first fracture. Comparisons are made with the first reservoir. Evaluation of the new reservoir was accomplished in two steps: (1) with a 23-day heat extraction experiment that began October 23, 1979, and (2) a second, longer-term heat extraction experiment still in progress, which as of November 25, 1980 has been in effect for 260 days. The results of this current experiment are compared with earlier experiments.

Murphy, H.D.; Tester, J.W.; Potter, R.M.

1980-01-01T23:59:59.000Z

465

Well Productivity in Gas-Condensate and Volatile Oil Reservoirs:  

E-Print Network (OSTI)

Wells in gas condensate reservoirs usually exhibit complex behaviours due to condensate deposit as the bottomhole pressure drops below the dew point. The formation of this liquid saturation can lead to a severe loss of well productivity and therefore lower gas recovery. A similar behaviour is observed in volatile oil reservoirs below the bubble point. Understanding these behaviours and extracting values of controlling parameters is necessary to evaluate well potential and design effective programmes to improve productivity. The Centre of Petroleum Studies at Imperial College London has been involved in research in these areas since 1997, sponsored mainly by consortia of oil companies. Results from this work have already greatly improved the understanding of well behaviour in gas condensate and volatile oil reservoirs and the ability to interpret well tests in such reservoirs. Work to-date has focused on vertical and horizontal wells in sandstone reservoirs. Much work remains to understand the behaviours of fractured wells and wells in naturally fractured reservoirs. The objective of this proposal is to complete the work performed to-date in sandstone reservoirs and to extend it to new well and reservoir characteristics, in order to develop a better understanding of near-wellbore effects in gas condensate and volatile oil reservoirs from well testing, and to use this understanding to develop new methods for predicting and improving well productivity in such reservoirs. The work will be performed by staff, MSc and PhD students from the Centre for Petroleum Studies at Imperial College, with input and guidance from industry partners.

Prof A. C. Gringarten

2004-01-01T23:59:59.000Z

466

Quantification of Hungry Horse Reservoir Water Levels Needed to Maintain or Enhance Reservoir Fisheries, 1985 Annual Report.  

Science Conference Proceedings (OSTI)

The Pacific Northwest Electric Power Planning and Conservation Act, passed in 1980 by Congress, has provided a mechanism which integrates and provides for stable energy planning in the Pacific Northwest. The Act created the Northwest Power Planning Council and charged the Council with developing a comprehensive fish and wildlife program to protect and enhance fish and wildlife impacted by hydroelectric development in the Columbia River Basin. Bonneville Power Administration (BPA) is one of the many agencies implementing the Council's program. The Hungry Horse Reservoir (HHR) study is part of the Council's program. This study proposes to quantify seasonal water levels needed to maintain or enhance principal gamefish species in Hungry Horse Reservoir. The specific study objectives are: (1) Quantify the amount of reservoir habitat available at different water level elevations; (2) Estimate recruitment of westslope cutthroat trout juveniles from important spawning and nursery areas; (3) Determine the abundance, growth, distribution and use of available habitat by major game species in the reservoir; (4) Determine the abundance and availability of fish food organisms in the reservoir; (5) Quantify the seasonal use of available food items by major fish species; (6) Develop relationships between reservoir drawdown and reservoir habitat use by fish and fish food organisms; and (7) Estimate the impact of reservoir operation on major gamefish species.

May, Bruce

1986-06-01T23:59:59.000Z

467

Sizing of a hot dry rock reservoir from a hydraulic fracturing experiment  

DOE Green Energy (OSTI)

Hot dry rock (HDR) reservoirs do not lend themselves to the standard methods of reservoir sizing developed in the petroleum industry such as the buildup/drawdown test. In a HDR reservoir the reservoir is created by the injection of fluid. This process of hydraulic fracturing of the reservoir rock usually involves injection of a large volume (5 million gallons) at high rates (40BPM). A methodology is presented for sizing the HDR reservoir created during the hydraulic fracturing process. The reservoir created during a recent fracturing experiment is sized using the techniques presented. This reservoir is then investigated for commercial potential by simulation of long term power production. 5 refs., 7 figs.

Zyvoloski, G.

1985-01-01T23:59:59.000Z

468

FACTORS AFFECTING HYDRAULICALLY FRACTURED WELL PERFORMANCE IN THE MARCELLUS SHALE GAS RESERVOIRS.  

E-Print Network (OSTI)

??Unconventional reservoirs such as shale, hydrates, tight sand, ultra tight sand and coal bed methane reservoirs serves as alternative sources to meet the increasing demand (more)

Osholake, Tunde

2010-01-01T23:59:59.000Z

469

The effect of natural fracture characteristics on current analytical models for hydraulically fractured unconventional shale reservoirs.  

E-Print Network (OSTI)

??In recent years, the oil and gas industry has shifted its focus more towards unconventional shale reservoirs. It has become apparent that these reservoirs require (more)

Junor, Nathaniel T.

2013-01-01T23:59:59.000Z

470

ASSESSMENT OF RESERVE ESTIMATION TOOLS FOR LOW PERMEABILITY RESERVOIRS FLOWING UNDER EARLY TRANSIENT FLOW REGIME.  

E-Print Network (OSTI)

??Growing energy demand has led to the focus being shifted to unconventional reservoirs. One such reservoir type is shale gas. The introduction of hydraulic fracturing (more)

Husain, Taha

2011-01-01T23:59:59.000Z

471

Numerical modeling of water injection into vapor-dominated geothermal reservoirs  

E-Print Network (OSTI)

Renewable Energy, Office of Geothermal Technologies, of theTransport in Fractured Geothermal Reservoirs, Geothermics,Depletion of Vapor-Dominated Geothermal Reservoirs, Lawrence

Pruess, Karsten

2008-01-01T23:59:59.000Z

472

Investigating statistical modeling approaches for reservoir characterization in waterfloods from rates fluctuations.  

E-Print Network (OSTI)

??Reservoir characterization is important for reservoir management and performance optimization. For waterflood optimization, traditionally several techniques have been suggested, most of which are either too (more)

Lee, Kun-Han

2010-01-01T23:59:59.000Z

473

U.S. Federal Offshore Crude Oil Reserves in Nonproducing Reservoirs...  

Gasoline and Diesel Fuel Update (EIA)

Reserves in Nonproducing Reservoirs (Million Barrels) U.S. Federal Offshore Crude Oil Reserves in Nonproducing Reservoirs (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3...

474

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

Gasoline and Diesel Fuel Update (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...

475

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

Annual Energy Outlook 2012 (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...

476

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

Annual Energy Outlook 2012 (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...

477

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

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

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...

478

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...

479

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

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

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...

480

Naturally fractured tight gas reservoir detection optimization  

SciTech Connect

Building upon the partitioning of the Greater Green River Basin (GGRB) that was conducted last quarter, the goal of the work this quarter has been to conclude evaluation of the Stratos well and the prototypical Green River Deep partition, and perform the fill resource evaluation of the Upper Cretaceous tight gas play, with the goal of defining target areas of enhanced natural fracturing. The work plan for the quarter of November 1-December 31, 1998 comprised four tasks: (1) Evaluation of the Green River Deep partition and the Stratos well and examination of potential opportunity for expanding the use of E and P technology to low permeability, naturally fractured gas reservoirs, (2) Gas field studies, and (3) Resource analysis of the balance of the partitions.

NONE

1999-06-01T23:59:59.000Z