National Library of Energy BETA

Sample records for oil field production

  1. Oil production history in Albania oil fields and their perspective

    SciTech Connect

    Marko, D.; Moci, A.

    1995-12-31

    In this paper we will make a general presentation for oil fields in Albania, actual state, and their perspective.

  2. Floating oil production unit slated in small field off Gabon

    SciTech Connect

    Not Available

    1991-10-14

    This paper reports on the first U.S. tanker converted to a floating production, storage, and offloading (FPSO) unit which takes up station in Gombe-Beta field off Gabon by Dec. 1. FPSO Ocean Producer will work under a 3 year, day rate contract let late in 1990 by Amoco-Gabon Bombe Marin co., a unit of Amoco Production Co. (OGJ, Dec. 24, 1990, p. 27). Gombe-Beta field is in the Atlantic Ocean about 70 miles south of Port Gentil, Gabon. Ocean Producer will be moored in 50 ft of water 3.7 miles off Gabon, with Bombe-Beta's unmanned production platform about 820 ft astern. The vessel will be held in position by a disconnectable, asymmetric, six point, spread mooring system, It is owned and operated by Oceaneering International Services Ltd. (OISL). Affiliate Oceaneering Production Systems (OPS) converted the 78,061 dwt oil tanker MT Baltimore Sea at a capital cost of $25 million at Gulf Copper Manufacturing Corp.'s Port Arthur, Tex., shipyard. Both companies are units of Oceaneering International Inc., Houston. OPS the Ocean Producer's use in Gombe-Beta field is the shallowest water FPSO application in the world. Amoco-Gabon chose an FPSO production system for Gombe-Beta because it expects the remote field to have a short economic life, and the oil requires extensive processing.

  3. Comparison of Permian basin giant oil fields with giant oil fields of other U. S. productive areas

    SciTech Connect

    Haeberle, F.R. )

    1992-04-01

    Covering over 40 million ac, the Permian basin is the fourth largest of the 28 productive areas containing giant fields. The 56 giant fields in the basin compare with the total of 264 giant oil fields in 27 other productive areas. Cumulative production figures of 18 billion bbl from the giant fields in the Permian basin are the largest cumulative production figures from giant fields in any of the productive areas. An estimated 1.9 billion bbl of remaining reserves in giant fields rank the basin third among these areas and the 19.9 billion bbl total reserves in giant fields in the basin are the largest total reserves in giant fields in any of the productive areas. The 1990 production figures from giant fields place the basin second in production among areas with giant fields. However, converting these figures to by-basin averages for the giant fields places the Permian basin 12th in field size among the areas with giant fields. Based on average reserves per well, the basin ranks 18th. Average 1990 production per giant field place the basin seventh and the average 1990 production per well in giant fields place the Permian basin 14th among the areas with giant fields.

  4. Evaluating oil quality and monitoring production from heavy oil reservoirs using geochemical methods: Application to the Boscan Field, Venezuela

    SciTech Connect

    Kaufman, R.L.; Noguera, V.H.; Bantz, D.M.; Rodriguez, R.

    1996-08-01

    Many oil fields worldwide contain heavy oil in one or more reservoir units. The low gravity of these oils is most frequently due to biodegradation and/or low maturity. The challenge is to find ways to economically recover this oil. Methods which reduce the operating costs of producing heavy oil add significant value to such projects. Geochemical techniques which use the composition of the reservoir fluids as natural tracers offer cost effective methods to assist with reservoir management. The low viscosity and gravity of heavy oil, combined with frequent high water cuts, low flow rates, and the presence of downhole artificial lift equipment, make many conventional production logging methods difficult to apply. Therefore, monitoring production, especially if the produced oil is commingled from multiple reservoirs, can be difficult. Geochemical methods can be used to identify oil/water contacts, tubing string leaks and to allocate production to individual zones from commingled production. An example of a giant heavy oil field where geochemical methods may be applicable is the Boscan Field in Venezuela. Low maturity oil, averaging 10{degrees} API gravity, is produced from the Eocene Upper and Lower Boscan (Miosa) Sands. Geochemical, stratigraphic and engineering data have helped to better define the controls on oil quality within the field, identified new reservoir compartments and defined unique characteristics of the Upper and Lower Boscan oils. This information can be used to identify existing wells in need of workovers due to mechanical problems and to monitor production from new infill wells.

  5. Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies, Class III

    SciTech Connect

    City of Long Beach; Tidelands Oil Production Company; University of Southern California; David K. Davies and Associates

    2002-09-30

    The objective of this project was to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California through the testing and application of advanced reservoir characterization and thermal production technologies. It was hoped that the successful application of these technologies would result in their implementation throughout the Wilmington Field and, through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs.

  6. Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies, Class III

    SciTech Connect

    City of Long Beach; Tidelands Oil Production Company; University of Southern California; David K. Davies and Associates

    2002-09-30

    The objective of this project was to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California through the testing and application of advanced reservoir characterization and thermal production technologies. The successful application of these technologies would result in expanding their implementation throughout the Wilmington Field and, through technology transfer, to other slope and basin clastic (SBC) reservoirs.

  7. Abandoned Texas oil fields

    SciTech Connect

    Not Available

    1980-12-01

    Data for Texas abandoned oil fields were primarily derived from two sources: (1) Texas Railroad Commission (TRRC), and (2) Dwight's ENERGYDATA. For purposes of this report, abandoned oil fields are defined as those fields that had no production during 1977. The TRRC OILMASTER computer tapes were used to identify these abandoned oil fields. The tapes also provided data on formation depth, gravity of oil production, location (both district and county), discovery date, and the cumulative production of the field since its discovery. In all, the computer tapes identified 9211 abandoned fields, most of which had less than 250,000 barrel cumulative production. This report focuses on the 676 abandoned onshore Texas oil fields that had cumulative production of over 250,000 barrels. The Dwight's ENERGYDATA computer tapes provided production histories for approximately two-thirds of the larger fields abandoned in 1966 and thereafter. Fields which ceased production prior to 1966 will show no production history nor abandonment date in this report. The Department of Energy hopes the general availability of these data will catalyze the private sector recovery of this unproduced resource.

  8. Exemptions from OSHA`s PSM rule oil and gas field production

    SciTech Connect

    West, H.H. [Shawnee Engineers, Houston, TX (United States); Landes, S. [SH Landes, Houston, TX (United States)

    1995-12-31

    The OSHA Process Safety Management (PSM) regulation, OSHA 1910.119, contains a number of exemptions which are specifically directed to the low hazard situations typically found in the field production facilities of the oil and gas industry. Each relevant PSM exemption is discussed with particular regard to the requirements of hydrocarbon production facilities.

  9. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-06-27

    The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California through the testing and application of advanced reservoir characterization and thermal production technologies. The successful application of these technologies will result in expanding their implementation throughout the Wilmington Field and, through technology transfer, to other slope and basin clastic (SBC) reservoirs. The existing steamflood in the Tar zone of Fault Block II-A (Tar II-A) has been relatively inefficient because of several producibility problems which are common in SBC reservoirs: inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil and non-uniform distribution of the remaining oil. This has resulted in poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. A suite of advanced reservoir characterization and thermal production technologies are being applied during the project to improve oil recovery and reduce operating costs.

  10. Increasing Heavy Oil Reserves in the Wilmington Oil Field through Advanced Reservoir Characterization and Thermal Production Technologies

    SciTech Connect

    City of Long Beach; David K.Davies and Associates; Tidelands Oil Production Company; University of Southern California

    1999-06-25

    The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California. This is realized through the testing and application of advanced reservoir characterization and thermal production technologies. It is hoped that the successful application of these technologies will result in their implementation throughout the Wilmington Field and through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs. The existing steamflood in the Tar zone of Fault Block (FB) II-A has been relatively insufficient because of several producability problems which are common in SBC reservoir; inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil and non-uniform distribution of the remaining oil. This has resulted in poor sweep efficiency, high steam-oil ratios, and early breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves.

  11. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Unknown

    2001-08-08

    The objective of this project is to increase the recoverable heavy oil reserves within sections of the Wilmington Oil Field, near Long Beach, California, through the testing and application of advanced reservoir characterization and thermal production technologies. The hope is that successful application of these technologies will result in their implementation throughout the Wilmington Field and, through technology transfer, will be extended to increase the recoverable oil reserves in other slope and basin clastic (SBC) reservoirs. The existing steamflood in the Tar zone of Fault Block II-A (Tar II-A) has been relatively inefficient because of several producibility problems which are common in SBC reservoirs: inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil and non-uniform distribution of the remaining oil. This has resulted in poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. A suite of advanced reservoir characterization and thermal production technologies are being applied during the project to improve oil recovery and reduce operating costs, including: (1) Development of three-dimensional (3-D) deterministic and stochastic reservoir simulation models--thermal or otherwise--to aid in reservoir management of the steamflood and post-steamflood phases and subsequent development work. (2) Development of computerized 3-D visualizations of the geologic and reservoir simulation models to aid reservoir surveillance and operations. (3) Perform detailed studies of the geochemical interactions between the steam and the formation rock and fluids. (4) Testing and proposed application of a

  12. Overview of NETL Field Studies Related to Oil and Gas Production

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ENERGY lab 18 Aug 2015 Richard Hammack, Monitoring Team Lead USDOE National Energy Technology Laboratory, Pittsburgh, PA Overview of NETL Field Studies Related to Oil and Gas Production DOE Tribal Leaders Forum Denver, Colorado Newfield Exploration, Bakken Petroleum System, North Dakota * Reduce Environmental Impacts * Demonstrate Safe/Reliable Operations * Improve Efficiency of Hydraulic Fracturing Program Objectives * Surface Monitoring - Ambient Air Quality - Air Emissions - Ground Motion -

  13. Production optimization of sucker rod pumping wells producing viscous oil in Boscan field, Venezuela

    SciTech Connect

    Guirados, C.; Sandoval, J.; Rivas, O.; Troconis, H.

    1995-12-31

    Boscan field is located in the western coast of Maracaibo lake and is operated by Maraven S.A., affiliate of Petroleos de Venezuela S.A. It has 315 active wells, 252 of which are produced with sucker rod pumping. Other artificial lift methods currently applied in this field are hydraulic (piston) pumping (39 wells) and ESP (24 wells). This paper presents the results of the production optimization of two sucker rod pumping wells of Boscan field producing viscous oil. This optimization has been possible due to the development of a new production scheme and the application of system analysis in completion design. The new production scheme involves the utilization of a subsurface stuffing box assembly and a slotted housing, both designed and patented by Intevep S.A., affiliate of Petroleos de Venezuela S.A. The completion design method and software used in the optimization study were also developed by Intevep S.A. The new production scheme and design method proved to be effective in preventing the causes of the above mentioned problems, allowing the increase of oil production under better operating conditions.

  14. Oil Production

    Energy Science and Technology Software Center

    1989-07-01

    A horizontal and slanted well model was developed and incorporated into BOAST, a black oil simulator, to predict the potential production rates for such wells. The HORIZONTAL/SLANTED WELL MODEL can be used to calculate the productivity index, based on the length and location of the wellbore within the block, for each reservoir grid block penetrated by the horizontal/slanted wellbore. The well model can be run under either pressure or rate constraints in which wellbore pressuresmore » can be calculated as an option of infinite-conductivity. The model can simulate the performance of multiple horizontal/slanted wells in any geometric combination within reservoirs.« less

  15. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2004-03-05

    The overall objective of this project is to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involves improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective is to transfer technology which can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The thermal recovery operations in the Tar II-A and Tar V have been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the

  16. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2003-09-04

    The overall objective of this project is to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involves improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective is to transfer technology which can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The thermal recovery operations in the Tar II-A and Tar V have been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the

  17. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2003-06-04

    The overall objective of this project is to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involves improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective is to transfer technology which can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The thermal recovery operations in the Tar II-A and Tar V have been relatively inefficient because of several producibility problems which are common in SBC reservoirs. Inadequate characterization of the heterogeneous turbidite sands, high permeability thief zones, low gravity oil, and nonuniform distribution of remaining oil have all contributed to poor sweep efficiency, high steam-oil ratios, and early steam breakthrough. Operational problems related to steam breakthrough, high reservoir pressure, and unconsolidated formation sands have caused premature well and downhole equipment failures. In aggregate, these reservoir and operational constraints have resulted in increased operating costs and decreased recoverable reserves. The advanced technologies to be applied include: (1) Develop three-dimensional (3-D) deterministic and stochastic geologic models. (2) Develop 3-D deterministic and stochastic thermal reservoir simulation models to aid in reservoir management and subsequent development work. (3) Develop computerized 3-D visualizations of the geologic and reservoir simulation models to aid in analysis. (4) Perform detailed study on the geochemical interactions between the steam and the formation rock and fluids. (5) Pilot steam injection and production via four new horizontal wells (2 producers and 2 injectors). (6) Hot water alternating steam (WAS) drive pilot in the

  18. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-05-07

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through September 2000, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on improving core analysis techniques, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post steamflood projects. Work was discontinued on the stochastic geologic model and developing a 3-D stochastic thermal reservoir simulation model of the Tar II-A Zone so the project team could use the 3-D deterministic reservoir simulation model to provide alternatives for the Tar II-A post steamflood operations and shale compaction studies. The project team spent the fourth quarter 2000 performing well work and reservoir surveillance on the Tar II-A post-steamflood project and the Tar V horizontal well steamflood pilot. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The current steamflood operations in the Tar V pilot are economical, but recent performance is below projections because of wellbore mechanical limitations that are being evaluated.

  19. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2002-01-31

    to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The steamflood operation in the Tar V pilot project is mature and profitable. Recent production performance is below projections because of wellbore mechanical limitations that were being addressed in 2001. As the fluid production is hot, the pilot steamflood was converted to a hot waterflood project in June 2001.

  20. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-11-01

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. Through June 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. The project team spent the Third Quarter 2001 performing well work and reservoir surveillance on the Tar II-A post-steamflood project. The Tar II-A post-steamflood operation started in February 1999 and steam chest fillup occurred in September-October 1999. The targeted reservoir pressures in the ''T'' and ''D'' sands are maintained at 90 {+-} 5% hydrostatic levels by controlling water injection and gross fluid production and through the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase. The project team ramped up well work activity from October 2000 to September 2001 to increase production and injection. This work will continue through 2001 as described in the Operational Management section. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for

  1. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2001-05-08

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through March 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. The project team spent the Second Quarter 2001 performing well work and reservoir surveillance on the Tar II-A post-steamflood project. The Tar II-A steamflood reservoirs have been operated over fifteen months at relatively stable pressures, due in large part to the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase in January 1999. Starting in the Fourth Quarter 2000, the project team has ramped up activity to increase production and injection. This work will continue through 2001 as described in the Operational Management section. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil Production Company's development strategy for the field. The current steamflood operations in the Tar V pilot are economical, but recent performance is below projections because of wellbore mechanical

  2. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2002-11-08

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through June 2002, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V post-steamflood pilot and Tar II-A post-steamflood projects. During the Third Quarter 2002, the project team essentially completed implementing the accelerated oil recovery and reservoir cooling plan for the Tar II-A post-steamflood project developed in March 2002 and is proceeding with additional related work. The project team has completed developing laboratory research procedures to analyze the sand consolidation well completion technique and will initiate work in the fourth quarter. The Tar V pilot steamflood project terminated hot water injection and converted to post-steamflood cold water injection on April 19, 2002. Proposals have been approved to repair two sand consolidated horizontal wells that sanded up, Tar II-A well UP-955 and Tar V well J-205, with gravel-packed inner liner jobs to be performed next quarter. Other well work to be performed next quarter is to convert well L-337 to a Tar V water injector and to recomplete vertical well A-194 as a Tar V interior steamflood pattern producer. Plans have been approved to drill and

  3. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2002-04-30

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. Through December 2001, project work has been completed on the following activities: data preparation; basic reservoir engineering; developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model and a rock-log model; well drilling and completions; and surface facilities on the Fault Block II-A Tar Zone (Tar II-A). Work is continuing on research to understand the geochemistry and process regarding the sand consolidation well completion technique, final reservoir tracer work, operational work and research studies to prevent thermal-related formation compaction in the Tar II-A steamflood area, and operational work on the Tar V steamflood pilot and Tar II-A post-steamflood projects. During the First Quarter 2002, the project team developed an accelerated oil recovery and reservoir cooling plan for the Tar II-A post-steamflood project and began implementing the associated well work in March. The Tar V pilot steamflood project will be converted to post-steamflood cold water injection in April 2002. The Tar II-A post-steamflood operation started in February 1999 and steam chest fillup occurred in September-October 1999. The targeted reservoir pressures in the ''T'' and ''D'' sands are maintained at 90 {+-} 5% hydrostatic levels by controlling water injection and gross fluid production and through the bimonthly pressure monitoring program enacted at the start of the post-steamflood phase. Most of the 2001 well work resulted in maintaining oil and gross fluid production and water injection rates. Reservoir pressures in the ''T'' and ''D'' sands are at 88% and 91% hydrostatic levels, respectively. Well work during the first quarter and plans for 2002 are

  4. Crude Oil Domestic Production

    Energy Information Administration (EIA) (indexed site)

    Data Series: Crude Oil Domestic Production Refinery Crude Oil Inputs Refinery Gross Inputs Refinery Operable Capacity (Calendar Day) Refinery Percent Operable Utilization Net ...

  5. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2000-02-18

    The project involves using advanced reservoir characterization and thermal production technologies to improve thermal recovery techniques and lower operating and capital costs in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., CA. Through March 1999, project work has been completed related to data preparation, basic reservoir engineering, developing a deterministic three dimensional (3-D) geologic model, a 3-D deterministic reservoir simulation model, and a rock-log model, well drilling and completions, and surface facilities. Work is continuing on the stochastic geologic model, developing a 3-D stochastic thermal reservoir simulation model of the Fault Block IIA Tar (Tar II-A) Zone, and operational work and research studies to prevent thermal-related formation compaction. Thermal-related formation compaction is a concern of the project team due to observed surface subsidence in the local area above the steamflood project. Last quarter on January 12, the steamflood project lost its inexpensive steam source from the Harbor Cogeneration Plant as a result of the recent deregulation of electrical power rates in California. An operational plan was developed and implemented to mitigate the effects of the two situations. Seven water injection wells were placed in service in November and December 1998 on the flanks of the Phase 1 steamflood area to pressure up the reservoir to fill up the existing steam chest. Intensive reservoir engineering and geomechanics studies are continuing to determine the best ways to shut down the steamflood operations in Fault Block II while minimizing any future surface subsidence. The new 3-D deterministic thermal reservoir simulator model is being used to provide sensitivity cases to optimize production, steam injection, future flank cold water injection and reservoir temperature and pressure. According to the model, reservoir fill up of the steam chest at the current injection rate of 28,000 BPD and gross

  6. Crude Oil Production

    Gasoline and Diesel Fuel Update

    Notes: Year-to-date totals include revised monthly production estimates by state published in Petroleum Navigator. Crude oil production quantities are estimated by state and summed ...

  7. Crude Oil Production

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    ... Notes: Year-to-date totals include revised monthly production estimates by state published in Petroleum Navigator. Crude oil production quantities are estimated by state and summed ...

  8. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2000-12-06

    to accurately project reservoir steam chest fill-up by October 1999. A geomechanics study and a separate reservoir simulation study have been performed to determine the possible indicators of formation compaction, the temperatures at which specific indicators are affected and the projected temperature profiles in the over and underburden shales over a ten year period following steam injection. It was believed that once steam chest fill-up occurred, the reservoir would act more like a waterflood and production and cold water injection could be operated at lower Injection to production ratios (I/P) and net injection rates. In mid-September 1999, net water injection was reduced substantially in the ''D'' sands following steam chest fill-up. This caused reservoir pressures to plummet about 100 psi within six weeks. Starting in late-October 1999, net ''D'' sand injection was increased and reservoir pressures have slowly increased back to steam chest fill-up pressures as of the end of March 2000. When the ''T'' sands reached fill-up, net ''T'' sand injection was lowered only slightly and reservoir pressures stabilized. A more detailed discussion of the operational changes is in the Reservoir Management section of this report. A reservoir pressure monitoring program was developed as part of the poststeamflood reservoir management plan. This bi-monthly sonic fluid level program measures the static fluid levels in all idle wells an average of once a month. The fluid levels have been calibrated for liquid and gas density gradients by comparing a number of them with Amerada bomb pressures taken within a few days. This data allows engineering to respond quickly to rises or declines in reservoir pressure by either increasing injection or production or idling production. Expanding thermal recovery operations to other sections of the Wilmington Oil Field, including the Tar V horizontal well pilot steamflood project, is a critical part of the City of Long Beach and Tidelands Oil

  9. Class III Mid-Term Project, "Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies"

    SciTech Connect

    Scott Hara

    2007-03-31

    The overall objective of this project was to increase heavy oil reserves in slope and basin clastic (SBC) reservoirs through the application of advanced reservoir characterization and thermal production technologies. The project involved improving thermal recovery techniques in the Tar Zone of Fault Blocks II-A and V (Tar II-A and Tar V) of the Wilmington Field in Los Angeles County, near Long Beach, California. A primary objective has been to transfer technology that can be applied in other heavy oil formations of the Wilmington Field and other SBC reservoirs, including those under waterflood. The first budget period addressed several producibility problems in the Tar II-A and Tar V thermal recovery operations that are common in SBC reservoirs. A few of the advanced technologies developed include a three-dimensional (3-D) deterministic geologic model, a 3-D deterministic thermal reservoir simulation model to aid in reservoir management and subsequent post-steamflood development work, and a detailed study on the geochemical interactions between the steam and the formation rocks and fluids. State of the art operational work included drilling and performing a pilot steam injection and production project via four new horizontal wells (2 producers and 2 injectors), implementing a hot water alternating steam (WAS) drive pilot in the existing steamflood area to improve thermal efficiency, installing a 2400-foot insulated, subsurface harbor channel crossing to supply steam to an island location, testing a novel alkaline steam completion technique to control well sanding problems, and starting on an advanced reservoir management system through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation. The second budget period phase (BP2) continued to implement state-of-the-art operational work to optimize thermal recovery processes, improve well drilling and completion practices, and evaluate the

  10. Water issues associated with heavy oil production.

    SciTech Connect

    Veil, J. A.; Quinn, J. J.; Environmental Science Division

    2008-11-28

    Crude oil occurs in many different forms throughout the world. An important characteristic of crude oil that affects the ease with which it can be produced is its density and viscosity. Lighter crude oil typically can be produced more easily and at lower cost than heavier crude oil. Historically, much of the nation's oil supply came from domestic or international light or medium crude oil sources. California's extensive heavy oil production for more than a century is a notable exception. Oil and gas companies are actively looking toward heavier crude oil sources to help meet demands and to take advantage of large heavy oil reserves located in North and South America. Heavy oil includes very viscous oil resources like those found in some fields in California and Venezuela, oil shale, and tar sands (called oil sands in Canada). These are described in more detail in the next chapter. Water is integrally associated with conventional oil production. Produced water is the largest byproduct associated with oil production. The cost of managing large volumes of produced water is an important component of the overall cost of producing oil. Most mature oil fields rely on injected water to maintain formation pressure during production. The processes involved with heavy oil production often require external water supplies for steam generation, washing, and other steps. While some heavy oil processes generate produced water, others generate different types of industrial wastewater. Management and disposition of the wastewater presents challenges and costs for the operators. This report describes water requirements relating to heavy oil production and potential sources for that water. The report also describes how water is used and the resulting water quality impacts associated with heavy oil production.

  11. Oil field management system

    DOEpatents

    Fincke, James R.

    2003-09-23

    Oil field management systems and methods for managing operation of one or more wells producing a high void fraction multiphase flow. The system includes a differential pressure flow meter which samples pressure readings at various points of interest throughout the system and uses pressure differentials derived from the pressure readings to determine gas and liquid phase mass flow rates of the high void fraction multiphase flow. One or both of the gas and liquid phase mass flow rates are then compared with predetermined criteria. In the event such mass flow rates satisfy the predetermined criteria, a well control system implements a correlating adjustment action respecting the multiphase flow. In this way, various parameters regarding the high void fraction multiphase flow are used as control inputs to the well control system and thus facilitate management of well operations.

  12. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2000-12-06

    chests from reoccurring. A new 3-D deterministic thermal reservoir simulation model was used to provide operations with the necessary water injection rates and allowable production rates by well to minimize future surface subsidence and to accurately project reservoir steam chest fill-up by October 1999. A geomechanics study and a separate reservoir simulation study have been performed to determine the possible indicators of formation compaction, the temperatures at which specific indicators are affected and the projected temperature profiles in the over and underburden shales over a ten year period following steam injection. Further geomechanics work should be conducted. It was believed that once steam chest fill-up occurred, the reservoir would act more like a waterflood and production and cold water injection could be operated at lower Injection to production ratios (I/P) and net injection rates. In mid-September 1999, net water injection was reduced substantially in the ''D'' sands following steam chest fill-up. This caused reservoir pressures to plummet about 100 psi within six weeks. Starting in late-October 1999, net ''D'' sand injection was increased and reservoir pressures have slowly increased back to steam chest fill-up pressures as of the end of March 2000. When the ''T'' sands reached fill-up, net ''T'' sand injection remained at a high rate and reservoir pressures stabilized. A more detailed discussion of the operational changes is in the Reservoir Management section of this report. A reservoir pressure monitoring program was developed as part of the poststeamflood reservoir management plan. This bi-monthly sonic fluid level program measures the static fluid levels in all idle wells an average of once a month. The fluid levels have been calibrated for liquid and gas density gradients by comparing a number of them with Amerada bomb pressures taken within a few days. This data allows engineering to respond quickly to rises or declines in reservoir pressure by

  13. INCREASING HEAVY OIL RESERVES IN THE WILMINGTON OIL FIELD THROUGH ADVANCED RESERVOIR CHARACTERIZATION AND THERMAL PRODUCTION TECHNOLOGIES

    SciTech Connect

    Scott Hara

    2000-12-14

    prevent the steam chests from reoccurring. A new 3-D deterministic thermal reservoir simulation model was used to provide operations with the necessary water injection rates and allowable production rates by well to minimize future surface subsidence and to accurately project reservoir steam chest fill-up by October 1999. A geomechanics study and a separate reservoir simulation study have been performed to determine the possible indicators of formation compaction, the temperatures at which specific indicators are affected and the projected temperature profiles in the over and underburden shales over a ten year period following steam injection. Further geomechanics work should be conducted. It was believed that once steam chest fill-up occurred, the reservoir would act more like a waterflood and production and cold water injection could be operated at lower Injection to production ratios (I/P) and net injection rates. In mid-September 1999, net water injection was reduced substantially in the ''D'' sands following steam chest fill-up. This caused reservoir pressures to plummet about 100 psi within six weeks. Starting in late-October 1999, net ''D'' sand injection was increased and reservoir pressures increased back to steam chest fill-up pressures of 90% hydrostatic pressure by March 2000 and have been maintained through September 2000. When the ''T'' sands reached fill-up in October 1999, net ''T'' sand injection remained at a high rate through April 2000 and reservoir pressures stabilized at 98% hydrostatic pressure. The objective is to lower ''T'' sand pressure slowly to 90% hydrostatic. Net injection was reduced and ''T'' sand reservoir pressure was at 97% hydrostatic in September 2000. A more detailed discussion of the operational changes is in the Reservoir Management section of this report. A reservoir pressure monitoring program was developed as part of the poststeamflood reservoir management plan. This bi-monthly sonic fluid level program measures the static fluid

  14. Going Global: Tight Oil Production

    Gasoline and Diesel Fuel Update

    GOING GLOBAL: TIGHT OIL PRODUCTION Leaping out of North America and onto the World Stage JULY 2014 GOING GLOBAL: TIGHT OIL PRODUCTION Jamie Webster, Senior Director Global Oil Markets Jamie.webster@ihs.com 1 GOING GLOBAL: TIGHT OIL PRODUCTION Key Message: Tight Oil Will Have Unconventional Effects Tight Oil Production will change in the coming decades. It will be:  More global, as it leaps out of North America  More inclusive, as companies come to the US for experience and US companies go

  15. Heavy oil production from Alaska

    SciTech Connect

    Mahmood, S.M.; Olsen, D.K.

    1995-12-31

    North Slope of Alaska has an estimated 40 billion barrels of heavy oil and bitumen in the shallow formations of West Sak and Ugnu. Recovering this resource economically is a technical challenge for two reasons: (1) the geophysical environment is unique, and (2) the expected recovery is a low percentage of the oil in place. The optimum advanced recovery process is still undetermined. Thermal methods would be applicable if the risks of thawing the permafrost can be minimized and the enormous heat losses reduced. Use of enriched natural gas is a probable recovery process for West Sak. Nearby Prudhoe Bay field is using its huge natural gas resources for pressure maintenance and enriched gas improved oil recovery (IOR). Use of carbon dioxide is unlikely because of dynamic miscibility problems. Major concerns for any IOR include close well spacing and its impact on the environment, asphaltene precipitation, sand production, and fines migration, in addition to other more common production problems. Studies have indicated that recovering West Sak and Lower Ugnu heavy oil is technically feasible, but its development has not been economically viable so far. Remoteness from markets and harsh Arctic climate increase production costs relative to California heavy oil or Central/South American heavy crude delivered to the U.S. Gulf Coast. A positive change in any of the key economic factors could provide the impetus for future development. Cooperation between the federal government, state of Alaska, and industry on taxation, leasing, and permitting, and an aggressive support for development of technology to improve economics is needed for these heavy oil resources to be developed.

  16. STEO December 2012 - oil production

    Energy Information Administration (EIA) (indexed site)

    Rise in 2012 U.S. oil production largest since 1859, output in 2013 seen topping 7 million bpd U.S. crude oil production is now expected to rise by about 760,000 barrels per day in 2012, the biggest annual increase in oil output since U.S. commercial crude oil production began in 1859. American oil producers are expected to pump a daily average of 6.4 million barrels of crude oil this year, according to the U.S. Energy Information Administrator's new monthly energy forecast. The annual increase

  17. Venezuela slates second oil field revival round

    SciTech Connect

    Not Available

    1992-12-07

    This paper reports that Venezuela will accept bids under a second round next year from private foreign and domestic companies for production contracts to operate marginal active as well as inactive oil fields. The first such round came earlier this year, involving about 55 other marginal, inactive fields. It resulted in two contractors signed with domestic and foreign companies. It represented the first time since nationalization of the petroleum industry in Venezuela in 1976 that private companies were allowed to produce oil in the country. A public bid tender was expected at presstime last week.

  18. Alcorn wells bolster Philippines oil production

    SciTech Connect

    Not Available

    1992-09-21

    This paper reports that Alcorn International Inc., Houston, is producing about 16,500 b/d of oil from West Linapacan A field in the South China Sea off the Philippines. The field's current production alone is more than fivefold the Philippines' total average oil flow of 3,000 b/d in 1991. It's part of a string of oil and gas strikes off Palawan Island that has made the region one of the hottest exploration/development plays in the Asia-Pacific theater.

  19. Minimize oil field power consumption

    SciTech Connect

    Harris, B.; Ennis, P.

    1999-08-01

    Though electric power is a major operating cost of oil production, few producers have systematically evaluated their power consumption for ways to be more efficient. There is significant money to be saved by doing so, and now is a good time to make an evaluation because new power options are at hand. They range from small turbo generators that can run on casing head gas and power one or two lift pumps, to rebuilt major turbines and ram-jet powered generators that can be set in a multi-well field and deliver power at bargain prices. Power industry deregulation is also underway. Opportunities for more advantageous power contracts from competitive sources are not far off. This two-part series covers power efficiency and power options. This article reviews steps you can take to evaluate the efficiency of your power use and go about improving it. Part 2 will discuss opportunities for use of distributed power and changes you can expect from decentralized power.

  20. STEO September 2012 - oil production

    Energy Information Administration (EIA) (indexed site)

    oil production forecast to rise almost 700,000 bpd this year, help cut U.S. petroleum imports U.S. crude oil production is expected to average 6.3 million barrels per day in 2012. That's up nearly 700,000 barrels per day from last year and the highest annual oil output since 1997 says the U.S. Energy Information Administration in its new monthly short-term energy outlook for September. EIA analyst Sam Gorgen explains: "Higher oil supplies, especially from North Dakota and Texas, boosted

  1. Sacha oil field of Ecuadorian Oriente

    SciTech Connect

    Canfield, R.W.; Bonilla, G.; Robbins, R.K.

    1982-08-01

    The Sacha oil field in the Ecuadorian Oriente was discovered in early 1969. Production began in July 1972, and at the end of 1980 had exceeded 190 million bbl. Drilling through 1980 had resulted in 91 oil wells and 2 dry holes. Estimated original primary recoverable reserves surpass 632 million bbl. The field is on a very low-relief anticline about 17.5 mi (28 km) long and averaging 4 mi (6.5 km) wide. Vertical closure amounts to 200 ft (60 m) and there are 41,000 acres (16,600 ha.) of areal closure on top of the principal reservoir. The Cretaceous sandstones, at drilled depths between 9,300 and 10,100 ft (2,835 and 3,080 m) provide excellent reservoirs. The Hollin Formation, the basal Cretaceous sandstone, is the principal reservoir, having produced 80% of the oil through 1980 and containing about 68% of the original reserves.

  2. ,"Total Crude Oil and Petroleum Products Exports"

    Energy Information Administration (EIA) (indexed site)

    Data for" ,"Data 1","Total Crude Oil and Petroleum Products ... "Back to Contents","Data 1: Total Crude Oil and Petroleum Products Exports" ...

  3. Using Flue Gas Huff 'n Puff Technology and Surfactants to Increase Oil Production from the Antelope Shale Formation of the Railroad Gap Oil Field

    SciTech Connect

    McWilliams, Michael

    2001-12-18

    This project was designed to test cyclic injection of exhaust flue gas from compressors located in the field to stimulate production from Antelope Shale zone producers. Approximately 17,000 m{sup 3} ({+-}600 MCF) of flue gas was to be injected into each of three wells over a three-week period, followed by close monitoring of production for response. Flue gas injection on one of the wells would be supplemented with a surfactant.

  4. Venezuelan oil field revival bids won

    SciTech Connect

    Not Available

    1992-06-29

    This paper reports that four private sector companies or combines will operate inactive oil fields in Venezuela under state owned Petroleos de Venezuela's marginal field reactivation program. The award of operating contract to winning bidders marks the first time private companies will be allowed to produce crude oil in Venezuela since nationalization of the industry in 1976. Winning bidders have committed a total of $720 million in investments to the program during the 1990s. Current plans call for drilling 670 appraisals and development wells, conducting 250 workovers and well repairs, and conducting about 2,9000 line km of seismic surveys. Venezuela's energy ministry is targeting a production level of 90,000 b/d by the end of the decade from the reactivated fields.

  5. Trends in heavy oil production and refining in California

    SciTech Connect

    Olsen, D.K.; Ramzel, E.B.; Pendergrass, R.A. II

    1992-07-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production and is part of a study being conducted for the US Department of Energy. This report summarizes trends in oil production and refining in Canada. Heavy oil (10{degrees} to 20{degrees} API gravity) production in California has increased from 20% of the state`s total oil production in the early 1940s to 70% in the late 1980s. In each of the three principal petroleum producing districts (Los Angeles Basin, Coastal Basin, and San Joaquin Valley) oil production has peaked then declined at different times throughout the past 30 years. Thermal production of heavy oil has contributed to making California the largest producer of oil by enhanced oil recovery processes in spite of low oil prices for heavy oil and stringent environmental regulation. Opening of Naval Petroleum Reserve No. 1, Elk Hills (CA) field in 1976, brought about a major new source of light oil at a time when light oil production had greatly declined. Although California is a major petroleum-consuming state, in 1989 the state used 13.3 billion gallons of gasoline or 11.5% of US demand but it contributed substantially to the Nation`s energy production and refining capability. California is the recipient and refines most of Alaska`s 1.7 million barrel per day oil production. With California production, Alaskan oil, and imports brought into California for refining, California has an excess of oil and refined products and is a net exporter to other states. The local surplus of oil inhibits exploitation of California heavy oil resources even though the heavy oil resources exist. Transportation, refining, and competition in the market limit full development of California heavy oil resources.

  6. Trends in heavy oil production and refining in California

    SciTech Connect

    Olsen, D.K.; Ramzel, E.B.; Pendergrass, R.A. II.

    1992-07-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production and is part of a study being conducted for the US Department of Energy. This report summarizes trends in oil production and refining in Canada. Heavy oil (10{degrees} to 20{degrees} API gravity) production in California has increased from 20% of the state's total oil production in the early 1940s to 70% in the late 1980s. In each of the three principal petroleum producing districts (Los Angeles Basin, Coastal Basin, and San Joaquin Valley) oil production has peaked then declined at different times throughout the past 30 years. Thermal production of heavy oil has contributed to making California the largest producer of oil by enhanced oil recovery processes in spite of low oil prices for heavy oil and stringent environmental regulation. Opening of Naval Petroleum Reserve No. 1, Elk Hills (CA) field in 1976, brought about a major new source of light oil at a time when light oil production had greatly declined. Although California is a major petroleum-consuming state, in 1989 the state used 13.3 billion gallons of gasoline or 11.5% of US demand but it contributed substantially to the Nation's energy production and refining capability. California is the recipient and refines most of Alaska's 1.7 million barrel per day oil production. With California production, Alaskan oil, and imports brought into California for refining, California has an excess of oil and refined products and is a net exporter to other states. The local surplus of oil inhibits exploitation of California heavy oil resources even though the heavy oil resources exist. Transportation, refining, and competition in the market limit full development of California heavy oil resources.

  7. Plans to revive oil fields in Venezuela on track

    SciTech Connect

    Not Available

    1992-02-24

    This paper reports on the three operating units of Venezuela's state owned oil company Petroleos de Venezuela SA which will begin receiving bids Feb. 28 from companies interested in operating 55 inactive oil fields in nine producing areas of Venezuela. Francisco Pradas, Pdvsa executive in charge of the program, the the company expects 88 companies or combines of foreign and domestic private companies to participate in the bidding. The program, announced last year, aims to reactivate production in marginal oil fields. It will involve the first direct participation by private companies in Venezuela's oil production since nationalization in 1976.

  8. Iran outlines oil productive capacity

    SciTech Connect

    Not Available

    1992-11-09

    National Iranian Oil Co. (NIOC) tested production limits last month to prove a claim of 4 million bd capacity made at September's meeting of the organization of Petroleum Exporting Countries. Onshore fields account for 3.6 million bd of the total, with offshore fields providing the rest. NIOC plans to expand total capacity to 4.5 million bd by April 1993, consisting of 4 million b/d onshore and 500,000 b/d offshore. Middle East Economic Survey says questions remain about completion dates for gas injection, drilling, and offshore projects, but expansion targets are attainable within the scheduled time. NIOC said some slippage may be unavoidable, but it is confident the objective will be reached by third quarter 1993 at the latest. More than 60 rigs are working or about to be taken under contract to boost development drilling in onshore fields and provide gas injection in some. NIOC has spent $3.2 billion in foreign exchange on the drilling program in the last 2 1/2 years.

  9. Field performance of a premium heating oil

    SciTech Connect

    Santa, T.; Jetter, S.

    1997-01-01

    As part of ongoing research to provide quality improvements to heating oil, Mobil Oil together with Santa Fuel conducted a field trial to investigate the performance of a new premium heating oil. This premium heating oil contains an additive system designed to minimize sludge related problems in the fuel delivery system of residential home heating systems. The additive used was similar to others reported at this and earlier BNL conferences, but was further developed to enhance its performance in oil heat systems. The premium heating oil was bulk additized and delivered to a subset of the customer base. The performance of this premium heating oil is discussed.

  10. Crude Oil and Petroleum Products Total Stocks Stocks by Type

    Energy Information Administration (EIA) (indexed site)

    Product: Crude Oil and Petroleum Products Crude Oil All Oils (Excluding Crude Oil) Pentanes Plus Liquefied Petroleum Gases EthaneEthylene PropanePropylene Normal ButaneButylene ...

  11. Increased oil production and reserves from improved completion techniques in the Bluebell field, Uinta Basin, Utah. Annual report, October 1, 1995--September 30, 1996

    SciTech Connect

    Morgan, C.D.; Allison, M.L.

    1997-08-01

    The Bluebell field is productive from the Tertiary lower Green River and Wasatch Formations of the Uinta Basin, Utah. The productive interval consists of thousands of feet of interbedded fractured clastic and carbonate beds deposited in a fluvial-dominated lacustrine environment. Wells in the Bluebell field are typically completed by perforating 40 or more beds over 1,000 to 3,000 vertical feet (300-900 m), then stimulating the entire interval. This completion technique is believed to leave many potentially productive beds damaged and/or untreated, while allowing water-bearing and low-pressure (thief) zones to communicate with the wellbore. Geologic and engineering characterization has been used to define improved completion techniques. A two-year characterization study involved detailed examination of outcrop, core, well logs, surface and subsurface fractures, produced oil-field waters, engineering parameters of the two demonstration wells, and analysis of past completion techniques and effectiveness. The characterization study resulted in recommendations for improved completion techniques and a field-demonstration program to test those techniques. The results of the characterization study and the proposed demonstration program are discussed in the second annual technical progress report. The operator of the wells was unable to begin the field demonstration this project year (October 1, 1995 to September 20, 1996). Correlation and thickness mapping of individual beds in the Wasatch Formation was completed and resulted in a. series of maps of each of the individual beds. These data were used in constructing the reservoir models. Non-fractured and fractured geostatistical models and reservoir simulations were generated for a 20-square-mile (51.8-km{sup 2}) portion of the Bluebell field. The modeling provides insights into the effects of fracture porosity and permeability in the Green River and Wasatch reservoirs.

  12. Review of EIA Oil Production Outlooks

    Gasoline and Diesel Fuel Update

    Review of EIA oil production outlooks For 2014 EIA Energy Conference July 15, 2014 | Washington, DC By Samuel Gorgen, Upstream Analyst Overview Gorgen, Tight Oil Production Trends EIA Conference, July 15, 2014 2 * Drilling Productivity Report performance review - Permian - Eagle Ford - Bakken * Crude oil production projections - Short-Term Energy Outlook - Annual Energy Outlook - International tight oil outlook * New DPR region highlights: Utica Drilling Productivity Report review - major tight

  13. Ben South (Tannehill) oil field, Stonewall, County, Texas

    SciTech Connect

    Hillock, R.T.

    1984-01-01

    Ben South is one of 157 Tannehill oil fields on the northeastern shelf of the Permian basin. Texas Railroad Commission District 7B has 66 Tannehill oil fields while District 8A has 21. The discovery well for the Ben South field was the Ryder Scott Management (Sauder) 1 McMeans, completed in 1973. Ben South field production has totaled 749,340 bbl of oil through March 1983 from 13 wells. Oil production is from the lower Tannehill (lower Wolfcamp) sands underlying the Stockwether Limestone. These Tannehill sands were deposited in a fluvial environment. Channel-fill and point-bar deposits make up the pay sands. The trapping mechanism is both stratigraphic and structural.

  14. The Heidrun Field: Oil offtake system

    SciTech Connect

    Rajabi, F.D.; Breivik, K.; Syvertsen, K.

    1996-12-31

    Offtake of oil from the Heidrun field is achieved through a Direct Shuttle Loading (DSL) system. This approach eliminates the need for an intermediate storage facility, allowing continuous production and transfer of oil directly from the Heidrun TLP to shuttle tankers. Purpose-built or appropriately converted tankers with an integral bow turret locate and connect to a Submerged Turret Loading (STL) buoy which functions both as a tanker mooring point and a termination for the flexible offloading line. The system is designed to permit the tankers to remain connected during loading and to disengage from the STL buoy on completion of loading in all weather conditions up to and including the 100 year storm. This paper describes implementation of the Heidrun DSL system from conception to first oil. It gives the background for choosing the DSL system and information on the data generated to support the selection process. Design, fabrication and installation of various components are explained to give an insight into the challenges that had to be overcome for realization of this first-of-its-kind system in a record time of about one year. Installation of the complete DSL system in the summer of 1994, approximately one year ahead of the original plans, enabled full scale in situ testing of the system with a purpose-modified shuttle tanker. The two-month test program provided the equivalent of one year of operational experience with the system before first oil. The paper addresses data obtained during the full scale testing, and comparison with analytical results. The operation of the Heidrun DSL system is also described. These data together with the experience gained during realization of this bold concept will give key information on how such a concept can be effectively applied to any major or marginal field development scenario either as an offtake system or in conjunction with an FPSO/FSO.

  15. Power Plays: Geothermal Energy in Oil and Gas Fields | Department...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Power Plays: Geothermal Energy in Oil and Gas Fields Power Plays: Geothermal Energy in Oil and Gas Fields Power Plays: Geothermal Energy in Oil and Gas Fields April 25, 2016 9:00AM ...

  16. Oil and Gas Field Code Master List - Energy Information Administration

    Energy Information Administration (EIA) (indexed site)

    Oil and Gas Field Code Master List With Data for 2015 | Release Date: February 24, 2016 | ... Comprehensive listing of U.S. oil and gas field names. Oil and Gas Field Code Master List ...

  17. Geothermal Testing Facilities in an Oil Field - Rocky Mountain Oil Field

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Testing Center; 2010 Geothermal Technology Program Peer Review Report | Department of Energy Field - Rocky Mountain Oil Field Testing Center; 2010 Geothermal Technology Program Peer Review Report Geothermal Testing Facilities in an Oil Field - Rocky Mountain Oil Field Testing Center; 2010 Geothermal Technology Program Peer Review Report DOE 2010 Geothermal Technologies Program Peer Review lowtemp_014_johnson.pdf (258.37 KB) More Documents & Publications Electrical Power Generation Using

  18. STEO January 2013 - oil production increase

    Energy Information Administration (EIA) (indexed site)

    oil production to increase in 2013 and 2014 U.S. crude oil production is expected to keep rising over the next two years. America's oil output will jump nearly 900,000 barrels per day in 2013 to an average 7.3 million barrels a day, according to the latest monthly forecast from the U.S. Energy Information Administration. This would mark the biggest one-year increase in output since U.S. commercial crude oil production began in 1859. U.S. daily oil production is expected to rise by another

  19. Oil field waste disposal costs at commercial disposal facilities

    SciTech Connect

    Veil, J.A.

    1997-10-01

    The exploration and production segment of the U.S. oil and gas industry generates millions of barrels of nonhazardous oil field wastes annually. In most cases, operators can dispose of their oil fields wastes at a lower cost on-site than off site and, thus, will choose on-site disposal. However, a significant quantity of oil field wastes are still sent to off-site commercial facilities for disposal. This paper provides information on the availability of commercial disposal companies in different states, the treatment and disposal methods they employ, and how much they charge. There appear to be two major off-site disposal trends. Numerous commercial disposal companies that handle oil field wastes exclusively are located in nine oil-and gas-producing states. They use the same disposal methods as those used for on-site disposal. In addition, the Railroad Commission of Texas has issued permits to allow several salt caverns to be used for disposal of oil field wastes. Twenty-two other oil- and gas-producing states contain few or no disposal companies dedicated to oil and gas industry waste. The only off-site commercial disposal companies available handle general industrial wastes or are sanitary landfills. In those states, operators needing to dispose of oil field wastes off-site must send them to a local landfill or out of state. The cost of off-site commercial disposal varies substantially, depending on the disposal method used, the state in which the disposal company is located, and the degree of competition in the area.

  20. Landslide oil field, San Joaquin Valley, California

    SciTech Connect

    Collins, B.P.; March, K.A.; Caballero, J.S.; Stolle, J.M.

    1988-03-01

    The Landslide field, located at the southern margin of the San Joaquin basin, was discovered in 1985 by a partnership headed by Channel Exploration Company, on a farm out from Tenneco Oil Company. Initial production from the Tenneco San Emidio 63X-30 was 2064 BOPD, making landslide one of the largest onshore discoveries in California during the past decade. Current production is 7100 BOPD from a sandstone reservoir at 12,500 ft. Fifteen wells have been drilled in the field, six of which are water injectors. Production from the Landslide field occurs from a series of upper Miocene Stevens turbidite sandstones that lie obliquely across an east-plunging structural nose. These turbidite sandstones were deposited as channel-fill sequences within a narrowly bounded levied channel complex. Both the Landslide field and the larger Yowlumne field, located 3 mi to the northwest, comprise a single channel-fan depositional system that developed in the restricted deep-water portion of the San Joaquin basin. Information from the open-hole logs, three-dimensional surveys, vertical seismic profiles, repeat formation tester data, cores, and pressure buildup tests allowed continuous drilling from the initial discovery to the final waterflood injector, without a single dry hole. In addition, the successful application of three-dimensional seismic data in the Landslide development program has helped correctly image channel-fan anomalies in the southern Maricopa basin, where data quality and severe velocity problems have hampered previous efforts. New exploration targets are currently being evaluated on the acreage surrounding the Landslide discovery and should lead to an interesting new round of drilling activity in the Maricopa basin.

  1. Field development options for a waterflooded heavy-oil reservoir

    SciTech Connect

    Kasraie, M. ); Sammon, P.H. ); Jespersen, P.J. )

    1993-09-01

    Battrum Unit 4 is a moderately heavy-oil reservoir in Saskatchewan producing under waterflood from a thin sand. This paper describes a history match of previous field behavior and systematically analyzes through the use of numerical simulation the potential benefits to production of further waterflooding (with and without infill drilling), steamflooding, and horizontal drilling. It is found that the remaining oil recovery potential of a steamflood with horizontal well is significantly higher than that of any of the waterflood options.

  2. Production optimization in the Provincia field, Colombia

    SciTech Connect

    Blann, J.; Jacobson, L.; Faber, C.

    1989-02-01

    Designing or redesigning production facilities for optimum operation usually results in the generation of maximum profit from an installation. But in older fields, or fields where a short life is expected, design changes may not be a viable option. In such cases, obtaining maximum production within the limits of existing facilities, thereby minimizing new investments, may be an attractive option. This paper discusses application of the latter technique in the Provincia field, Colombia, to optimize oil and gas production within constraints imposed by periodic temporary gas-compression-capacity restrictions and by the configuration of existing oil and gas facilities. The multistep optimization program used at Provincia included improvement of individual well performance, optimization of individual well facilities, fieldwide optimization of surface facilities, and optimization of the field production scheme.

  3. Field-to-Fuel Performance Testing of Various Biomass Feedstocks: Production and Catalytic Upgrading of Bio-Oil to Refinery Blendstocks (Presentation)

    SciTech Connect

    Carpenter, D.; Westover, T.; Howe, D.; Evans, R.; French, R.; Kutnyakov, I.

    2014-09-01

    Large-scale, cost-competitive deployment of thermochemical technologies to replace petroleum oil with domestic biofuels will require inclusion of high volumes of low-cost, diverse biomass types into the supply chain. However, a comprehensive understanding of the impacts of feedstock thermo-physical and chemical variability, particularly inorganic matter (ash), on the yield and product distribution

  4. Methodology for Monthly Crude Oil Production Estimates

    Energy Information Administration (EIA) (indexed site)

    015 U.S. Energy Information Administration | Methodology for Monthly Crude Oil Production Estimates 1 Methodology for Monthly Crude Oil Production Estimates Executive summary The U.S. Energy Information Administration (EIA) relies on data from state and other federal agencies and does not currently collect survey data directly from crude oil producers. Summarizing the estimation process in terms of percent of U.S. production: * 20% is based on state agency data, including North Dakota and

  5. Remediation of oil field wastes

    SciTech Connect

    Peters, R.W.; Wentz, C.A.

    1990-01-01

    Treatment and disposal of drilling muds and hazardous wastes has become a growing concern in the oil and gas industry. Further, past practices involving improper disposal require considerable research and cost to effectively remediate contaminated soils. This paper investigates two case histories describing the treatments employed to handle the liquid wastes involved. Both case histories describe the environmentally safe cleanup operations that were employed. 1 ref., 1 fig., 3 tabs.

  6. OPEC Crude Oil Production 1998-2001

    Gasoline and Diesel Fuel Update

    OPEC Crude Oil Production 1998-2001 History Projections Sources: History: EIA; Projections: Short-Term Energy Outlook, March 2001. Previous slide Next slide Back to first slide ...

  7. A field laboratory for improved oil recovery

    SciTech Connect

    Hildebrandt, A.F.; McDonald, J.; Claridge, E.; Killough, J.

    1992-09-01

    The purpose of Annex III of the Memorandum of Understanding, undertaken by the Houston Petroleum Research Center at the University of Houston, was to develop a field laboratory for research in improved oil recovery using a Gulf Coast reservoir in Texas. The participants: (1) make a field site selection and conducted a high resolution seismic survey in the demonstration field, (2) obtained characteristics of the reservoir (3) developed an evaluation of local flood efficiency in different parts of the demonstration reservoir, (4) used diverse methodology to evaluate the potential recovery of the remaining oil in the test reservoir, (5) developed cross-well seismic tomography, and (6) will transfer the learned technologies to oil operators through publication and workshops. This abstract is an overview of these tasks.

  8. Total Crude Oil and Petroleum Products Exports

    Energy Information Administration (EIA) (indexed site)

    Exports Product: Total Crude Oil and Petroleum Products Crude Oil Natural Gas Plant Liquids and Liquefied Refinery Gases Pentanes Plus Liquefied Petroleum Gases Ethane/Ethylene Propane/Propylene Normal Butane/Butylene Isobutane/Isobutylene Other Liquids Hydrogen/Oxygenates/Renewables/Other Hydrocarbons Oxygenates (excl. Fuel Ethanol) Methyl Tertiary Butyl Ether (MTBE) Other Oxygenates Renewable Fuels (incl. Fuel Ethanol) Fuel Ethanol Biomass-Based Diesel Unfinished Oils Naphthas and Lighter

  9. High oil production continues to cut U.S. oil imports

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    High oil production continues to cut U.S. oil imports High U.S. crude oil production will help further reduce America's reliance on oil imports during the next two years. In its ...

  10. U.S. oil imports to decline with rising oil production through...

    Gasoline and Diesel Fuel Update

    oil imports to decline with rising oil production through 2014 The United States will need fewer oil imports over the next two years because of rising U.S. oil production. The new ...

  11. Soviet oil production begins to falter

    SciTech Connect

    Fueg, J.C

    1989-08-01

    Soviet industry managers are warning that a new oil production slump may be on the way, especially in the crucial West Siberian industry. The USSR's global energy balance will depend on accelerating natural gas development. In the rest of Eastern Europe, Albania, Poland, Romania and Yugoslavia all showed significant declines in oil production.

  12. OPEC Crude Oil Production 1998-2001

    Gasoline and Diesel Fuel Update

    OPEC began increasing production again in 2000. World oil production increased by 3.5 million barrels per day from fourth quarter 1999 to fourth quarter 2000 to reach 77.9 million ...

  13. Increased oil production and reserves from improved completion techniques in the Bluebell Field, Uinta Basin, Utah. Quarterly technical progress report, April 1, 1996--June 30, 1996, 11th Quarter of the project

    SciTech Connect

    Allison, E.; Morgan, C.D.

    1996-07-30

    The objective of this project is to increase oil production and reserves in the Uinta Basin by demonstrating improved completion techniques. Low productivity of Uinta Basin wells is caused by gross production intervals of several thousand feet that contain perforated thief zones, water-bearing zones, and unperforated oil-bearing intervals. Geologic and engineering characterization and computer simulation of the Green River and Wasatch formations in the Bluebell field will determine reservoir heterogeneities related to fractures and depositional trends. This will be followed by drilling and recompletion of several wells to demonstrate improved completion techniques based on the reservoir characterization. Transfer of the project results will be an ongoing component of the project.

  14. Oil geochemistry study; Blocks III and IV Bachaquedro Field, Lake Maracaibo, Venezuela

    SciTech Connect

    Patterson, B.A.; Villarroel, H.G. de; Rondon, L.

    1996-08-01

    Blocks III and IV Bachaquero, Field, located on the east side of Lake Maracaibo, comprise an area of 40 square kilometers. In 1956 the discovery well penetrated oil saturated sands in a south dipping homoclinal structure. In 1958 production reached a maximum of 245,000 barrels per day of moderate gravity oil from three Miocene age Lagunillas Formation sands, designated as L, M, and N. The Bachaquero Field has experienced production problems including high gas-oil ratios from M and N sands to the north, high water cuts in all three sands to the south, and low production rates in the southeast. In addition, the vertical and lateral continuity of the oil pools are unknown. High resolution gas chromatography and analysis of biological markers was employed in order to resolve the continuity of the oil pools, determine genetic origin of the oils, and shed light on erratic production. Oil in the L sands are vertically discontinuous from oil in the M+N sands. The two oil pools appear laterally continuous within the study area, indicating absence of fault barriers. Well VLD 311, open to both L and M sands, produces a mix of oils, but with a strong contribution from the M sand. Bachaquero Field reservoirs were charged with oil from two different facies of the Upper Cretaceous La Luna or perhaps from La Luna and Colon source rocks as the stratigraphically younger L sands contain less mature oil with a stronger terrigenous imprint than oil the M and N sands.

  15. Conversion Technologies for Advanced Biofuels - Bio-Oil Production |

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Department of Energy Oil Production Conversion Technologies for Advanced Biofuels - Bio-Oil Production RTI International report-out at the CTAB webinar on Conversion Technologies for Advanced Biofuels - Bio-Oil Production. ctab_webinar_bio_oils_production.pdf (772.25 KB) More Documents & Publications Conversion Technologies for Advanced Biofuels - Bio-Oil Upgrading 2013 Peer Review Presentations-Bio-oil Workshop on Conversion Technologies for Advanced Biofuels - Bio-Oils

  16. US Crude Oil Production Surpasses Net Imports | Department of...

    Office of Environmental Management (EM)

    US Crude Oil Production Surpasses Net Imports US Crude Oil Production Surpasses Net Imports Source: Energy Information Administration Short Term Energy Outlook. Chart by Daniel...

  17. Engineered microbes and methods for microbial oil production...

    Office of Scientific and Technical Information (OSTI)

    Engineered microbes and methods for microbial oil production Title: Engineered microbes and methods for microbial oil production Some aspects of this invention provide engineered ...

  18. Engineered microbes and methods for microbial oil production...

    Office of Scientific and Technical Information (OSTI)

    Patent: Engineered microbes and methods for microbial oil production Citation Details In-Document Search Title: Engineered microbes and methods for microbial oil production Some ...

  19. Potential Oil Production from the Coastal Plain of the Arctic...

    Annual Energy Outlook

    Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment Preface Potential Oil Production from the Coastal Plain of the Arctic ...

  20. Engineered microbes and methods for microbial oil production...

    Office of Scientific and Technical Information (OSTI)

    Data Explorer Search Results Engineered microbes and methods for microbial oil production Title: Engineered microbes and methods for microbial oil production Some aspects of this ...

  1. Potential Oil Production from the Coastal Plain of the Arctic...

    Energy Information Administration (EIA) (indexed site)

    Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment Executive Summary This Service Report, Potential Oil Production from the ...

  2. Improving Microalgal Oil Production Based on Quantitative, Biochemical...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Microalgal Oil Production Based on Quantitative, Biochemical and Genetic Analyses of ... Goal Statement * Maximizing production of oil (triacylglycerols) in the green alga ...

  3. ,"Crude Oil and Petroleum Products Total Stocks Stocks by Type...

    Energy Information Administration (EIA) (indexed site)

    Data for" ,"Data 1","Crude Oil and Petroleum Products Total Stocks Stocks ... PM" "Back to Contents","Data 1: Crude Oil and Petroleum Products Total Stocks Stocks ...

  4. US Crude Oil Production Surpasses Net Imports | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    US Crude Oil Production Surpasses Net Imports US Crude Oil Production Surpasses Net Imports Source: Energy Information Administration Short Term Energy Outlook. Chart by Daniel Wood.

  5. Application of oil gas-chromatography in reservoir compartmentalization in a mature Venezuelan oil field

    SciTech Connect

    Munoz, N.G.; Mompart, L.; Talukdar, S.C.

    1996-08-01

    Gas chromatographic oil {open_quotes}fingerprinting{close_quotes} was successfully applied in a multidisciplinary production geology project by Maraven, S.A. to define the extent of vertical and lateral continuity of Eocene and Miocene sandstone reservoirs in the highly faulted Bloque I field, Maracaibo Basin, Venezuela. Seventy-five non-biodegraded oils (20{degrees}-37.4{degrees} API) were analyzed with gas chromatography. Fifty were produced from the Eocene Misoa C-4, C-5, C-6 or C-7 horizons, fifteen from the Miocene basal La Rosa and ten from multizone completions. Gas chromatographic and terpane and sterane biomarker data show that all of the oils are genetically related. They were expelled from a type II, Upper Cretaceous marine La Luna source rock at about 0.80-0.90% R{sub o} maturity. Alteration in the reservoir by gas stripping with or without subsequent light hydrocarbons mixing was observed in some oils. Detailed chromatographic comparisons among the oils shown by star plots and cluster analysis utilizing several naphthenic and aromatic peak height ratios, resulted in oil pool groupings. This led to finding previously unknown lateral and vertical reservoir communication and also helped in checking and updating the scaling character of faults. In the commingled oils, percentages of each contributing zone in the mixture were also determined giving Maraven engineers a proven, rapid and inexpensive tool for production allocation and reservoir management The oil pool compartmentalization defined by the geochemical fingerprinting is in very good agreement with the sequence stratigraphic interpretation of the reservoirs and helped evaluate the influence of structure in oil migration and trapping.

  6. VEE-0023- In the Matter of Oil Products, Inc.

    Office of Energy Efficiency and Renewable Energy (EERE)

    On May 13, 1996, Oil Products, Inc. (Oil Products) filed an Application for Exception with the Office of Hearings and Appeals (OHA) of the Department of Energy (DOE). In its application, Oil...

  7. Hydroprocessing Bio-oil and Products Separation for Coke Production

    SciTech Connect

    Elliott, Douglas C.; Neuenschwander, Gary G.; Hart, Todd R.

    2013-04-01

    Fast pyrolysis of biomass can be used to produce a raw bio-oil product, which can be upgraded by catalytic hydroprocessing to hydrocarbon liquid products. In this study the upgraded products were distilled to recover light naphtha and oils and to produce a distillation resid with useful properties for coker processing and production of renewable, low-sulfur electrode carbon. For this hydroprocessing work, phase separation of the bio-oil was applied as a preparatory step to concentrate the heavier, more phenolic components thus generating a more amenable feedstock for resid production. Low residual oxygen content products were produced by continuous-flow, catalytic hydroprocessing of the phase separated bio-oil.

  8. Production of hydrogen from oil shale

    SciTech Connect

    Schora, F. C.; Feldkirchner, H. L.; Janka, J. C.

    1985-12-24

    A process for production of hydrogen from oil shale fines by direct introduction of the oil shale fines into a fluidized bed at temperatures about 1200/sup 0/ to about 2000/sup 0/ F. to obtain rapid heating of the oil shale. The bed is fluidized by upward passage of steam and oxygen, the steam introduced in the weight ratio of about 0.1 to about 10 on the basis of the organic carbon content of the oil shale and the oxygen introduced in less than the stoichiometric quantity for complete combustion of the organic carbonaceous kerogen content of the oil shale. Embodiments are disclosed for heat recovery from the spent shale and heat recovery from the spent shale and product gas wherein the complete process and heat recovery is carried out in a single reaction vessel. The process of this invention provides high conversion of organic carbon component of oil shale and high production of hydrogen from shale fines which when used in combination with a conventional oil shale hydroconversion process results in increased overall process efficiency of greater than 15 percent.

  9. Experiences in the design of CRA`s for erosion/corrosion control in the production facilities of eastern Venezuela oil fields

    SciTech Connect

    Romero, N.; Palacios, C.A.

    1997-08-01

    It is a well known fact that CRA`s are used in the oil industry as one way to control erosion/corrosion effects. Many fields in the eastern region of Venezuela are considered corrosive due to the presence of CO{sub 2} (5 to 20%), H{sub 2}S (up to 5 ppm), and water (50% water cut) contained in the produced hydrocarbons (condensated). For some areas, the hydrocarbon is accompanied by sand, making them erosive as well. These conditions and frequent failures experienced in the field, led to the use of CRA`s. For the wells, 13% Cr and bimetallic (carbon steel/13% Cr) tubing was used for 51 condensate wells containing 5 to 20% CO{sub 2}. For the surface equipment (valves, reducers, expanders and other types of fittings) tungsten carbide hard facing were used, for some of the valves, a epoxi-phenolic coating was used. This article describes the different design criteria used for the installation of the tubing, the logistics involved during field inspections and handling tips to avoid galling during workovers. It also, presents results from the bi-metallic tubing and the hard facings used for the surface equipment.

  10. Crosshole EM for oil field characterization and EOR monitoring: Field examples from Lost Hills, California

    SciTech Connect

    Wilt, M.; Schenkel, C.; Wratcher, M.; Lambert, I.; Torres-Verdin, C.; Tseng H.W.

    1996-07-16

    A steamflood recently initiated by Mobil Development and Production U.S. at the Lost Hills No 3 oil field in California is notable for its shallow depth and the application of electromagnetic (EM) geophysical techniques to monitor the subsurface steam flow. Steam was injected into three stacked eastward-dipping unconsolidated oil sands at depths from 60 to 120 m; the plume is expected to develop as an ellipsoid aligned with the regional northwest-southeast strike. Because of the shallow depth of the sands and the high viscosity of the heavy oil, it is important to track the steam in the unconsolidated sediments for both economic and safety reasons. Crosshole and surface-to-borehole electromagnetic imaging were applied for reservoir characterization and steamflood monitoring. The crosshole EM data were collected to map the interwell distribution of the high-resistivity oil sands and to track the injected steam and hot water. Measurements were made in two fiberglass-cased observation wells straddling the steam injector on a northeast-southwest profile. Field data were collected before the steam drive, to map the distribution of the oil sands, and then 6 and 10 months after steam was injected, to monitor the expansion of the steam chest. Resistivity images derived from the collected data clearly delineated the distribution and dipping structure of the target oil sands. Difference images from data collected before and during steamflooding indicate that the steam chest has developed only in the middle and lower oil sands, and it has preferentially migrated westward in the middle oil sand and eastward in the deeper sand. Surface-to-borehole field data sets at Lost Hills were responsive to the large-scale subsurface structure but insufficiently sensitive to model steam chest development in the middle and lower oil sands. As the steam chest develops further, these data will be of more use for process monitoring.

  11. Increased oil production and reserves from improved completion techniques in the Bluebell Field, Uinta Basin, Utah. Annual report, October 1, 1994--September 30, 1995

    SciTech Connect

    Allison, M.L.; Morgan, C.D.

    1996-05-01

    The Bluebell field produces from the Tertiary lower Green River and Wasatch Formations of the Uinta Basin, Utah. The productive interval consists of thousands of feet of interbedded fractured clastic and carbonate beds deposited in a fluvial-dominated deltaic lacustrine environment. Wells in the Bluebell field are typically completed by perforating 40 or more beds over 1,000 to 3,000 vertical feet (300-900 m), then applying an acid-fracture stimulation treatment to the entire interval. This completion technique is believed to leave many potentially productive beds damaged and/or untreated, while allowing water-bearing and low-pressure (thief) zones to communicate with the wellbore. Geologic and engineering characterization has been used to define improved completion techniques. The study identified reservoir characteristics of beds that have the greatest long-term production potential.

  12. Oil and gas field code master list, 1993

    SciTech Connect

    Not Available

    1993-12-16

    This document contains data collected through October 1993 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the United States. Other Federal and State government agencies, as well as industry, use the EIA Oil and Gas Field Code Master List as the standard for field identification. A machine-readable version of the Oil and Gas Field Code Master List is available from the National Technical Information Service.

  13. Oil field experiments of microbial improved oil recovery in Vyngapour, West Siberia, Russia

    SciTech Connect

    Murygina, V.P.; Mats, A.A.; Arinbasarov, M.U.; Salamov, Z.Z.; Cherkasov, A.B.

    1995-12-31

    Experiments on microbial improved oil recovery (MIOR) have been performed in the Vyngapour oil field in West Siberia for two years. Now, the product of some producing wells of the Vyngapour oil field is 98-99% water cut. The operation of such wells approaches an economic limit. The nutritious composition containing local industry wastes and sources of nitrogen, phosphorus and potassium was pumped into an injection well on the pilot area. This method is called {open_quotes}nutritional flooding.{close_quotes} The mechanism of nutritional flooding is based on intensification of biosynthesis of oil-displacing metabolites by indigenous bacteria and bacteria from food industry wastes in the stratum. 272.5 m{sup 3} of nutritious composition was introduced into the reservoir during the summer of 1993, and 450 m3 of nutritious composition-in 1994. The positive effect of the injections in 1993 showed up in 2-2.5 months and reached its maximum in 7 months after the injections were stopped. By July 1, 1994, 2,268.6 tons of oil was produced over the base variant, and the simultaneous water extraction reduced by 33,902 m{sup 3} as compared with the base variant. The injections in 1994 were carried out on the same pilot area.

  14. Top 100 Oil and Gas Fields of 2009

    Energy Information Administration (EIA) (indexed site)

    Top 100 Oil and Gas Fields of 2009 Introduction This supplement to the Energy Information Administration's summary of U.S. Crude Oil, Natural Gas, and Natural Gas Liquids Proved Reserves, 2009 ranks the United States' largest oil and gas fields by their estimated 2009 proved reserves. The Top 100's Share of U.S. Proved Reserves in 2009 The Top 100 oil fields and Top 100 gas fields each accounted for about 60 percent of the respective total proved reserves of the United States. The Top 100 oil

  15. Crude Oil and Petroleum Products Movements by Tanker and Barge...

    Gasoline and Diesel Fuel Update

    Feed. Use Other Oils for Petrochem. Feed. Use Special Naphthas Lubricants Waxes Asphalt and Road Oil Miscellaneous Products Period-Unit: Monthly-Thousand Barrels Annual-Thousand ...

  16. Conversion Technologies for Advanced Biofuels - Bio-Oil Production...

    Energy.gov [DOE] (indexed site)

    for Advanced Biofuels - Bio-Oil Production. ctabwebinarbiooilsproduction.pdf (772.25 KB) More Documents & Publications Conversion Technologies for Advanced Biofuels - Bio-Oil ...

  17. Potential Oil Production from the Coastal Plain of the Arctic...

    Gasoline and Diesel Fuel Update

    Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: ... of technically recoverable undiscovered oil are in the ANWR coastal plain, a 5 percent ...

  18. Potential Oil Production from the Coastal Plain of the Arctic...

    Energy Information Administration (EIA) (indexed site)

    Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment 2. Analysis Discussion Resource Assessment The USGS most recent assessment of oil ...

  19. Assessment of microorganisms from Indonesian Oil Fields

    SciTech Connect

    Kadarwati, S.; Udiharto, M.; Rahman, M.; Jasjfi, E.; Legowo, E.H.

    1995-12-31

    Petroleum resources have been the mainstay of the national development in Indonesia. However, resources are being depleted after over a century of exploitation, while the demand continues to grow with the rapid economic development of the country. In facing the problem, EOR has been applied in Indonesia, such as the steamflooding project in Duri field, but a more energy efficient technology would be preferable. Therefore, MEOR has been recommended as a promising solution. Our study, aimed at finding indigenous microorganisms which can be developed for application in MEOR, has isolated microbes from some oil fields of Indonesia. These microorganisms have been identified, their activities studied, and the effects of their metabolisms examined. This paper describes the research carried out by LEMIGAS in this respect, giving details on the methods of sampling, incubation, identification, and activation of the microbes as well as tests on the effects of their metabolites, with particular attention to those with potential for application in MEOR.

  20. Table 5.2 Crude Oil Production and Crude Oil Well Productivity, 1954-2011

    Energy Information Administration (EIA) (indexed site)

    Crude Oil Production and Crude Oil Well Productivity, 1954-2011 Year Crude Oil Production Crude Oil Well 1 Productivity 48 States 2 Alaska 3 Total Onshore Offshore Total Producing Wells 4 Average Productivity 5 Federal State Total Thousand Barrels Thousand Barrels Thousands Barrels per Well 1954 2,314,988 0 2,314,988 2,266,387 NA NA 48,601 2,314,988 511 4,530 1955 2,484,428 0 2,484,428 2,425,289 NA NA 59,139 2,484,428 524 4,741 1956 2,617,283 0 2,617,283 2,543,889 NA NA 73,394 2,617,283 551

  1. Rejuvenation of a giant oil field-Quiriquire Field, Venezuela: A team approach

    SciTech Connect

    Friestad, H.; Hull, R.; Miller, D.

    1996-08-01

    Quiriquire field is located in the Maturin basin of eastern Venezuela, at the southeastern corner of the Serrania del Interior mountain range. Since its discovery in 1928, the field has produced over 750 MMBO from a stratigraphically trapped, shallow, Pliocene alluvial fan (Quiriquire Formation). A deep oil zone, the Los Jabillos sand of Oligocene age, was discovered in 1952 on a deep thrust anticline situated below the shallow oil field. Both zones potentially have significant reserves yet to be recovered. In 1994, Maxus, BP, and Otepi began working with Lagoven to rejuvenate oil production from both zones. Maxus, as operator, has been utilizing geologists, geophysicists, petrophysicists, and reservoir, drilling, construction, and environmental engineers, working together as a team, to fully evaluate the most economic methods of developing these remaining reserves. A program of reactivation and recompletion of old wells, as well as the drilling of deviated infill wells, stepouts, and new exploration plays has been formulated by the team. A staged approach to the broad program will enable Maxus to prioritize those projects which have the best economic return. The use of new technology in seismic, drilling, logging, and completions is expected to improve the recovery of oil over previous conventional methods. Using modern technology to enhance the understanding of the structural and stratigraphic trapping mechanisms, the team has defined and built structural and seismic models to help identify possible productive reservoirs.

  2. ,"U.S. Total Crude Oil and Products Imports"

    Energy Information Administration (EIA) (indexed site)

    ... of Crude Oil and Petroleum Products (Thousand Barrels per Day)","U.S. Imports from Guatemala of Crude Oil and Petroleum Products (Thousand Barrels per Day)","U.S. Imports from ...

  3. ,"U.S. Total Crude Oil and Products Imports"

    Energy Information Administration (EIA) (indexed site)

    ... Greece of Crude Oil and Petroleum Products (Thousand Barrels)","U.S. Imports from Guatemala of Crude Oil and Petroleum Products (Thousand Barrels)","U.S. Imports from Guinea of ...

  4. ,"U.S. Total Crude Oil and Products Imports"

    Energy Information Administration (EIA) (indexed site)

    ... Panama of Crude Oil and Petroleum Products (Thousand Barrels)","U.S. Imports from Papua New Guinea of Crude Oil and Petroleum Products (Thousand Barrels)","U.S. Imports from Peru ...

  5. ,"U.S. Total Crude Oil and Products Imports"

    Energy Information Administration (EIA) (indexed site)

    ... Belgium of Crude Oil and Petroleum Products (Thousand Barrels)","U.S. Imports from Belize of Crude Oil and Petroleum Products (Thousand Barrels)","U.S. Imports from Benin of ...

  6. Implications of Increasing U.S. Crude Oil Production

    Gasoline and Diesel Fuel Update

    Implications of Increasing U.S. Crude Oil Production By John Powell June 18, 2013 U.S. crude oil production is up dramatically since 2010 and will continue to grow rapidly; this has implications for: John Powell June 18, 2013 2 * Refinery operations * Refinery investment * Logistics infrastructure investment * Exports of petroleum products * Exports of crude oil Increased U.S. crude oil production has resulted in: John Powell June 18, 2013 3 * Declines in U.S. crude imports * Changes to refinery

  7. Oil and Gas Field Code Master List 1990

    SciTech Connect

    Not Available

    1991-01-04

    This is the ninth annual edition of the Energy Information Administration's (EIA) Oil and Gas Field Code Master List. It reflects data collected through October 1990 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the United States. There are 54,963 field records in this year's Oil and Gas Field Code Master List (FCML). This amounts to 467 more than in last year's report. As it is maintained by EIA, the Master List includes: Field records for each state and county in which a field resides; field records for each offshore area block in the Gulf of Mexico in which a field resides;field records for each alias field name; fields crossing state boundaries that may be assigned different names by the respective state naming authorities.

  8. Method of determining interwell oil field fluid saturation distribution

    DOEpatents

    Donaldson, Erle C.; Sutterfield, F. Dexter

    1981-01-01

    A method of determining the oil and brine saturation distribution in an oil field by taking electrical current and potential measurements among a plurality of open-hole wells geometrically distributed throughout the oil field. Poisson's equation is utilized to develop fluid saturation distributions from the electrical current and potential measurement. Both signal generating equipment and chemical means are used to develop current flow among the several open-hole wells.

  9. Economic evaluation on CO₂-EOR of onshore oil fields in China

    DOE PAGES [OSTI]

    Wei, Ning; Li, Xiaochun; Dahowski, Robert T.; Davidson, Casie L.; Liu, Shengnan; Zha, Yongjin

    2015-06-01

    Carbon dioxide enhanced oil recovery (CO₂-EOR) and sequestration in depleted oil reservoirs is a plausible option for utilizing anthropogenic CO₂ to increase oil production while storing CO₂ underground. Evaluation of the storage resources and cost of potential CO₂-EOR projects is an essential step before the commencement of large-scale deployment of such activities. In this paper, a hybrid techno-economic evaluation method, including a performance model and cost model for onshore CO₂-EOR projects, has been developed based on previous studies. Total 296 onshore oil fields, accounting for about 70% of total mature onshore oil fields in China, were evaluated by the techno-economicmore » method. The key findings of this study are summarized as follows: (1) deterministic analysis shows there are approximately 1.1 billion tons (7.7 billion barrels) of incremental crude oil and 2.2 billion tons CO₂ storage resource for onshore CO₂-EOR at net positive revenue within the Chinese oil fields reviewed under the given operating strategy and economic assumptions. (2) Sensitivity study highlights that the cumulative oil production and cumulative CO₂ storage resource are very sensitive to crude oil price, CO₂ cost, project lifetime, discount rate and tax policy. High oil price, short project lifetime, low discount rate, low CO₂ cost, and low tax policy can greatly increase the net income of the oil enterprise, incremental oil recovery and CO₂ storage resource. (3) From this techno-economic evaluation, the major barriers to large-scale deployment of CO₂-EOR include complex geological conditions, low API of crude oil, high tax policy, and lack of incentives for the CO₂-EOR project.« less

  10. Economic evaluation on CO₂-EOR of onshore oil fields in China

    SciTech Connect

    Wei, Ning; Li, Xiaochun; Dahowski, Robert T.; Davidson, Casie L.; Liu, Shengnan; Zha, Yongjin

    2015-06-01

    Carbon dioxide enhanced oil recovery (CO₂-EOR) and sequestration in depleted oil reservoirs is a plausible option for utilizing anthropogenic CO₂ to increase oil production while storing CO₂ underground. Evaluation of the storage resources and cost of potential CO₂-EOR projects is an essential step before the commencement of large-scale deployment of such activities. In this paper, a hybrid techno-economic evaluation method, including a performance model and cost model for onshore CO₂-EOR projects, has been developed based on previous studies. Total 296 onshore oil fields, accounting for about 70% of total mature onshore oil fields in China, were evaluated by the techno-economic method. The key findings of this study are summarized as follows: (1) deterministic analysis shows there are approximately 1.1 billion tons (7.7 billion barrels) of incremental crude oil and 2.2 billion tons CO₂ storage resource for onshore CO₂-EOR at net positive revenue within the Chinese oil fields reviewed under the given operating strategy and economic assumptions. (2) Sensitivity study highlights that the cumulative oil production and cumulative CO₂ storage resource are very sensitive to crude oil price, CO₂ cost, project lifetime, discount rate and tax policy. High oil price, short project lifetime, low discount rate, low CO₂ cost, and low tax policy can greatly increase the net income of the oil enterprise, incremental oil recovery and CO₂ storage resource. (3) From this techno-economic evaluation, the major barriers to large-scale deployment of CO₂-EOR include complex geological conditions, low API of crude oil, high tax policy, and lack of incentives for the CO₂-EOR project.

  11. U.S. crude oil production expected to exceed oil imports later this year

    Energy Information Administration (EIA) (indexed site)

    crude oil production expected to exceed oil imports later this year U.S. crude oil production is expected to surpass U.S. crude oil imports by the fourth quarter of this year. That would mark the first time since February 1995 that domestic crude oil output exceeds imports, according to the latest monthly energy outlook from the U.S. Energy Information Administration. The United States will still need to import crude oil to help meet domestic demand. However, total crude oil imports this year

  12. Short-Term Energy Outlook Supplement: Status of Libyan Loading Ports and Oil and Natural Gas Fields

    Gasoline and Diesel Fuel Update

    Short-Term Energy Outlook Supplement: Status of Libyan Loading Ports and Oil and Natural Gas Fields Tuesday, September 10, 2013, 10:00AM EST Overview During July and August 2013, protests at major oil loading ports in the central-eastern region of Libya forced the complete or partial shut-in of oil fields linked to the ports. As a result of protests at ports and at some oil fields, crude oil production fell to 1.0 million barrels per day (bbl/d) in July and 600,000 bbl/d in August, although the

  13. Refinery Stocks of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    Product: Crude Oil and Petroleum Products Crude Oil Petroleum Products Pentanes Plus Liquefied Petroleum Gases Ethane/Ethylene Propane/Propylene Normal Butane/Butylene Isobutane/Isobutylene Oxygenates/Renewables/Other Hydrocarbons Oxygenates (excl. Fuel Ethanol) Methyl Tertiary Butyl Ether (MTBE) All Other Oxygenates Renewable Fuels (incl. Fuel Ethanol) Fuel Ethanol Renewable Diesel Fuel Other Renewable Fuels Other Hydrocarbons Unfinished Oils Naphthas and Lighter Kerosene and Light Gas Oils

  14. Kill fluid for oil field operations

    SciTech Connect

    Sydansk, R.D.

    1990-08-14

    This patent describes a process employing a kill fluid to substantially reduce the volumetric flow of formation fluid into a wellbore penetrating a formation containing the formation fluid below an earthen surface. It comprises: admixing components of a continuous flowing gel at the surface comprising of water-soluble carboxylate-containing polymer, a complex capable of crosslinking the polymer and formed of at least one electropositive chromium III species and at least one electronegative carboxylatespecies, and an aqueous solvent for the polymer and the complex; crosslinking the polymer and the complex to form the gel, wherein the kill fluid comprises the gel; placing a volume of the kill fluid in the wellbore sufficient to create a hydrostatic head which exerts a kill fluid pressure against the formation fluid substantially equal to or greater than the formation fluid pressure and thereby substantially reduces the volumetric flow of the formation fluid into the wellbore; performing an oil field operation after placing the volume of the kill fluid in the wellbore; and removing the gel from the wellbore to substantially restore the volumetric flow of the formation fluid into the wellbore.

  15. Low oil prices cut less into U.S. oil production

    Energy Information Administration (EIA) (indexed site)

    Low oil prices cut less into U.S. oil production U.S. crude oil production has been more resilient to lower oil prices since mid-2014 than many had expected. In its new forecast, the U.S. Energy Information Administration estimates domestic oil production averaged 9.6 million barrels per day in May the highest monthly output since 1972 despite a 60% drop in the number of rigs drilling for oil since last October. Output is up because producers are completing wells already drilled and those wells

  16. Production and Upgrading of Infrastructure Compatible Bio-Oil...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    ... bio-oil production and delivery Base-line fast pyrolysis bio-oil (for this project and ... finished fuels in continuous-flow reactors Low-severity hydrotreating for ...

  17. EIA - Analysis of Crude Oil Production in the Arctic National...

    Annual Energy Outlook

    Notes Analysis of Crude Oil Production in the Arctic National Wildlife Refuge Introduction ... as of 2006 (Washington, DC, 2006). 17 World oil consumption is projected to be 117.6 ...

  18. Higher U.S. oil production in 2013 and 2014 means lower oil imports

    Energy Information Administration (EIA) (indexed site)

    Higher U.S. oil production in 2013 and 2014 means lower oil imports U.S. crude oil production topped 7 million barrels per day in November and December for the first time in 20 years, and production is expected to keep rising over the next two years. The U.S. Energy Information Administration's new monthly forecast sees domestic crude oil output averaging 7.3 million barrels per day this year and climbing to 7.9 million barrels next year. Higher crude oil production means America will need less

  19. Oil and Gas field code master list 1995

    SciTech Connect

    1995-12-01

    This is the fourteenth annual edition of the Energy Information Administration`s (EIA) Oil and Gas Field Code Master List. It reflects data collected through October 1995 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the US. The Field Code Index, a listing of all field names and the States in which they occur, ordered by field code, has been removed from this year`s publications to reduce printing and postage costs. Complete copies (including the Field Code Index) will be available on the EIA CD-ROM and the EIA World-Wide Web Site. Future editions of the complete Master List will be available on CD-ROM and other electronic media. There are 57,400 field records in this year`s Oil and Gas Field Code Master List. As it is maintained by EIA, the Master List includes the following: field records for each State and county in which a field resides; field records for each offshore area block in the Gulf of Mexico in which a field resides; field records for each alias field name (see definition of alias below); and fields crossing State boundaries that may be assigned different names by the respective State naming authorities. Taking into consideration the double-counting of fields under such circumstances, EIA identifies 46,312 distinct fields in the US as of October 1995. This count includes fields that no longer produce oil or gas, and 383 fields used in whole or in part for oil or gas Storage. 11 figs., 6 tabs.

  20. EIA - Analysis of Crude Oil Production in the Arctic National Wildlife

    Energy Information Administration (EIA) (indexed site)

    Refuge - Methodology and Assumptions Methodology and Assumptions Analysis of Crude Oil Production in the Arctic National Wildlife Refuge Methodology and Assumptions The effects of opening the coastal plain area of ANWR were determined by incorporating the ANWR region into the National Energy Modeling System (NEMS).5 The key assumptions required to project crude oil production from the coastal plain of ANWR include: timing of first production, timing of continuing development, field size

  1. Application of bio-huff-`n`-puff technology at Jilin oil field

    SciTech Connect

    Xiu-Yuan Wang; Yan-Fed Xue; Gang Dai; Ling Zhao

    1995-12-31

    An enriched culture 48, capable of adapting to the reservoir conditions and fermenting molasses to produce gas and acid, was used as an inoculum for bio- huff-`n`-puff tests at Fuyu oil area of Jilin oil field. The production well was injected with water containing 4-6% (v/v) molasses and inoculum, and then shut in. After 15-21 days, the well was placed back in operation. A total of 44 wells were treated, of which only two wells showed no effects. The daily oil production of treated wells increased by 33.3-733.3%. Up to the end of 1994, the oil production was increased by 204 tons per well on average. Results obtained from various types of production wells were discussed.

  2. Petroleum geology of Giant oil and gas fields in Turpan Basin Xinjiang China

    SciTech Connect

    Boliang, Hu; Jiajing, Yang,

    1995-08-01

    Turpan Basin is the smallest and the last development basin in three big basins of Xinjiang autonomous region, P.R. China. Since April, 1989, the Shanshan oilfield was discovered, the Oinling, Wenjisang, Midang, Baka, Qiudong and North Putaogou fields were discovered. In 1994, the crude oil productivity of Turpan Basin was a Million tons, with an estimated output of 3 million tons per year by 1995; obviously a key oil productive base in the west basins of China, Tarim, Jungar, Chaidam, Hexi, Erduos and Sichuan Basins. The Turpan Basin is an intermontane basin in a eugeosyncline foldbelt of the north Tianshan Mountains. The oil and gas was produced from the payzone of the Xishanyao, Sanjianfang and Qiketai Formatiosn of the Middle Jurassic series. The geochemical characteristics of the crude oil and gas indicate they derive from the Middle to Lower Jurassic coal series, in which contains the best oil-prone source rocks in the basin.

  3. Preliminary technical and legal evaluation of disposing of nonhazardous oil field waste into salt caverns

    SciTech Connect

    Veil, J.; Elcock, D.; Raivel, M.; Caudle, D.; Ayers, R.C. Jr.; Grunewald, B.

    1996-06-01

    Caverns can be readily formed in salt formations through solution mining. The caverns may be formed incidentally, as a result of salt recovery, or intentionally to create an underground chamber that can be used for storing hydrocarbon products or compressed air or disposing of wastes. The purpose of this report is to evaluate the feasibility, suitability, and legality of disposing of nonhazardous oil and gas exploration, development, and production wastes (hereafter referred to as oil field wastes, unless otherwise noted) in salt caverns. Chapter 2 provides background information on: types and locations of US subsurface salt deposits; basic solution mining techniques used to create caverns; and ways in which salt caverns are used. Later chapters provide discussion of: federal and state regulatory requirements concerning disposal of oil field waste, including which wastes are considered eligible for cavern disposal; waste streams that are considered to be oil field waste; and an evaluation of technical issues concerning the suitability of using salt caverns for disposing of oil field waste. Separate chapters present: types of oil field wastes suitable for cavern disposal; cavern design and location; disposal operations; and closure and remediation. This report does not suggest specific numerical limits for such factors or variables as distance to neighboring activities, depths for casings, pressure testing, or size and shape of cavern. The intent is to raise issues and general approaches that will contribute to the growing body of information on this subject.

  4. Production Hydraulic Packer Field Test

    SciTech Connect

    Schneller, Tricia; Salas, Jose

    2000-06-30

    In October 1999, the Rocky Mountain Oilfield Testing Center and Halliburton Energy Services cooperated on a field test of Halliburton's new Production Hydraulic Packer technology on Well 46-TPX-10 at Naval Petroleum Reserve No. 3 near Casper, WY. Performance of the packer was evaluated in set and unset operations. The packer's ability to seal the annulus between the casing and tubing was hydraulically tested and the results were recorded.

  5. Geology and geochemistry of crude oils, Bolivar coastal fields, Venezuela

    SciTech Connect

    Bockmeulen, H.; Barker, C.; Dickey, P.A.

    1983-02-01

    The Bolivar Coastal Fields (BCF) are located on the eastern margin of Lake Maracaibo, Venezuela. They form the largest oil field outside of the Middle East and contain mostly heavy oil with a gravity less than 22/sup 0/ API. Thirty crude oils from the BCF were collected along two parallel and generally southwest-northeast trends. These oils were characterized by their API gravity, percent saturates, aromatics, NSO and asphalitic compounds, gas chromatograms for whole oils, C/sub 4/-C/sub 7/ fractions, and aromatics. Also, 24 associated waters were sampled and analyzed for Ca/sup + +/, Mg/sup + +/, Na/sup +/, HCO/sub 3//sup -/, CO/sub 3//sup - -/, SO/sub 4//sup - -/, pH, and total dissolved solids (TDS). The geological and geochemical significances of these analyses are discussed with particular emphasis on the genesis of the petroleum.

  6. California State Offshore Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries CA, State Offshore Crude Oil plus

  7. West Virginia Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries West Virginia Crude Oil plus Lease Condensate

  8. Engineered microbes and methods for microbial oil production (Patent) |

    Office of Scientific and Technical Information (OSTI)

    DOEPatents Engineered microbes and methods for microbial oil production Title: Engineered microbes and methods for microbial oil production Some aspects of this invention provide engineered microbes for oil production. Methods for microbe engineering and for use of engineered microbes are also provided herein. In some embodiments, microbes are provided that are engineered to modulate a combination of rate-controlling steps of lipid synthesis, for example, a combination of a step generating

  9. Planning and management of the Nido Reef Complex Oil Field development, Philippines

    SciTech Connect

    Harry, R.Y.

    1981-01-01

    As Operator for the Northeast Palawan consortium, Philippines-Cities Service, Inc., commenced the Philippines first commercial offshore oil production from the Nido Reef Complex Oil Field on February 1, 1979, some 11 months after a decision by management to start development. The relative speed at which design, fabrication, and construction were accomplished is attributed to the use of the concepts of project planning, task force approach, and project management. This paper presents the above concepts as applied to the Nido Complex.

  10. Market analysis of shale oil co-products. Appendices

    SciTech Connect

    Not Available

    1980-12-01

    Data are presented in these appendices on the marketing and economic potential for soda ash, aluminia, and nahcolite as by-products of shale oil production. Appendices 1 and 2 contain data on the estimated capital and operating cost of an oil shales/mineral co-products recovery facility. Appendix 3 contains the marketing research data.

  11. Combined process for heavy oil, upgrading and synthetic fuel production

    SciTech Connect

    Polomski, R.E.

    1984-06-05

    A process for upgrading heavy oil to fuel products comprises deasphalting the heavy oil with an oxygenated solvent and simultaneously converting the oxygenated solvent and deasphalted oil over a ZSM-5 type catalyst to produce gasoline and distillate boiling range hydrocarbons.

  12. PERCENT FEDERAL LAND FOR OIL/GAS FIELD OUTLINES

    Energy Information Administration (EIA) (indexed site)

    PERCENT FEDERAL LAND FOR OIL/GAS FIELD OUTLINES The VBA code below calculates the area percent of a first polygon layer (e.g. oil/gas field outlines) that are within a second polygon layer (e.g. federal land) and writes out the fraction as an attribute for the first polygon layer. If you make buffered well field outline polygons using the VBA code in BUFFERED_WELL_FIELD_OUTLINES.doc, you will have a feature class with the attribute PCTFEDLAND to use as the first polygon layer. If not, add the

  13. Top 100 U.S. Oil and Gas Fields

    Energy Information Administration (EIA) (indexed site)

    Natural Gas Glossary › FAQS › Overview Data Summary Prices Exploration & reserves Production Imports/exports Pipelines Storage Consumption All natural gas data reports Analysis & Projections Major Topics Most popular Consumption Exploration & reserves Imports/exports & pipelines Prices Production Projections Recurring Storage All reports Browse by Tag Alphabetical Frequency Tag Cloud Supplement from: U.S. Crude Oil and Natural Gas Proved Reserves Top 100 U.S. Oil and Gas

  14. U.S. Crude Oil Production to 2025: Updated Production of Crude...

    Annual Energy Outlook

    Figure data Previous Issues 5-29-2014 U.S. Crude Oil Production to 2025: Updated Projection of Crude Types Release date: May 28, 2015 Preface U.S. oil production has grown rapidly ...

  15. Oil & Natural Gas Projects Exploration and Production Technologies...

    OpenEI (Open Energy Information) [EERE & EIA]

    & Natural Gas Projects Exploration and Production Technologies Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Oil & Natural Gas Projects Exploration...

  16. Potential Oil Production from the Coastal Plain of the Arctic...

    Energy Information Administration (EIA) (indexed site)

    Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment References Energy Information Administration, Annual Energy Outlook 2000, ...

  17. Potential Oil Production from the Coastal Plain of the Arctic...

    Gasoline and Diesel Fuel Update

    Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment Glossary ANILCA: Alaska National Interest Lands Conservation Act ANS: ...

  18. ,"Crude Oil and Petroleum Products Total Stocks Stocks by Type...

    Energy Information Administration (EIA) (indexed site)

    Name","Description"," Of Series","Frequency","Latest Data for" ,"Data 1","Crude Oil and Petroleum Products Total Stocks Stocks by Type",6,"Monthly","82015","1151956"...

  19. Table 7. Crude oil proved reserves, reserves changes, and production...

    Energy Information Administration (EIA) (indexed site)

    Crude oil proved reserves, reserves changes, and production, 2014" "million barrels" ,,"Changes in Reserves During 2014" ,"Published",,,..."New Reservoir" ,"Proved",,"Revision","...

  20. Impacts of the Venezuelan Crude Oil Production Loss

    Reports and Publications

    2003-01-01

    This assessment of the Venezuelan petroleum loss examines two areas. The first part of the analysis focuses on the impact of the loss of Venezuelan crude production on crude oil supply for U.S. refiners who normally run a significant fraction of Venezuelan crude oil. The second part of the analysis looks at the impact of the Venezuelan production loss on crude markets in general, with particular emphasis on crude oil imports, refinery crude oil throughput levels, stock levels, and the changes in price differences between light and heavy crude oils.

  1. Largest US oil and gas fields, August 1993

    SciTech Connect

    Not Available

    1993-08-06

    The Largest US Oil and Gas Fields is a technical report and part of an Energy Information Administration (EIA) series presenting distributions of US crude oil and natural gas resources, developed using field-level data collected by EIA`s annual survey of oil and gas proved reserves. The series` objective is to provide useful information beyond that routinely presented in the EIA annual report on crude oil and natural gas reserves. These special reports also will provide oil and gas resource analysts with a fuller understanding of the nature of US crude oil and natural gas occurrence, both at the macro level and with respect to the specific subjects addressed. The series` approach is to integrate EIA`s crude oil and natural gas survey data with related data obtained from other authoritative sources, and then to present illustrations and analyses of interest to a broad spectrum of energy information users ranging from the general public to oil and gas industry personnel.

  2. Let's Try That Again: Selling the Teapot Dome Oil Field | Department...

    Office of Environmental Management (EM)

    Let's Try That Again: Selling the Teapot Dome Oil Field Let's Try That Again: Selling the Teapot Dome Oil Field January 30, 2015 - 11:28am Addthis A solitary oil pump at the Teapot ...

  3. Oil and gas field code master list 1994

    SciTech Connect

    Not Available

    1995-01-01

    This is the thirteenth annual edition of the Energy Information Administration`s (EIA) Oil and Gas Field Code Master List. It reflects data collected through October 1994 and provides standardized field name spellings and codes for all identified oil and/or gas fields in the United States. The master field name spellings and codes are to be used by respondents when filing the following Department of Energy (DOE) forms: Form EIA-23, {open_quotes}Annual Survey of Domestic Oil and Gas Reserves,{close_quotes} filed by oil and gas well operators (field codes are required from larger operators only); Forms FERC 8 and EIA-191, {open_quotes}Underground Gas Storage Report,{close_quotes} filed by natural gas producers and distributors who operate underground natural gas storage facilities. Other Federal and State government agencies, as well as industry, use the EIA Oil and Gas Field Code Master List as the standard for field identification. A machine-readable version of the Oil and Gas Field Code Master List is available from the National Technical Information Service, 5285 Port Royal Road, Springfield, Virginia 22161, (703) 487-4650. In order for the Master List to be useful, it must be accurate and remain current. To accomplish this, EIA constantly reviews and revises this list. The EIA welcomes all comments, corrections, and additions to the Master List. All such information should be given to the EIA Field Code Coordinator at (214) 953-1858. EIA gratefully acknowledges the assistance provides by numerous State organizations and trade associations in verifying the existence of fields and their official nomenclature.

  4. Life-Cycle Assessment of Pyrolysis Bio-Oil Production*

    SciTech Connect

    Steele, Philip; Puettmann, Maureen E.; Penmetsa, Venkata Kanthi; Cooper, Jerome E.

    2012-07-01

    As part ofthe Consortium for Research on Renewable Industrial Materials' Phase I life-cycle assessments ofbiofuels, lifecycle inventory burdens from the production of bio-oil were developed and compared with measures for residual fuel oil. Bio-oil feedstock was produced using whole southern pine (Pinus taeda) trees, chipped, and converted into bio-oil by fast pyrolysis. Input parameters and mass and energy balances were derived with Aspen. Mass and energy balances were input to SimaPro to determine the environmental performance of bio-oil compared with residual fuel oil as a heating fuel. Equivalent functional units of 1 MJ were used for demonstrating environmental preference in impact categories, such as fossil fuel use and global warming potential. Results showed near carbon neutrality of the bio-oil. Substituting bio-oil for residual fuel oil, based on the relative carbon emissions of the two fuels, estimated a reduction in CO2 emissions by 0.075 kg CO2 per MJ of fuel combustion or a 70 percent reduction in emission over residual fuel oil. The bio-oil production life-cycle stage consumed 92 percent of the total cradle-to-grave energy requirements, while feedstock collection, preparation, and transportation consumed 4 percent each. This model provides a framework to better understand the major factors affecting greenhouse gas emissions related to bio-oil production and conversion to boiler fuel during fast pyrolysis.

  5. Oil and gas field code master list 1997

    SciTech Connect

    1998-02-01

    The Oil and Gas Field Code Master List 1997 is the sixteenth annual listing of all identified oil and gas fields in the US. It is updated with field information collected through October 1997. The purpose of this publication is to provide unique, standardized codes for identification of domestic fields. Use of these field codes fosters consistency of field identification by government and industry. As a result of their widespread adoption they have in effect become a national standard. The use of field names and codes listed in this publication is required on survey forms and other reports regarding field-specific data collected by EIA. There are 58,366 field records in this year`s FCML, 437 more than last year. The FCML includes: field records for each State and county in which a field resides; field records for each offshore area block in the Gulf of Mexico in which a field resides; field records for each alias field name (definition of alias is listed); fields crossing State boundaries that may be assigned different names by the respective State naming authorities. This report also contains an Invalid Field Record List of 4 records that have been removed from the FCML since last year`s report. These records were found to be either technically incorrect or to represent field names which were never recognized by State naming authorities.

  6. Economic Implementation and Optimization of Secondary Oil Recovery Process: St. Mary West Field, Lafayette County, Arkansas

    SciTech Connect

    Brock P.E., Cary D.

    2003-03-10

    The purpose of this study was to investigate the economic appropriateness of several enhanced oil recovery processes that are available to a small mature oil field located in southwest Arkansas and to implement the most economic efficient process evaluated. The State of Arkansas natural resource laws require that an oilfield is to be unitized before conducting a secondary recovery project. This requires all properties that can reasonably be determined to include the oil productive reservoir must be bound together as one common lease by a legal contract that must be approved to be fair and equitable to all property owners within the proposed unit area.

  7. Update on cavern disposal of NORM-contaminated oil field wastes.

    SciTech Connect

    Veil, J. A.

    1998-09-22

    Some types of oil and gas production and processing wastes contain naturally occurring radioactive material (NORM). If NORM is present at concentrations above regulatory levels in oil field waste, the waste requires special disposal practices. The existing disposal options for wastes containing NORM are limited and costly. Argonne National Laboratory has previously evaluated the feasibility, legality, risk and economics of disposing of nonhazardous oil field wastes, other than NORM waste, in salt caverns. Cavern disposal of nonhazardous oil field waste, other than NORM waste, is occurring at four Texas facilities, in several Canadian facilities, and reportedly in Europe. This paper evaluates the legality, technical feasibility, economics, and human health risk of disposing of NORM-contaminated oil field wastes in salt caverns as well. Cavern disposal of NORM waste is technically feasible and poses a very low human health risk. From a legal perspective, a review of federal regulations and regulations from several states indicated that there are no outright prohibitions against NORM disposal in salt caverns or other Class II wells, except for Louisiana which prohibits disposal of radioactive wastes or other radioactive materials in salt domes. Currently, however, only Texas and New Mexico are working on disposal cavern regulations, and no states have issued permits to allow cavern disposal of NORM waste. On the basis of the costs currently charged for cavern disposal of nonhazardous oil field waste (NOW), NORM waste disposal in caverns is likely to be cost competitive with existing NORM waste disposal methods when regulatory agencies approve the practice.

  8. Prediction of Oil Production With Confidence Intervals*

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    ... spray Target studies for Muon Collider Pellet injection studies for ITER Oil reservoirgroundwater simulation studies 56 Conclusions: Turbulent mixing A ...

  9. Louisiana Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Louisiana Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 1 1 1 5 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  10. Michigan Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Michigan Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 10 2010's 0 8 3 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  11. Mississippi Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Mississippi Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1 2010's 0 1 1 0 2 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  12. Montana Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Montana Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 2 10 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  13. Nebraska Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Nebraska Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 1 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  14. Alabama Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Alabama Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 1 1 0 0 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  15. Alaska Crude Oil + Lease Condensate Reserves New Field Discoveries (Million

    Energy Information Administration (EIA) (indexed site)

    Barrels) New Field Discoveries (Million Barrels) Alaska Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 9 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  16. California Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) California Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 2 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  17. Colorado Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Colorado Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 7 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  18. Wyoming Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Wyoming Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 1 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  19. New Mexico Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) New Mexico Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 1 0 0 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  20. North Dakota Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) North Dakota Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 12 2010's 29 14 9 4 3 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  1. Ohio Crude Oil + Lease Condensate Reserves New Field Discoveries (Million

    Energy Information Administration (EIA) (indexed site)

    Barrels) New Field Discoveries (Million Barrels) Ohio Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 1 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  2. Oklahoma Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Oklahoma Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 1 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field

  3. Texas Crude Oil + Lease Condensate Reserves New Field Discoveries (Million

    Energy Information Administration (EIA) (indexed site)

    Barrels) New Field Discoveries (Million Barrels) Texas Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 11 2010's 78 33 23 3 10 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  4. Kansas Crude Oil + Lease Condensate Reserves New Field Discoveries (Million

    Energy Information Administration (EIA) (indexed site)

    Barrels) New Field Discoveries (Million Barrels) Kansas Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 2 2010's 2 2 1 1 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  5. New information on disposal of oil field wastes in salt caverns

    SciTech Connect

    Veil, J.A.

    1996-10-01

    Solution-mined salt caverns have been used for many years for storing hydrocarbon products. This paper summarizes an Argonne National Laboratory report that reviews the legality, technical suitability, and feasibility of disposing of nonhazardous oil and gas exploration and production wastes in salt caverns. An analysis of regulations indicated that there are no outright regulatory prohibitions on cavern disposal of oil field wastes at either the federal level or in the 11 oil-producing states that were studied. There is no actual field experience on the long-term impacts that might arise following closure of waste disposal caverns. Although research has found that pressures will build-up in a closed cavern, none has specifically addressed caverns filled with oil field wastes. More field research on pressure build-up in closed caverns is needed. On the basis of preliminary investigations, we believe that disposal of oil field wastes in salt caverns is legal and feasible. The technical suitability of the practice depends on whether the caverns are well-sited and well-designed, carefully operated, properly closed, and routinely monitored.

  6. Can nonhazardous oil field wastes be disposed of in salt caverns?

    SciTech Connect

    Veil, J.A.

    1996-10-01

    Solution-mined salt caverns have been used for many years for storing hydrocarbon products. This paper summarizes an Argonne National Laboratory report that reviews the legality, technical suitability, and feasibility of disposing of nonhazardous oil and gas exploration and production wastes in salt caverns. An analysis of regulations indicated that there are no outright regulatory prohibitions on cavern disposal -of oil field wastes at either the federal level or in the 11 oil-producing states that were studied. There is no actual field experience on the long-term impacts that might arise following closure of waste disposal caverns. Although research has found that pressures will build up in a closed cavern, none has specifically addressed caverns filled with oil field wastes. More field research on pressure build up in closed caverns is needed. On the basis of preliminary investigations, we believe that disposal of oil field wastes in salt caverns is legal and feasible. The technical suitability of the practice depends on whether the caverns are well-sited and well-designed, carefully operated, properly closed, and routinely monitored.

  7. Verifying a Simplified Fuel Oil Field Measurement Protocol

    SciTech Connect

    Henderson, Hugh; Dentz, Jordan; Doty, Chris

    2013-07-01

    The Better Buildings program is a U.S. Department of Energy program funding energy efficiency retrofits in buildings nationwide. The program is in need of an inexpensive method for measuring fuel oil consumption that can be used in evaluating the impact that retrofits have in existing properties with oil heat. This project developed and verified a fuel oil flow field measurement protocol that is cost effective and can be performed with little training for use by the Better Buildings program as well as other programs and researchers.

  8. Verifying a Simplified Fuel Oil Flow Field Measurement Protocol

    SciTech Connect

    Henderson, H.; Dentz, J.; Doty, C.

    2013-07-01

    The Better Buildings program is a U.S. Department of Energy program funding energy efficiency retrofits in buildings nationwide. The program is in need of an inexpensive method for measuring fuel oil consumption that can be used in evaluating the impact that retrofits have in existing properties with oil heat. This project developed and verified a fuel oil flow field measurement protocol that is cost effective and can be performed with little training for use by the Better Buildings program as well as other programs and researchers.

  9. Process for stimulating and upgrading the oil production from a heavy oil reservoir

    SciTech Connect

    Sweany, G.A.

    1981-08-18

    A process for thermally stimulating and upgrading oil production from a heavy oil reservoir wherein the heavy oil produced from the reservoir is combined with a hydrogen donor diluent and the mixture is subjected to thermal cracking to upgrade the heavy oil into more valuable hydrocarbon products. The cracked products are fractionated into a light end vapor fraction, an intermediate liquid fraction, a gas oil fraction and a pitch fraction, and at least a portion of the gas oil fraction is hydrogenated by contacting it with a hydrogen-containing gas stream to produce the hydrogen donor diluent combined with the heavy oil. The pitch fraction is subjected to partial oxidation to produce the hydrogen-containing gas stream and a by-product gas stream containing steam which is combined with additional steam and injected into the heavy oil reservoir to enhance the mobility of heavy oil contained therein. The light end vapor fraction and unreacted hydrogen-containing gas produced by the process are utilized as fuel in the process. The intermediate liquid fraction produce and portion of the gas oil fraction not hydrogenated are readily transportable from the process.

  10. A field laboratory for improved oil recovery. Final report

    SciTech Connect

    Hildebrandt, A.F.; McDonald, J.; Claridge, E.; Killough, J.

    1992-09-01

    The purpose of Annex III of the Memorandum of Understanding, undertaken by the Houston Petroleum Research Center at the University of Houston, was to develop a field laboratory for research in improved oil recovery using a Gulf Coast reservoir in Texas. The participants: (1) make a field site selection and conducted a high resolution seismic survey in the demonstration field, (2) obtained characteristics of the reservoir (3) developed an evaluation of local flood efficiency in different parts of the demonstration reservoir, (4) used diverse methodology to evaluate the potential recovery of the remaining oil in the test reservoir, (5) developed cross-well seismic tomography, and (6) will transfer the learned technologies to oil operators through publication and workshops. This abstract is an overview of these tasks.

  11. Dalhart's only Permian field gets best oil well

    SciTech Connect

    Not Available

    1992-07-20

    This paper reports that activity is picking up in Proctor Ranch oil field in the northwestern Texas panhandle, the only Permian producing field in the lightly drilled Dalhart basin. During the last 2 1/2 months, the field has a new operator and a new producing well, the best of five drilled since discovery in 1990. Corlena Oil Co., Amarillo, acquired the field from McKinney Oil Co. in May and tested its first well in early July. The 1-64 Proctor, 18 miles west of Channing, pumped at rates as high as 178 bd of oil and 6 b/d of water from Permian Wolfcamp dolomite perforations at 4,016-29 ft. Corlena plans to drill another well south of the field soon. The lease requires that the next well be spudded by early November. The field appears to be combination structural-stratigraphic trap in which the dolomite pinches out against the Bravo Domes-Oldham nose to the west.

  12. NAFTA opportunities: Oil and gas field drilling machinery and services sector

    SciTech Connect

    Not Available

    1993-01-01

    The North American Free Trade Agreement (NAFTA) significantly improves market access in Mexico and Canada for U.S. exports of oil and gas field equipment. Foreign markets account for more than 80 percent of U.S. shipments of oil and gas field machinery. Foreign markets are expected to continue their importance to this industry, in the long term. Mexico and Canada are moderate-sized markets for U.S. exports of oilfield products. In 1992, U.S. exports of this equipment amounted to about $113 million to Mexico and $11 million to Canada.

  13. Louisiana - South Onshore Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Louisiana - South Onshore Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 1 1 0 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  14. Louisiana State Offshore Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Louisiana State Offshore Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 1 4 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  15. Miscellaneous States Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Miscellaneous States Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 2 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  16. New Mexico - East Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) New Mexico - East Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 1 0 0 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  17. Top 100 U.S. Oil and Gas Fields

    Energy Information Administration (EIA) (indexed site)

    Top 100 U.S. Oil and Gas Fields March 2015 Independent Statistics & Analysis www.eia.gov U.S. Department of Energy Washington, DC 20585 U.S. Energy Information Administration | Top 100 U.S. Oil and Gas Fields i This report was prepared by the U.S. Energy Information Administration (EIA), the statistical and analytical agency within the U.S. Department of Energy. By law, EIA's data, analyses, and forecasts are independent of approval by any other officer or employee of the United States

  18. Application of electrical submersible pumps in heavy crude oil in Boscan Field

    SciTech Connect

    Bortolin, L.L.

    1995-12-31

    During recent years optimization of artificial lift methods has been applied in the oil industry, in order to evaluate the effect on oil well production and to establish a company`s optimal investment policies. Higher costs on new artificial lifting equipment and facilities for new fields have created the necessity to review the latest available technology of different lifting methods and specially that related to electrical submersible pumps (ESP). Few studies in the area of heavy crude oil production optimization using ESP as a lifting method have been published. This paper discusses the results of an ESP pilot project performed in 24 wells in Boscan field, and analyzes the performance of the equipment and its application range. The ESP equipment was installed in completions at depths ranging from 7000 to 9000 feet, with a 10{degrees}API gravity crude and bottomhole temperature of 180{degrees}F. It was concluded that despite a reduction of the pump`s efficiency, the ESP equipment does qualify as a good alternative lifting method for heavy oil production. It is also possible to obtain higher production rates. The results obtained in this pilot project, confirm that submersible pumps are an alternative method for lifting heavy crude oil from relatively deep reservoirs.

  19. IMPROVED APPROACHES TO DESIGN OF POLYMER GEL TREATMENTS IN MATURE OIL FIELDS: FIELD DEMONSTRATION IN DICKMAN FIELD, NESS COUNTY, KANSAS

    SciTech Connect

    Ronald Fowler

    2004-11-30

    This report describes the results of the one-year project entitled ''Improved Approaches to Design of Polymer Gel Treatments in Mature Oil Fields: Field Demonstration in Dickman Field, Ness County, Kansas''. The project was a 12-month collaboration of Grand Mesa Operating Company (a small independent), TIORCO Inc. (a company focused on improved recovery technology) and the University of Kansas. The study undertook tasks to determine an optimum polymer gel treatment design in Mississippian reservoirs, demonstrate application, and evaluate the success of the program. The project investigated geologic and engineering parameters and cost-effective technologies required for design and implementation of effective polymer gel treatment programs in the Mississippian reservoir in the Midcontinent. The majority of Mississippian production in Kansas occurs at or near the top of the Mississippian section just below the regional sub-Pennsylvanian unconformity and karst surface. Dickman Field with the extremely high water cuts and low recovery factors is typical of Mississippian reservoirs. Producibility problems in these reservoirs include inadequate reservoir characterization, drilling and completion design problems, and most significantly extremely high water cuts and low recovery factors that place continued operations at or near their economic limits. Geologic, geophysical and engineering data were integrated to provide a technical foundation for candidate selection and treatment design. Data includes core, engineering data, and 3D seismic data. Based on technical and economic considerations a well was selected for gel-polymer treatment (Grand Mesa Operating Company Tilley No.2). The treatment was not successful due to the small amount of polymer that could be injected. Data from the initial well and other candidates in the demonstration area was analyzed using geologic, geophysical and engineering data. Based on the results of the treatment and the integrated reservoir

  20. Production data reporting and how it aids surveillance in thermal recovery fields

    SciTech Connect

    Dever, R.E.; Womack, F.A.

    1983-03-01

    Modern surveillance requirements in large thermal recovery oil fields overwhelm manual efforts at collection, retrieval, and reporting of operations and production data. The introduction of a customized data base management and reporting system for this purpose can benefit Operations and Engineering through increased production from timelier awareness of field operating conditions, reduced operating expenses, better steam utilization, and significant manpower productivity increases.

  1. Crude Oil and Petroleum Products Movements by Pipeline between PAD

    Energy Information Administration (EIA) (indexed site)

    Districts Product: Crude Oil and Petroleum Products Crude Oil Petroleum Products Pentanes Plus Liquefied Petroleum Gases Ethane/Ethylene Propane/Propylene Isobutane/Isobutylene Normal Butane/Butylene Motor Gasoline Blend. Comp. (MGBC) MGBC - Reformulated MGBC - Reformulated RBOB MGBC - RBOB for Blending w/ Alcohol* MGBC - Conventional MGBC - CBOB MGBC - Conventional GTAB MGBC - Conventional Other Renewable Fuels Renewable Diesel Fuel Finished Motor Gasoline Reformulated Gasoline Conventional

  2. About the Oil and Gas Field Code Master List

    Annual Energy Outlook

    ... Oil and Gas Board of Alabama Alaska Alaska Oil and Gas Conservation Commission Arizona Arizona Oil and Gas Conservation Commission Arkansas Arkansas Oil and Gas Commission ...

  3. Risk assessment of nonhazardous oil-field waste disposal in salt caverns.

    SciTech Connect

    Elcock, D.

    1998-03-10

    Salt caverns can be formed in underground salt formations incidentally as a result of mining or intentionally to create underground chambers for product storage or waste disposal. For more than 50 years, salt caverns have been used to store hydrocarbon products. Recently, concerns over the costs and environmental effects of land disposal and incineration have sparked interest in using salt caverns for waste disposal. Countries using or considering using salt caverns for waste disposal include Canada (oil-production wastes), Mexico (purged sulfates from salt evaporators), Germany (contaminated soils and ashes), the United Kingdom (organic residues), and the Netherlands (brine purification wastes). In the US, industry and the regulatory community are pursuing the use of salt caverns for disposal of oil-field wastes. In 1988, the US Environmental Protection Agency (EPA) issued a regulatory determination exempting wastes generated during oil and gas exploration and production (oil-field wastes) from federal hazardous waste regulations--even though such wastes may contain hazardous constituents. At the same time, EPA urged states to tighten their oil-field waste management regulations. The resulting restrictions have generated industry interest in the use of salt caverns for potentially economical and environmentally safe oil-field waste disposal. Before the practice can be implemented commercially, however, regulators need assurance that disposing of oil-field wastes in salt caverns is technically and legally feasible and that potential health effects associated with the practice are acceptable. In 1996, Argonne National Laboratory (ANL) conducted a preliminary technical and legal evaluation of disposing of nonhazardous oil-field wastes (NOW) into salt caverns. It investigated regulatory issues; the types of oil-field wastes suitable for cavern disposal; cavern design and location considerations; and disposal operations, closure and remediation issues. It determined

  4. Enhanced Microbial Pathways for Methane Production from Oil Shale

    SciTech Connect

    Paul Fallgren

    2009-02-15

    Methane from oil shale can potentially provide a significant contribution to natural gas industry, and it may be possible to increase and continue methane production by artificially enhancing methanogenic activity through the addition of various substrate and nutrient treatments. Western Research Institute in conjunction with Pick & Shovel Inc. and the U.S. Department of Energy conducted microcosm and scaled-up reactor studies to investigate the feasibility and optimization of biogenic methane production from oil shale. The microcosm study involving crushed oil shale showed the highest yield of methane was produced from oil shale pretreated with a basic solution and treated with nutrients. Incubation at 30 C, which is the estimated temperature in the subsurface where the oil shale originated, caused and increase in methane production. The methane production eventually decreased when pH of the system was above 9.00. In the scaled-up reactor study, pretreatment of the oil shale with a basic solution, nutrient enhancements, incubation at 30 C, and maintaining pH at circumneutral levels yielded the highest rate of biogenic methane production. From this study, the annual biogenic methane production rate was determined to be as high as 6042 cu. ft/ton oil shale.

  5. Fact #578: July 6, 2009 World Oil Reserves, Production, and Consumptio...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    8: July 6, 2009 World Oil Reserves, Production, and Consumption, 2007 Fact 578: July 6, 2009 World Oil Reserves, Production, and Consumption, 2007 The United States was ...

  6. New Mexico - West Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  7. Arkansas Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  8. California Federal Offshore Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  9. Pennsylvania Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  10. Texas State Offshore Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  11. Utah Crude Oil + Lease Condensate Reserves New Field Discoveries (Million

    Energy Information Administration (EIA) (indexed site)

    Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  12. Florida Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  13. Illinois Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  14. Indiana Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  15. Kentucky Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  16. Louisiana - North Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  17. Geothermal Testing Facilities in an Oil Field | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Field Geothermal Testing Facilities in an Oil Field Engineered Geothermal Systems, Low Temp, Exploration Demonstration. The proposed project is to develop a long term testing facility and test geothermal power units for the evaluation of electrical power generation from low-temperature and co-produced fluids. The facility will provide the ability to conduct both long and short term testing of different power generation configurations to determine reliability, efficiency and to provide economic

  18. Heavy and Thermal Oil Recovery Production Mechanisms, SUPRI TR-127

    SciTech Connect

    Kovscek, Anthony R.; Brigham, William E.; Castanier, Louis M.

    2001-09-07

    The program spans a spectrum of topics and is divided into five categories: (i) multiphase flow and rock properties, (ii) hot fluid injection, (iii) primary heavy-oil production, (iv) reservoir definition, and (v) in-situ combustion.

  19. Supply and Disposition of Crude Oil and Petroleum Products

    Gasoline and Diesel Fuel Update

    distillate fuel oil with sulfur content 15 ppm and under due to product detail limitations in exports data received from the U.S. Census Bureau. LRG Liquefied Refinery Gas. ...

  20. Development of an In Situ Biosurfactant Production Technology for Enhanced Oil Recovery

    SciTech Connect

    M.J. McInerney; R.M. Knapp; Kathleen Duncan; D.R. Simpson; N. Youssef; N. Ravi; M.J. Folmsbee; T.Fincher; S. Maudgalya; Jim Davis; Sandra Weiland

    2007-09-30

    The long-term economic potential for enhanced oil recovery (EOR) is large with more than 300 billion barrels of oil remaining in domestic reservoirs after conventional technologies reach their economic limit. Actual EOR production in the United States has never been very large, less than 10% of the total U. S. production even though a number of economic incentives have been used to stimulate the development and application of EOR processes. The U.S. DOE Reservoir Data Base contains more than 600 reservoirs with over 12 billion barrels of unrecoverable oil that are potential targets for microbially enhanced oil recovery (MEOR). If MEOR could be successfully applied to reduce the residual oil saturation by 10% in a quarter of these reservoirs, more than 300 million barrels of oil could be added to the U.S. oil reserve. This would stimulate oil production from domestic reservoirs and reduce our nation's dependence on foreign imports. Laboratory studies have shown that detergent-like molecules called biosurfactants, which are produced by microorganisms, are very effective in mobilizing entrapped oil from model test systems. The biosurfactants are effective at very low concentrations. Given the promising laboratory results, it is important to determine the efficacy of using biosurfactants in actual field applications. The goal of this project is to move biosurfactant-mediated oil recovery from laboratory investigations to actual field applications. In order to meet this goal, several important questions must be answered. First, it is critical to know whether biosurfactant-producing microbes are present in oil formations. If they are present, then it will be important to know whether a nutrient regime can be devised to stimulate their growth and activity in the reservoir. If biosurfactant producers are not present, then a suitable strain must be obtained that can be injected into oil reservoirs. We were successful in answering all three questions. The specific objectives

  1. Product Supplied for Total Crude Oil and Petroleum Products

    Gasoline and Diesel Fuel Update

    EthaneEthylene PropanePropylene Normal ButaneButylene IsobutaneIsobutylene Other Liquids HydrogenOxygenatesRenewablesOther Hydrocarbons Unfinished Oils Motor Gasoline Blend. ...

  2. Oil products distribution in Iran: a planning approach

    SciTech Connect

    Abrishami, H.

    1986-01-01

    The significance of this study is that it examines the functions of the most important element in the public sector of the economy of Iran - the Ministry of Oil. Oil is the main source of Iran's foreign earnings and the commodity most crucial to the country's economy as its prime export. Furthermore, it plays a vital role in meeting domestic energy demands. The distribution of oil products affects, on the one hand, households, small businesses, and larger industries while, on the other, it affects the allocation, in general of other national resources. Accordingly, the effects of the Ministry of Oil's policies with regard to its production-distribution system cannot be overemphasized. The research entailed has elicited certain factors: The Ministry of Oil's present system suffers from a number of weaknesses in its production-distribution design. These deficiencies involved, among others, terminal location, number of terminals, assignment of terminals to customers, substitution of other major sources of energy for major oil products, the middle distillates problem, and an outmoded distribution method and techniques. This dissertation addresses alternatives that will eliminate faults in the present system. The approach and conclusions of this research have the potential of application to any type of industry in Iran - oil or otherwise, whether in the private or public sector - that has a similar intricate distribution-system design subject to similar variables.

  3. Vegetable Oil from Leaves and Stems: Vegetative Production of Oil in a C4 Crop

    SciTech Connect

    2012-01-01

    PETRO Project: Arcadia Biosciences, in collaboration with the University of California-Davis, is developing plants that produce vegetable oil in their leaves and stems. Ordinarily, these oils are produced in seeds, but Arcadia Biosciences is turning parts of the plant that are not usually harvested into a source of concentrated energy. Vegetable oil is a concentrated source of energy that plants naturally produce and is easily separated after harvest. Arcadia Biosciences will isolate traits that control oil production in seeds and transfer them into leaves and stems so that all parts of the plants are oil-rich at harvest time. After demonstrating these traits in a fast-growing model plant, Arcadia Biosciences will incorporate them into a variety of dedicated biofuel crops that can be grown on land not typically suited for food production

  4. Special ESP configurations designed to test and produce Yemen oil field. [Electric-Submersible Pump

    SciTech Connect

    Wilkie, D.I. )

    1993-09-27

    Innovative electric-submersible-pump (ESP) configurations were used in the exploration phase of a Yemen oil field discovered by Canadian Occidental Petroleum Ltd. Because of subnormal reservoir pressure, CanOxy developed the field with ESPs and had to install surface components that could operate at the high, 130 F., ambient temperatures common in Yemen. The field is in a remote area that has seen very little development. The reservoirs produce a medium-to-heavy crude with a low gas/oil ratio, typically less than 20 scf/bbl. Problems faced in evaluating the field included drilling through unconsolidated sands with high flow capacity and subnormal reservoir pressure. CanOxy had to develop the technology to test the wells during the exploration phase, and intends to use new, or at least uncommon technology, for producing the wells. The paper describes testing the wells, the electric generators and variable speed drives, and the use of these pumps on production wells.

  5. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. Appendix 1, Volume 1

    SciTech Connect

    Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

    1992-06-01

    This volume contains maps, well logging correlated to porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plot, detailed core log, paragenetic sequence and reservoir characterization sheet of the following fields in southwest Alabama: Appleton oil field; Barnett oil field; Barrytown oil field; Big Escambia Creek gas and condensate field; Blacksher oil field; Broken Leg Creed oil field; Bucatunna Creed oil field; Chappell Hill oil field; Chatom gas and condensate field; Choctaw Ridge oil field; Chunchula gas and condensate field; Cold Creek oil field; Copeland gas and condensate field; Crosbys Creed gas and condensate field; and East Barnett oil field. (AT)

  6. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. [Jurassic Smackover Formation

    SciTech Connect

    Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

    1992-06-01

    This volume contains maps, well logging correlated to porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plot, detailed core log, paragenetic sequence and reservoir characterization sheet of the following fields in southwest Alabama: Appleton oil field; Barnett oil field; Barrytown oil field; Big Escambia Creek gas and condensate field; Blacksher oil field; Broken Leg Creed oil field; Bucatunna Creed oil field; Chappell Hill oil field; Chatom gas and condensate field; Choctaw Ridge oil field; Chunchula gas and condensate field; Cold Creek oil field; Copeland gas and condensate field; Crosbys Creed gas and condensate field; and East Barnett oil field. (AT)

  7. Electric Power Generation from Co-Produced and Other Oil Field...

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Electric Power Generation from Co-Produced and Other Oil Field Fluids Electric Power Generation from Co-Produced and Other Oil Field Fluids Co-produced and low-temperature ...

  8. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. [Jurassic Smackover Formation

    SciTech Connect

    Kopasaka-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D; Hall, D.R.

    1992-06-01

    This volume contains maps, well log correlated to lithology, porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plots; detailed core log, porosity vs. natural permeability plot for one lithofacies, paragenetic sequence and reservoir characterization sheet for the following fields in southwest Alabama: Stave Creek oil field; Sugar Ridge oil field; Toxey oil field, Turkey Creed oil field; Turnerville oil field, Uriah oil field; Vocation oil field; Wallace oil field; Wallers Creek oil field; West Appleton oil field; West Barrytown oil field; West Bend oil field; West Okatuppa Creed oil field; Wild Fork Creek oil field; Wimberly oil field; Womack Hill oil field; and Zion Chapel oil field. (AT)

  9. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. Appendix 1, Volume 4

    SciTech Connect

    Kopasaka-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D; Hall, D.R.

    1992-06-01

    This volume contains maps, well log correlated to lithology, porosity and permeability, structural cross section, graph of production history, porosity vs. natural log permeability plots; detailed core log, porosity vs. natural permeability plot for one lithofacies, paragenetic sequence and reservoir characterization sheet for the following fields in southwest Alabama: Stave Creek oil field; Sugar Ridge oil field; Toxey oil field, Turkey Creed oil field; Turnerville oil field, Uriah oil field; Vocation oil field; Wallace oil field; Wallers Creek oil field; West Appleton oil field; West Barrytown oil field; West Bend oil field; West Okatuppa Creed oil field; Wild Fork Creek oil field; Wimberly oil field; Womack Hill oil field; and Zion Chapel oil field. (AT)

  10. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. [Jurassic Smackover Formation

    SciTech Connect

    Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

    1992-06-01

    This volume contains maps, well logging, structural cross section, graph of production history, porosity vs. natural log permeability plots, detailed core log, paragenetic sequence, and reservoir characterization sheet for the following fields in southwest Alabama: North Smiths Church oil field; North Wallers Creek oil field; Northeast Barnett oil field; Northwest Range oil field; Pace Creek oil field; Palmers Crossroads oil field; Perdido oil field; Puss Cuss Creek oil field; Red Creek gas condensate field; Robinson Creek oil field; Silas oil field; Sizemore Creek gas condensate field; Smiths Church gas condensate field; South Burnt Corn Creek oil field; South Cold Creek oil field; South Vocation oil field; South Wild Fork Creek gas condensate field; South Womack Hill oil field; Southeast Chatom gas condensate field; Southwest Barrytown oil field; and Souwilpa Creek gas condensate field.

  11. Establishment of an oil and gas database for increased recovery and characterization of oil and gas carbonate reservoir heterogeneity. Appendix 1, Volume 3

    SciTech Connect

    Kopaska-Merkel, D.C.; Moore, H.E. Jr.; Mann, S.D.; Hall, D.R.

    1992-06-01

    This volume contains maps, well logging, structural cross section, graph of production history, porosity vs. natural log permeability plots, detailed core log, paragenetic sequence, and reservoir characterization sheet for the following fields in southwest Alabama: North Smiths Church oil field; North Wallers Creek oil field; Northeast Barnett oil field; Northwest Range oil field; Pace Creek oil field; Palmers Crossroads oil field; Perdido oil field; Puss Cuss Creek oil field; Red Creek gas condensate field; Robinson Creek oil field; Silas oil field; Sizemore Creek gas condensate field; Smiths Church gas condensate field; South Burnt Corn Creek oil field; South Cold Creek oil field; South Vocation oil field; South Wild Fork Creek gas condensate field; South Womack Hill oil field; Southeast Chatom gas condensate field; Southwest Barrytown oil field; and Souwilpa Creek gas condensate field.

  12. Expectations for Oil Shale Production (released in AEO2009)

    Reports and Publications

    2009-01-01

    Oil shales are fine-grained sedimentary rocks that contain relatively large amounts of kerogen, which can be converted into liquid and gaseous hydrocarbons (petroleum liquids, natural gas liquids, and methane) by heating the rock, usually in the absence of oxygen, to 650 to 700 degrees Fahrenheit (in situ retorting) or 900 to 950 degrees Fahrenheit (surface retorting). (Oil shale is, strictly speaking, a misnomer in that the rock is not necessarily a shale and contains no crude oil.) The richest U.S. oil shale deposits are located in Northwest Colorado, Northeast Utah, and Southwest Wyoming. Currently, those deposits are the focus of petroleum industry research and potential future production. Among the three states, the richest oil shale deposits are on federal lands in northwest Colorado.

  13. Geological reasons for rapid water encroachment in wells at Sutorma oil field

    SciTech Connect

    Arkhipov, S.V.; Dvorak, S.V.; Sonich, V.P.; Nikolayeva, Ye.V.

    1987-12-01

    The Sutorma oil field on the northern Surgut dome is one of the new fields in West Siberia. It came into production in 1982, but already by 1983 it was found that the water contents in the fluids produced were much greater than the design values. The adverse effects are particularly pronounced for the main reservoir at the deposit, the BS/sub 10//sup 2/ stratum. Later, similar problems occurred at other fields in the Noyarbr and Purpey regions. It is therefore particularly important to elucidate the geological reasons for water encroachment.

  14. U.S. Crude Oil and Petroleum Products Stocks by Type

    Energy Information Administration (EIA) (indexed site)

    Product: Crude Oil and Petroleum Products Crude Oil All Oils (Excluding Crude Oil) Pentanes Plus Liquefied Petroleum Gases Ethane/Ethylene Ethylene Propane/Propylene Propylene (Nonfuel Use) Normal Butane/Butylene Refinery Grade Butane Isobutane/Butylene Other Hydrocarbons Oxygenates (excluding Fuel Ethanol) MTBE Other Oxygenates Renewables (including Fuel Ethanol) Fuel Ethanol Renewable Diesel Fuel Other Renewable Fuels Unfinished Oils Unfinished Oils, Naphthas & Lighter Unfinished Oils,

  15. Peaking of world oil production: Impacts, mitigation, & risk management

    SciTech Connect

    Hirsch, R.L.; Bezdek, Roger; Wendling, Robert

    2005-02-01

    The peaking of world oil production presents the U.S. and the world with an unprecedented risk management problem. As peaking is approached, liquid fuel prices and price volatility will increase dramatically, and, without timely mitigation, the economic, social, and political costs will be unprecedented. Viable mitigation options exist on both the supply and demand sides, but to have substantial impact, they must be initiated more than a decade in advance of peaking.... The purpose of this analysis was to identify the critical issues surrounding the occurrence and mitigation of world oil production peaking. We simplified many of the complexities in an effort to provide a transparent analysis. Nevertheless, our study is neither simple nor brief. We recognize that when oil prices escalate dramatically, there will be demand and economic impacts that will alter our simplified assumptions. Consideration of those feedbacks will be a daunting task but one that should be undertaken. Our aim in this study is to-- • Summarize the difficulties of oil production forecasting; • Identify the fundamentals that show why world oil production peaking is such a unique challenge; • Show why mitigation will take a decade or more of intense effort; • Examine the potential economic effects of oil peaking; • Describe what might be accomplished under three example mitigation scenarios. • Stimulate serious discussion of the problem, suggest more definitive studies, and engender interest in timely action to mitigate its impacts.

  16. The 1-AB block fields-a giant oil accumulation in Eastern Peru

    SciTech Connect

    Jarvis, H.A.; Lay, V. ); Orosco, C. )

    1993-02-01

    The 1-Ab block fields are located in the northeastern part of Peru. Geologically, the area is the sub-Andean Maranon Basin, a continuation of the Napo Basin from eastern Ecuador. During the 20 years that Occidental has operated Block 1-AB, approximately 11,500 km of seismic data has been recorded and 34 exploratory wells have been drilled, resulting in the discovery of 18 fields, or 53% exploration success. The 1-AB oil accumulation discovered in 1972 is a group of medium to small asymmetric anticlines distributed along six northwest-southeast trending structural alignments: North Capahuari-South Capahuari-Tambo, Carmen-North San Jaacinto and Bartra. This concentration of productive structures in a relative small area is unique within the Maranon basin. The controlling factors include exceptional pre-Cretaceous uplifting and the presence of very good to excellent Cretaceous sandstones reservoirs. The two major Cretaceous producing zones, the Chonta and Vivian sandstones, have been defined within the Coniacian and Campanian ages respectively. The Chonta sands are related to shelfal deposition across Block 1-AB, represented by strand plain and barrier island sediments. The Vivian formation is a massive fluvial sandstone covering all of the Maranon basin and ranging in thickness between 40 and 200 feet. After oil was accumulated, fresh water influxes into the reservoirs of the northern and eastern fields caused oil biodegradation and salinity variation of the reservoir waters, depending upon the intensity of biodegradation. Oil remigration also has been documented for the South Huayari field.

  17. Method for creating high carbon content products from biomass oil

    DOEpatents

    Parker, Reginald; Seames, Wayne

    2012-12-18

    In a method for producing high carbon content products from biomass, a biomass oil is added to a cracking reactor vessel. The biomass oil is heated to a temperature ranging from about 100.degree. C. to about 800.degree. C. at a pressure ranging from about vacuum conditions to about 20,700 kPa for a time sufficient to crack the biomass oil. Tar is separated from the cracked biomass oil. The tar is heated to a temperature ranging from about 200.degree. C. to about 1500.degree. C. at a pressure ranging from about vacuum conditions to about 20,700 kPa for a time sufficient to reduce the tar to a high carbon content product containing at least about 50% carbon by weight.

  18. Opportunities to improve oil productivity in unstructured deltaic reservoirs

    SciTech Connect

    Not Available

    1991-01-01

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

  19. Annual Energy Outlook 2014 projects reduced need for U.S. oil imports due to tight oil production growth

    Energy Information Administration (EIA) (indexed site)

    7, 2014 Annual Energy Outlook 2014 projects reduced need for U.S. oil imports due to tight oil production growth U.S. production of tight crude oil is expected to make up a larger share of total U.S. oil output in the years ahead, and help lower imports share of total U.S. oil consumption. In its annual long-term projections, the U.S. Energy Information Administration (EIA) expects total U.S. crude oil production to reach a record 9.6 million barrels per day (bbl/d) in 2019, under its baseline

  20. The drilling of a horizontal well in a mature oil field

    SciTech Connect

    Rougeot, J.E.; Lauterbach, K.A.

    1991-01-01

    This report documents the drilling of a medium radius horizontal well in the Bartlesville Sand of the Flatrock Field, Osage County, Oklahoma by Rougeot Oil and Gas Corporation (Rougeot) of Sperry, Oklahoma. The report includes the rationale for selecting the particular site, the details of drilling the well, the production response, conclusions reached, and recommendations made for the future drilling of horizontal wells. 11 figs., 2 tabs.

  1. Low-Salinity Waterflooding to Improve Oil Recovery - Historical Field Evidence

    SciTech Connect

    Eric P. Robertson

    2007-11-01

    Waterflooding is by far the most widely applied method of improved oil recovery. Crude oil/brine/rock interactions can lead to large variations in the displacement efficiency of wa-terfloods. Laboratory water-flood tests and single-well tracer tests have shown that injection of dilute brine can increase oil recovery, but work designed to test the method on a field scale has not yet been undertaken. Historical waterflood records could unintentionally provide some evidence of improved recovery from waterflooding with lower salinity brine. Nu-merous fields in the Powder River basin of Wyoming have been waterflooded using low salinity brine (about 500 ppm) obtained from the Madison limestone or Fox Hills sandstone. Three Minnelusa formation fields in the basin were identified as potential candidates for waterflood comparisons based on the salinity of the connate and injection water. Historical pro-duction and injection data for these fields were obtained from the public record. Field waterflood data were manipulated to be displayed in the same format as laboratory coreflood re-sults. Recovery from fields using lower salinity injection wa-ter was greater than that using higher salinity injection wa-ter—matching recovery trends for laboratory and single-well tests.

  2. Interactive geological interpretation of the El Roble oil field, eastern Venezuela basin

    SciTech Connect

    Briceno, M.A.; Joffree Arud, G.M. ); Segura, F. ); Rosario Sifontes, A.S.; Bejarano, C. )

    1990-05-01

    The El Noble oil field has been in production since May 1939, following the completion of RPN 1 well in the mid-section of the Oficina Formation. Seventy-three wells, 50% of which are producers, have been drilled as part of evaluation and appraisal-development programs. Production comes mostly from the Tertiary Oficina and Merecure formations, whose cumulative production is 45.2 MMbbl of light and condensate oil, and 74-94 bcf of gas. To date, 158 reservoirs have been identified in more than 40 sand bodies. Over 120 wells have been drilled in the study area which covers the El Roble field and its surroundings. Due to the importance of the field as a supplier to the domestic gas market, Corpoven has decided to reevaluate the area through an integrated study which takes into account all available data, including lab and sedimentological analyses, petrophysical analyses, well logs, etc., all of which have been processed through the Intergraph Gipsie system. The Intergraph Gipsie system allows the handling of data and the generation of ecological maps, sections, and graphs in a relatively short time using interactive routines, freeing the geologist for interpretations. More than 40 sand beds were reevaluated and their oil and gas volumes estimated. Further corrections and updating should be easily handled through the system.

  3. Power Plays: Geothermal Energy In Oil and Gas Fields | Department of Energy

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Power Plays: Geothermal Energy In Oil and Gas Fields Power Plays: Geothermal Energy In Oil and Gas Fields The SMU Geothermal Lab is hosting their 7th international energy conference and workshop Power Plays: Geothermal Energy in Oil and Gas Fields May 18-20, 2015 on the SMU Campus in Dallas, Texas. The two-day conference brings together leaders from the geothermal, oil and gas communities along with experts in finance, law, technology, and government agencies to discuss generating electricity

  4. Past, Present, and Future Production of Bio-oil

    SciTech Connect

    Steele, Philip; Yu, Fei; Gajjela, Sanjeev

    2009-04-01

    Bio-oil is a liquid product produced by fast pyrol-ysis of biomass. The fast pyrolysis is performed by heating the biomass rapidly (2 sec) at temperatures ranging from 350 to 650 oC. The vapors produced by this rapid heating are then condensed to produce a dark brown water-based emulsion composed of frag-ments of the original hemicellulose, cellulose and lignin molecules contained in the biomass. Yields range from 60 to 75% based on the feedstock type and the pyrolysis reactor employed. The bio-oil pro-duced by this process has a number of negative prop-erties that are produced mainly by the high oxygen content (40 to 50%) contributed by that contained in water (25 to 30% of total mass) and oxygenated compounds. Each bio-oil contains hundreds of chemi-cal compounds. The chemical composition of bio-oil renders it a very recalcitrant chemical compound. To date, the difficulties in utilizing bio-oil have limited its commercial development to the production of liq-uid smoke as food flavoring. Practitioners have at-tempted to utilize raw bio-oil as a fuel; they have also applied many techniques to upgrade bio-oil to a fuel. Attempts to utilize raw bio-oil as a combustion engine fuel have resulted in engine or turbine dam-age; however, Stirling engines have been shown to successfully combust raw bio-oil without damage. Utilization of raw bio-oil as a boiler fuel has met with more success and an ASTM standard has recently been released describing bio-oil characteristics in relation to assigned fuel grades. However, commercialization has been slow to follow and no reports of distribution of these bio-oil boiler fuels have been reported. Co-feeding raw bio-oil with coal has been successfully performed but no current power generation facilities are following this practice. Upgrading of bio-oils to hydrocarbons via hydroprocessing is being performed by several organizations. Currently, limited catalyst life is the obstacle to commercialization of this tech-nology. Researchers

  5. Oil gravity distribution in the diatomite at South Belridge Field, Kern County, CA: Implications for oil sourcing and migration

    SciTech Connect

    Hill, D.W.; Sande, J.J.; Doe, P.H.

    1995-04-01

    Understanding oil gravity distribution in the Belridge Diatomite has led to economic infill development and specific enhanced recovery methods for targeted oil properties. To date more than 100 wells have provided samples used to determining vertical and areal distribution of oil gravity in the field. Detailed geochemical analyses were also conducted on many of the oil samples to establish different oil types, relative maturities, and to identify transformed oils. The geochemical analysis also helped identify source rock expulsion temperatures and depositional environments. The data suggests that the Belridge diatomite has been charged by a single hydrocarbon source rock type and was generated over a relatively wide range of temperatures. Map and statistical data support two distinct oil segregation processes occurring post expulsion. Normal gravity segregation within depositional cycles of diatomite have caused lightest oils to migrate to the crests of individual cycle structures. Some data suggests a loss of the light end oils in the uppermost cycles to the Tulare Formation above, or through early biodegradation. Structural rotation post early oil expulsion has also left older, heavier oils concentrated on the east flank of the structure. With the addition of other samples from the south central San Joaquin area, we have been able to tie the Belridge diatomite hydrocarbon charge into a regional framework. We have also enhanced our ability to predict oil gravity and well primary recovery by unraveling some key components of the diatomite oil source and migration history.

  6. Disposal of NORM-contaminated oil field wastes in salt caverns -- Legality, technical feasibility, economics, and risk

    SciTech Connect

    Veil, J.A.; Smith, K.P.; Tomasko, D.; Elcock, D.; Blunt, D.; Williams, G.P.

    1998-07-01

    Some types of oil and gas production and processing wastes contain naturally occurring radioactive materials (NORM). If NORM is present at concentrations above regulatory levels in oil field waste, the waste requires special disposal practices. The existing disposal options for wastes containing NORM are limited and costly. This paper evaluates the legality, technical feasibility, economics, and human health risk of disposing of NORM-contaminated oil field wastes in salt caverns. Cavern disposal of NORM waste is technically feasible and poses a very low human health risk. From a legal perspective, there are no fatal flaws that would prevent a state regulatory agency from approaching cavern disposal of NORM. On the basis of the costs charged by caverns currently used for disposal of nonhazardous oil field waste (NOW), NORM waste disposal caverns could be cost competitive with existing NORM waste disposal methods when regulatory agencies approve the practice.

  7. Louisiana Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Louisiana Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 68 2010's 66 68 70 71 69 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  8. Michigan Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Michigan Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 6 2010's 6 6 7 7 8 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  9. Miscellaneous States Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Miscellaneous States Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 2 2010's 2 2 3 3 2 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus

  10. Mississippi Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Mississippi Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 24 2010's 24 24 28 24 25 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  11. Montana Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Montana Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 29 2010's 25 24 27 30 30 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  12. Nebraska Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Nebraska Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 2 2010's 2 3 3 3 3 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  13. New Mexico - East Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) New Mexico - East Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 58 2010's 63 70 83 98 117 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil

  14. New Mexico - West Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) New Mexico - West Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 2 2010's 2 2 3 4 7 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus

  15. Alabama Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Alabama Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 7 2010's 7 8 10 10 9 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  16. Alaska Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Alaska Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 210 2010's 195 206 191 186 182 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  17. Arkansas Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Arkansas Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 6 2010's 5 6 6 4 6 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  18. California Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) California Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 208 2010's 198 196 198 199 203 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  19. Colorado Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Colorado Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 30 2010's 33 41 52 70 102 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  20. Wyoming Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Wyoming Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 51 2010's 53 55 57 64 75 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  1. New Mexico Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) New Mexico Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 60 2010's 65 72 86 102 124 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  2. North Dakota Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) North Dakota Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 84 2010's 114 152 251 314 394 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil

  3. Ohio Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Ohio Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 4 2010's 5 4 5 7 14 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  4. Oklahoma Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Oklahoma Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 63 2010's 63 79 85 113 132 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  5. Pennsylvania Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Pennsylvania Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 2 2010's 3 3 5 6 7 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  6. Texas Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 401 2010's 460 534 742 931 1,160 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  7. Texas State Offshore Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas State Offshore Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1 2010's 1 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus

  8. Utah Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Utah Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 23 2010's 25 27 31 36 43 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  9. West Virginia Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) West Virginia Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1 2010's 1 2 3 7 9 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  10. Florida Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Florida Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1 2010's 2 2 3 2 4 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  11. Illinois Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Illinois Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 5 2010's 4 4 4 3 2 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  12. Indiana Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Indiana Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1 2010's 1 1 1 1 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  13. Kansas Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Kansas Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 40 2010's 41 41 43 46 48 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  14. Kentucky Crude Oil + Lease Condensate Estimated Production from Reserves

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Estimated Production from Reserves (Million Barrels) Kentucky Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 2 2010's 1 1 1 1 1 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  15. Louisiana - North Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Louisiana - North Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 11 2010's 10 11 12 13 13 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil

  16. Environmental Compliance for Oil and Gas Exploration and Production

    SciTech Connect

    Hansen, Christine

    1999-10-26

    The Appalachian/Illinois Basin Directors is a group devoted to increasing communication among the state oil and gas regulatory agencies within the Appalachian and Illinois Basin producing region. The group is comprised of representatives from the oil and gas regulatory agencies from states in the basin (Attachment A). The directors met to discuss regulatory issues common to the area, organize workshops and seminars to meet the training needs of agencies dealing with the uniqueness of their producing region and perform other business pertinent to this area of oil and gas producing states. The emphasis of the coordinated work was a wide range of topics related to environmental compliance for natural gas and oil exploration and production.

  17. Water Management in Mature Oil Fields using Advanced Particle Gels

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    Water Management in Mature Oil Fields using Advanced Particle Gels Final Report Contract no.: 11123-32 Jan. 15, 2016  Prime Contractor: The University of Texas at Austin  Participant: Missouri University of Science and Technology Contacts: - Mojdeh Delshad, 512-471-3219, delshad@mail.utexas.edu Baojun Bai, 573-341-4016, baib@mst.edu Research Partnership to Secure Energy for America (RPSEA) Project Manager: John R. Terneus Start Date: January 18, 2013 End Date: January 17, 2015 2 Table of

  18. Fact #652: December 6, 2010 U.S. Crude Oil Production Rises | Department of

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Energy 2: December 6, 2010 U.S. Crude Oil Production Rises Fact #652: December 6, 2010 U.S. Crude Oil Production Rises The production of crude oil in the U.S., including lease condensates, rose in 2009 for the first time since 1991. The general trend of declining oil production began in 1986 after a slight peak in 1985 of 8.97 million barrels per day. In 2008, the lowest point in the series, oil production was only 4.95 million barrels per day. The highest U.S. crude oil production was forty

  19. Low-rank coal oil agglomeration product and process

    DOEpatents

    Knudson, Curtis L.; Timpe, Ronald C.; Potas, Todd A.; DeWall, Raymond A.; Musich, Mark A.

    1992-01-01

    A selectively-sized, raw, low-rank coal is processed to produce a low ash and relative water-free agglomerate with an enhanced heating value and a hardness sufficient to produce a non-decrepitating, shippable fuel. The low-rank coal is treated, under high shear conditions, in the first stage to cause ash reduction and subsequent surface modification which is necessary to facilitate agglomerate formation. In the second stage the treated low-rank coal is contacted with bridging and binding oils under low shear conditions to produce agglomerates of selected size. The bridging and binding oils may be coal or petroleum derived. The process incorporates a thermal deoiling step whereby the bridging oil may be completely or partially recovered from the agglomerate; whereas, partial recovery of the bridging oil functions to leave as an agglomerate binder, the heavy constituents of the bridging oil. The recovered oil is suitable for recycling to the agglomeration step or can serve as a value-added product.

  20. Low-rank coal oil agglomeration product and process

    DOEpatents

    Knudson, C.L.; Timpe, R.C.; Potas, T.A.; DeWall, R.A.; Musich, M.A.

    1992-11-10

    A selectively-sized, raw, low-rank coal is processed to produce a low ash and relative water-free agglomerate with an enhanced heating value and a hardness sufficient to produce a non-degradable, shippable fuel. The low-rank coal is treated, under high shear conditions, in the first stage to cause ash reduction and subsequent surface modification which is necessary to facilitate agglomerate formation. In the second stage the treated low-rank coal is contacted with bridging and binding oils under low shear conditions to produce agglomerates of selected size. The bridging and binding oils may be coal or petroleum derived. The process incorporates a thermal deoiling step whereby the bridging oil may be completely or partially recovered from the agglomerate; whereas, partial recovery of the bridging oil functions to leave as an agglomerate binder, the heavy constituents of the bridging oil. The recovered oil is suitable for recycling to the agglomeration step or can serve as a value-added product.

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

    SciTech Connect

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

    2002-02-28

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

  2. Total Crude Oil and Petroleum Products Imports by Processing Area

    Gasoline and Diesel Fuel Update

    Supplement from: U.S. Crude Oil and Natural Gas Proved Reserves Top 100 U.S. Oil and Gas Fields With Data for 2013 | Release Date: April 2, 2015 | Next Release Date: January 2016 Previous Issues (pdf): Year: 2009 2008 2007 (Appendix B) 2006 (Appendix B) 2005 (Appendix B) 2004 (Appendix B) 2003 (Appendix B) 2002 (Appendix B) 2001 (Appendix B) 2000 (Appendix B) 1999 (Appendix B) 1998 (Appendix B) 1997 (Appendix B) 1996 (Appendix B) Go Introduction This supplement to the U.S. Energy Information

  3. A theoretical model of subsidence caused by petroleum production: Big Hill Field, Jefferson County, Texas

    SciTech Connect

    Hill, D.W.; Sharp, J.M. Jr. . Dept. of Geological Sciences)

    1993-02-01

    In the Texas Gulf Coastal Plain, there is a history of oil and gas production extending over 2 to 5 decades. Concurrent with this production history, there has been unprecedented population growth accompanied by vastly increased groundwater demands. Land subsidence on both local and regional bases in this geologic province has been measured and predicted in several studies. The vast majority of these studies have addressed the problem from the standpoint of groundwater usage while only a few have considered the effects of oil and gas production. Based upon field-based computational techniques (Helm, 1984), a model has been developed to predict land subsidence caused by oil and gas production. This method is applied to the Big Hill Field in Jefferson County, Texas. Inputs include production data from a series of wells in this field and lithologic data from electric logs of these same wells. Outputs include predicted amounts of subsidence, the time frame of subsidence, and sensitivity analyses of compressibility and hydraulic conductivity estimates. Depending upon estimated compressibility, subsidence, to date, is predicted to be as high as 20 cm. Similarly, depending upon estimated vertical hydraulic conductivity, the time frame may be decades for this subsidence. These same methods can be applied to other oil/gas fields with established production histories as well as new fields when production scenarios are assumed. Where subsidence has been carefully measured above petroleum reservoir, the model may be used inversely to calculate sediment compressibilities.

  4. Enhanced oil recovery by CO/sub 2/ miscible displacement in the Little Knife Field, Billings County, North Dakota

    SciTech Connect

    Desch, J.B.; Larsen, W.K.; Lindsay, R.F.; Nettle, R.L.

    1982-01-01

    Gulf Oil Exploration and Production Company, in conjunction with the Department of Energy, has successfully conducted a field test of the CO/sub 2/ miscible displacement process in the Little Knife Field. All project objectives were conceived, implemented, and accomplished as a result of the synergetic cooperation and communication between the various departments within Gulf Oil Corporation and the DOE. The minitest succeeded in establishing water-flood residual-oil saturations. It also succeeded in reducing the waterflood residual-oil saturation to a lower value by CO/sub 2//water injection. Finally, and most importantly, the minitest was successfully characterized, developed, and monitored. Monitoring was accomplished by cased-hole logging, fluid sampling, and simulation modeling. 9 refs.

  5. Risk analyses for disposing nonhazardous oil field wastes in salt caverns

    SciTech Connect

    Tomasko, D.; Elcock, D.; Veil, J.; Caudle, D.

    1997-12-01

    Salt caverns have been used for several decades to store various hydrocarbon products. In the past few years, four facilities in the US have been permitted to dispose nonhazardous oil field wastes in salt caverns. Several other disposal caverns have been permitted in Canada and Europe. This report evaluates the possibility that adverse human health effects could result from exposure to contaminants released from the caverns in domal salt formations used for nonhazardous oil field waste disposal. The evaluation assumes normal operations but considers the possibility of leaks in cavern seals and cavern walls during the post-closure phase of operation. In this assessment, several steps were followed to identify possible human health risks. At the broadest level, these steps include identifying a reasonable set of contaminants of possible concern, identifying how humans could be exposed to these contaminants, assessing the toxicities of these contaminants, estimating their intakes, and characterizing their associated human health risks. The contaminants of concern for the assessment are benzene, cadmium, arsenic, and chromium. These were selected as being components of oil field waste and having a likelihood to remain in solution for a long enough time to reach a human receptor.

  6. Natural Gas Production and U.S. Oil Imports | Department of Energy

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    Natural Gas Production and U.S. Oil Imports Natural Gas Production and U.S. Oil Imports January 26, 2012 - 11:14am Addthis Matthew Loveless Matthew Loveless Data Integration ...

  7. U.S. oil production expected to decline over next year, rebounding...

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    9, 2015 U.S. oil production expected to decline over next year, rebounding in late 2016 U.S. monthly crude oil production is expected to decline through the middle of next year in ...

  8. U.S. net oil and petroleum product imports expected to fall to...

    Gasoline and Diesel Fuel Update

    of demand in 2014 With rising domestic crude oil production, the United States will rely less on imports of crude oil and petroleum products to meet domestic demand next year. ...

  9. Chemically bonded phosphate ceramic sealant formulations for oil field applications

    DOEpatents

    Wagh, Arun S.; Jeong, Seung-Young; McDaniel, Richard

    2008-10-21

    A sealant for an oil or geothermal well capable of setting within about 3 to about 6 hours at temperatures less than about 250.degree. F. for shallow wells less than about 10,000 feet and deep wells greater than about 10,000 feet having MgO present in the range of from about 9.9 to about 14.5%, KH.sub.2PO.sub.4 present in the range of from about 29.7 to about 27.2%, class C fly ash present in the range of from about 19.8 to about 36.3%, class F fly ash present in the range of from about 19.8 to about 0%, boric acid or borax present in the range of from about 0.39 to about 1.45%, and water present in the range of from about 20.3 to about 21.86% by weight of the sealant.A method of sealing wells is disclosed as are compositions for very high temperature wells is disclosed as is a composition for treating oil field wastes.

  10. Fact #780: May 20, 2013 Crude Oil Reserve to Production Ratio | Department

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    of Energy 0: May 20, 2013 Crude Oil Reserve to Production Ratio Fact #780: May 20, 2013 Crude Oil Reserve to Production Ratio The ratio of reserves to production gives a relative measure of the resources available in different oil producing countries. Assuming 2011 crude oil production rates and holding reserves constant, the reserves in Venezuela would last another 258 years, while Canada's reserves would last 165 years and the United States reserves would last 11 years. Saudi Arabia, which

  11. Accelerated Depletion: Assessing Its Impacts on Domestic Oil and Natural Gas Prices and Production

    Reports and Publications

    2000-01-01

    Analysis of the potential impacts of accelerated depletion on domestic oil and natural gas prices and production.

  12. Examination of eastern oil shale disposal problems - the Hope Creek field study

    SciTech Connect

    Koppenaal, D.W.; Kruspe, R.R.; Robl, T.L.; Cisler, K.; Allen, D.L.

    1985-02-01

    A field-based study of problems associated with the disposal of processed Eastern oil shale was initiated in mid-1983 at a private research site in Montgomery County, Kentucky. The study (known as the Hope Creek Spent Oil Shale Disposal Project) is designed to provide information on the geotechnical, revegetation/reclamation, and leachate generation and composition characteristics of processed Kentucky oil shales. The study utilizes processed oil shale materials (retorted oil shale and reject raw oil shale fines) obtained from a pilot plant run of Kentucky oil shale using the travelling grate retort technology. Approximately 1000 tons of processed oil shale were returned to Kentucky for the purpose of the study. The study, composed of three components, is described. The effort to date has concentrated on site preparation and the construction and implementation of the field study research facilities. These endeavors are described and the project direction in the future years is defined.

  13. Charm production in a strong magnetic field

    SciTech Connect

    Machado, C. S.; Navarra, F. S.; Noronha, J.; Oliveira, E. G. de; Strickland, M.

    2014-11-11

    We discuss the effects of a strong magnetic field on B and D mesons, focusing on the changes of the energy levels and the masses of the bound states. Using the Color Evaporation Model we discuss the possible changes in the production of J/? and ?. We briefly comment the recent experimental data.

  14. Production of valuable hydrocarbons by flash pyrolysis of oil shale

    DOEpatents

    Steinberg, M.; Fallon, P.T.

    1985-04-01

    A process for the production of gas and liquid hydrocarbons from particulated oil shale by reaction with a pyrolysis gas at a temperature of from about 700/sup 0/C to about 1100/sup 0/C, at a pressure of from about 400 psi to about 600 psi, for a period of about 0.2 second to about 20 seconds. Such a pyrolysis gas includes methane, helium, or hydrogen. 3 figs., 3 tabs.

  15. Oil and gas production equals jobs and revenue

    SciTech Connect

    Aimes, L.A.

    1994-12-31

    The effects of oil and gas production on jobs and revenue are discussed. Some suggestions are presented that should provide the climate to increase jobs, add revenue and increase efficiency in state agencies within the producing states. Some of the ideas and suggestions are summarized. Some of these ideas include: how to extend the economic limits of marginal properties; how the states can encourage additional drilling without incurring loss of revenue; and the use of investment tax credits.

  16. Field Testing of Pre-Production Prototype Residential Heat Pump...

    Energy Saver

    Field Testing of Pre-Production Prototype Residential Heat Pump Water Heaters Field Testing of Pre-Production Prototype Residential Heat Pump Water Heaters Provides and overview of ...

  17. U.S. Crude Oil + Lease Condensate Estimated Production from Reserves...

    Energy Information Administration (EIA) (indexed site)

    Estimated Production from Reserves (Million Barrels) U.S. Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 ...

  18. Electric Power Generation from Co-Produced and Other Oil Field Fluids |

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Department of Energy Electric Power Generation from Co-Produced and Other Oil Field Fluids Electric Power Generation from Co-Produced and Other Oil Field Fluids Co-produced and low-temperature demonstration projects presentation at the 2013 peer review meeting held in Denver, Colorado. coproduced_demoprojects_peerreview2013.pdf (2.47 MB) More Documents & Publications Chena Hot Springs Resort - Electric Power Generation Using Geothermal Fluid Coproduced from Oil and/or Gas Wells

  19. Fact #578: July 6, 2009 World Oil Reserves, Production, and Consumption,

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    2007 | Department of Energy 8: July 6, 2009 World Oil Reserves, Production, and Consumption, 2007 Fact #578: July 6, 2009 World Oil Reserves, Production, and Consumption, 2007 The United States was responsible for 8% of the world's petroleum production, held 2% of the world's crude oil reserves, and consumed 24% of the world's petroleum consumption in 2007. The Organization for Petroleum Exporting Countries (OPEC) held 69% of the world's crude oil reserves and produced 41% of world

  20. Louisiana - South Onshore Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Louisiana - South Onshore Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 48 2010's 47 47 47 47 46 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  1. Louisiana State Offshore Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Louisiana State Offshore Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 9 2010's 9 10 11 11 10 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages:

  2. Lower 48 States Crude Oil + Lease Condensate Estimated Production from

    Energy Information Administration (EIA) (indexed site)

    Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Lower 48 States Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1,719 2010's 1,796 1,859 2,195 2,543 3,018 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  3. Engineered microbes and methods for microbial oil production

    DOEpatents

    Stephanopoulos, Gregory; Tai, Mitchell; Chakraborty, Sagar

    2015-02-10

    Some aspects of this invention provide engineered microbes for oil production. Methods for microbe engineering and for use of engineered microbes are also provided herein. In some embodiments, microbes are provided that are engineered to modulate a combination of rate-controlling steps of lipid synthesis, for example, a combination of a step generating metabolites, acetyl-CoA, ATP or NADPH for lipid synthesis (a push step), and a step sequestering a product or an intermediate of a lipid synthesis pathway that mediates feedback inhibition of lipid synthesis (a pull step). Such push-and-pull engineered microbes exhibit greatly enhanced conversion yields and TAG synthesis and storage properties.

  4. California State Offshore Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) California State Offshore Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 14 2010's 13 12 13 14 14 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  5. Texas - RRC District 1 Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas - RRC District 1 Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 10 2010's 15 44 112 192 263 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  6. Texas - RRC District 10 Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas - RRC District 10 Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 16 2010's 22 30 40 43 40 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages:

  7. Texas - RRC District 5 Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas - RRC District 5 Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 3 2010's 3 4 5 6 6 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude

  8. Texas - RRC District 6 Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas - RRC District 6 Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 18 2010's 18 18 19 19 20 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages:

  9. Texas - RRC District 8 Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas - RRC District 8 Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 121 2010's 158 156 205 228 283 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring

  10. Texas - RRC District 9 Crude Oil + Lease Condensate Estimated Production

    Energy Information Administration (EIA) (indexed site)

    from Reserves (Million Barrels) Estimated Production from Reserves (Million Barrels) Texas - RRC District 9 Crude Oil + Lease Condensate Estimated Production from Reserves (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 15 2010's 17 21 22 21 21 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages:

  11. Potential Oil Production from the Coastal Plain of the Arctic National

    Energy Information Administration (EIA) (indexed site)

    Wildlife Refuge: Updated Assessment Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment Preface Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment is a product of the Energy Information Administration’s (EIA) Reserves and Production Division. EIA, under various programs, has assessed foreign and domestic oil and gas resources, reserves, and production potential. As a policy-neutral

  12. Coupling the Alkaline-Surfactant-Polymer Technology and The Gelation Technology to Maximize Oil Production

    SciTech Connect

    Malcolm Pitts; Jie Qi; Dan Wilson; Phil Dowling; David Stewart; Bill Jones

    2005-12-01

    Performance and produced polymer evaluation of four alkaline-surfactant-polymer projects concluded that only one of the projects could have benefited from combining the alkaline-surfactant-polymer and gelation technologies. Cambridge, the 1993 Daqing, Mellott Ranch, and the Wardlaw alkaline-surfacant-polymer floods were studied. An initial gel treatment followed by an alkaline-surfactant-polymer flood in the Wardlaw field would have been a benefit due to reduction of fracture flow. Numerical simulation demonstrated that reducing the permeability of a high permeability zone of a reservoir with gel improved both waterflood and alkaline-surfactant-polymer flood oil recovery. A Minnelusa reservoir with both A and B sand production was simulated. A and B sands are separated by a shale layer. A sand and B sand waterflood oil recovery was improved by 196,000 bbls or 3.3% OOIP when a gel was placed in the B sand. Alkaline-surfactant-polymer flood oil recovery improvement over a waterflood was 392,000 bbls or 6.5% OOIP. Placing a gel into the B sand prior to an alkaline-surfactant-polymer flood resulted in 989,000 bbl or 16.4% OOIP more oil than only water injection. A sand and B sand alkaline-surfactant-polymer flood oil recovery was improved by 596,000 bbls or 9.9% OOIP when a gel was placed in the B sand.

  13. Computer simulation of nonstationary thermal fields in design and operation of northern oil and gas fields

    SciTech Connect

    Vaganova, N. A.; Filimonov, M. Yu.

    2015-11-30

    A mathematical model, numerical algorithm and program code for simulation and long-term forecasting of changes in permafrost as a result of operation of a multiple well pad of northern oil and gas field are presented. In the model the most significant climatic and physical factors are taken into account such as solar radiation, determined by specific geographical location, heterogeneous structure of frozen soil, thermal stabilization of soil, possible insulation of the objects, seasonal fluctuations in air temperature, and freezing and thawing of the upper soil layer. Results of computing are presented.

  14. Declines in U.S. monthly oil production expected to continue

    Energy Information Administration (EIA) (indexed site)

    Declines in U.S. monthly oil production expected to continue U.S. monthly oil production continues to decline in response to the drop in oil prices that began almost two years ago. In its new monthly forecast, the U.S. Energy Information Administration said domestic oil production averaged 8.7 million barrels per day in May falling below the daily output level of 9 million barrels for the first time since September 2014. May's 250,000 barrel-per-day decrease in oil production would be the

  15. U.S. oil production forecast update reflects lower rig count

    Energy Information Administration (EIA) (indexed site)

    U.S. oil production forecast update reflects lower rig count Lower oil prices and fewer rigs drilling for crude oil are expected to slow U.S. oil production growth this year and in 2016. U.S. crude oil production is still expected to average 9.2 million barrels per day this year. That's up half a million barrels per day from last year and the highest output level in more than four decades. A substantial part of the year-over-year increase reflects rapid production growth throughout 2014.

  16. Implications of Increasing Light Tight Oil Production for U.S. Refining -

    Energy Information Administration (EIA) (indexed site)

    Energy Information Administration Implications of Increasing Light Tight Oil Production for U.S. Refining Release date: May 5, 2015 Revised: May 12, 2015 (revision) 1. Background and Analytical Framework Background Recent and projected increases in U.S. crude production have sparked discussion about the implications of current limitations on crude oil exports for prices, including both world and domestic crude oil and petroleum product prices, and for the level of domestic crude production

  17. Natural Oil Production from Microorganisms: Bioprocess and Microbe Engineering for Total Carbon Utilization in Biofuel Production

    SciTech Connect

    2010-07-15

    Electrofuels Project: MIT is using carbon dioxide (CO2) and hydrogen generated from electricity to produce natural oils that can be upgraded to hydrocarbon fuels. MIT has designed a 2-stage biofuel production system. In the first stage, hydrogen and CO2 are fed to a microorganism capable of converting these feedstocks to a 2-carbon compound called acetate. In the second stage, acetate is delivered to a different microorganism that can use the acetate to grow and produce oil. The oil can be removed from the reactor tank and chemically converted to various hydrocarbons. The electricity for the process could be supplied from novel means currently in development, or more proven methods such as the combustion of municipal waste, which would also generate the required CO2 and enhance the overall efficiency of MIT’s biofuel-production system.

  18. Table 5. Domestic Crude Oil Production, Projected vs. Actual

    Energy Information Administration (EIA) (indexed site)

    Domestic Crude Oil Production, Projected vs. Actual" "Projected" " (million barrels)" ,1993,1994,1995,1996,1997,1998,1999,2000,2001,2002,2003,2004,2005,2006,2007,2008,2009,2010,2011,2012,2013 "AEO 1994",2507.55,2372.5,2255.7,2160.8,2087.8,2022.1,1952.75,1890.7,1850.55,1825,1799.45,1781.2,1766.6,1759.3,1777.55,1788.5,1806.75,1861.5 "AEO

  19. Table 5. Domestic Crude Oil Production, Projected vs. Actual

    Energy Information Administration (EIA) (indexed site)

    Domestic Crude Oil Production, Projected vs. Actual Projected (million barrels) 1993 1994 1995 1996 1997 1998 1999 2000 2001 2002 2003 2004 2005 2006 2007 2008 2009 2010 2011 2012 2013 AEO 1994 2508 2373 2256 2161 2088 2022 1953 1891 1851 1825 1799 1781 1767 1759 1778 1789 1807 1862 AEO 1995 2402 2307 2205 2095 2037 1967 1953 1924 1916 1905 1894 1883 1887 1887 1920 1945 1967 AEO 1996 2387 2310 2248 2172 2113 2062 2011 1978 1953 1938 1916 1920 1927 1949 1971 1986 2000 2018 2055 AEO 1997 2362 2307

  20. The impact of CO{sub 2} taxation on oil and gas production in Norway

    SciTech Connect

    Celius, H.K.; Ingeberg, K.

    1996-12-31

    This paper analyses the effect of the CO{sub 2} tax which was imposed on the burning of gas in the Norwegian sector of the North Sea, effective in 1991. The introduction of the tax resulted in a number of technical improvements aimed at the reduction of flaring, and increased energy efficiency of the power generation and total production process. An economic analysis was done to establish the following: (1) How did the tax affect the profitability of the technical measures which were implemented did the tax make it profitable, or would it have been profitable without the tax; (2) can we expect improvements to continue in the coming years; and (3) what will be the impact on the development of new fields, on field abandonment and on measures to improve oil recovery how much more oil will be left in the reservoir because of the tax. The first task was analyzed by an empirical approach, the latter based on models. The reduction in CO{sub 2} discharge during 1990-1993 was in the order of 8%, the main contribution came from reduction in flaring. This rate of improvement is not expected to continue, since most processes have been brought up to {open_quotes}state-of-the-art{close_quotes} by during these initial years. However, continuous energy optimization is still expected to give some improvements The majority of the technical measures taken to reduce the CO{sub 2} discharge proved to be profitable without the tax, and no unprofitable measures were implemented. The effect of earlier abandonment of fields is smaller than expected, advancing the abandonment by a few weeks for a typical North Sea field. The same seems to be the case for development of new fields. The additional reserves needed to compensate for the tax is in the order of 3 - 4% for a medium GOR oil field, above 5% for a larger gas field.

  1. GEOGRAPHIC INFORMATION SYSTEM APPROACH FOR PLAY PORTFOLIOS TO IMPROVE OIL PRODUCTION IN THE ILLINOIS BASIN

    SciTech Connect

    Beverly Seyler; John Grube

    2004-12-10

    Oil and gas have been commercially produced in Illinois for over 100 years. Existing commercial production is from more than fifty-two named pay horizons in Paleozoic rocks ranging in age from Middle Ordovician to Pennsylvanian. Over 3.2 billion barrels of oil have been produced. Recent calculations indicate that remaining mobile resources in the Illinois Basin may be on the order of several billion barrels. Thus, large quantities of oil, potentially recoverable using current technology, remain in Illinois oil fields despite a century of development. Many opportunities for increased production may have been missed due to complex development histories, multiple stacked pays, and commingled production which makes thorough exploitation of pays and the application of secondary or improved/enhanced recovery strategies difficult. Access to data, and the techniques required to evaluate and manage large amounts of diverse data are major barriers to increased production of critical reserves in the Illinois Basin. These constraints are being alleviated by the development of a database access system using a Geographic Information System (GIS) approach for evaluation and identification of underdeveloped pays. The Illinois State Geological Survey has developed a methodology that is being used by industry to identify underdeveloped areas (UDAs) in and around petroleum reservoirs in Illinois using a GIS approach. This project utilizes a statewide oil and gas Oracle{reg_sign} database to develop a series of Oil and Gas Base Maps with well location symbols that are color-coded by producing horizon. Producing horizons are displayed as layers and can be selected as separate or combined layers that can be turned on and off. Map views can be customized to serve individual needs and page size maps can be printed. A core analysis database with over 168,000 entries has been compiled and assimilated into the ISGS Enterprise Oracle database. Maps of wells with core data have been generated

  2. Costs for off-site disposal of nonhazardous oil field wastes: Salt caverns versus other disposal methods

    SciTech Connect

    Veil, J.A.

    1997-09-01

    According to an American Petroleum Institute production waste survey reported on by P.G. Wakim in 1987 and 1988, the exploration and production segment of the US oil and gas industry generated more than 360 million barrels (bbl) of drilling wastes, more than 20 billion bbl of produced water, and nearly 12 million bbl of associated wastes in 1985. Current exploration and production activities are believed to be generating comparable quantities of these oil field wastes. Wakim estimates that 28% of drilling wastes, less than 2% of produced water, and 52% of associated wastes are disposed of in off-site commercial facilities. In recent years, interest in disposing of oil field wastes in solution-mined salt caverns has been growing. This report provides information on the availability of commercial disposal companies in oil-and gas-producing states, the treatment and disposal methods they employ, and the amounts they charge. It also compares cavern disposal costs with the costs of other forms of waste disposal.

  3. Production of higher quality bio-oils by in-line esterification of pyrolysis vapor

    SciTech Connect

    Hilten, Roger Norris; Das, Keshav; Kastner, James R; Bibens, Brian P

    2014-12-02

    The disclosure encompasses in-line reactive condensation processes via vapor phase esterification of bio-oil to decease reactive species concentration and water content in the oily phase of a two-phase oil, thereby increasing storage stability and heating value. Esterification of the bio-oil vapor occurs via the vapor phase contact and subsequent reaction of organic acids with ethanol during condensation results in the production of water and esters. The pyrolysis oil product can have an increased ester content and an increased stability when compared to a condensed pyrolysis oil product not treated with an atomized alcohol.

  4. Habitat of oil in the Lindsborg field, Salina basin, north-central Kansas

    SciTech Connect

    Newell, K.D. )

    1991-03-01

    The Lindsborg field was discovered in 1938, and is now 14 mi in length and 1-2 mi in width. It has a projected ultimate recovery of 16 MMBO. Three pay zones (5-20 ft thick) produce in the field. The Simpson pay zone (Middle Ordovician) is a well-rounded, quartzitic sandstone that is interpreted to be a paralic, high-energy shelf deposit. The Viola pay (Middle Ordovician) appears to be a dolomitic, lime grainstone but no cores are available to confirm this. The uppermost pay zone, the Upper Ordovician Maquoketa, is a finely laminated, vuggy, cherry dolomite interpreted to have been deposited as a subtidal lime mudstone in a restricted lagoon. The Simpson and Viola pays are structurally trapped in culminations along the crest of the Lindsborg anticline. Although the Maquoketa pay is structurally trapped with the other pay zones in the southern half of the field, its locus of production in the north half of the fields extends 100 ft vertically down the western flank of the anticline. The trapping mechanism is unclear due to lack of core control and modern logging suites, but it may be subtle updip diagenetic change from vuggy to nonvuggy dolomite. The Simpson and Maquoketa oils are geochemically distinct. Both may reflect efficient local source-to-reservoir migration from originally rich but marginally mature Ordovician and Devonian shales that contact each pay zone. If oil in the Lindsborg field is locally generated, the prospectivity of the relatively unproductive and underexplored Salina basin may be enhanced.

  5. World oil and gas resources-future production realities

    SciTech Connect

    Masters, C.D.; Root, D.H.; Attanasi, E.D. )

    1990-01-01

    Welcome to uncertainty was the phrase Jack Schanz used to introduce both layman and professionals to the maze of petroleum energy data that must be comprehended to achieve understanding of this critical commodity. Schanz was referring to the variables as he and his colleagues with Resources for the Future saw them in those years soon after the energy-awakening oil embargo of 1973. In some respects, the authors have made progress in removing uncertainty from energy data, but in general, we simply must accept that there are many points of view and many ways for the blindman to describe the elephant. There can be definitive listing of all uncertainties, but for this paper the authors try to underscore those traits of petroleum occurrence and supply that the author's believe bear most heavily on the understanding of production and resource availability. Because oil and gas exist in nature under such variable conditions and because the products themselves are variable in their properties, the authors must first recognize classification divisions of the resource substances, so that the reader might always have a clear perception of just what we are talking about and how it relates to other components of the commodity in question.

  6. Increased Oil Production and Reserves Utilizing Secondary/Terriary Recovery Techniques on Small Reservoirs in the Paradox Basin, Utah

    SciTech Connect

    David E. Eby; Thomas C. Chidsey, Jr.

    1998-04-08

    The primary objective of this project is to enhance domestic petroleum production by demonstration and technology transfer of an advanced oil recovery technology in the Paradox basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to about 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million barrels of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon dioxide-(CO -) 2 flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place in the Paradox basin within the Navajo Nation. Two activities continued this quarter as part of the geological and reservoir characterization of productive carbonate buildups in the Paradox basin: (1) diagenetic characterization of project field reservoirs, and (2) technology transfer.

  7. State taxation on the production of crude oil: a comparison of nine states

    SciTech Connect

    Archibald, S.

    1981-06-01

    The purpose of this study is to compare the level of taxation on the production of oil in California to that which currently exists in other major oil-producing states. Two hypothetical oil corporations are constructed, then state and local taxes imposed on these corporations in nine major oil-producing states, including California, are compared and, in addition, a combined state and local tax rate levied on crude oil production in each of these states is determined. The states selected represent nine of the fifteen most oil-productive states in the United States today. The states used in the study ranked in terms of annual oil production are: Texas, Alaska, Louisiana, California, Wyoming, New Mexico, North Dakota, and Montana. (DMC)

  8. East Coast (PADD 1) Total Crude Oil and Petroleum Products Net Receipts by

    Energy Information Administration (EIA) (indexed site)

    Pipeline, Tanker, Barge and Rail Product: Total Crude Oil and Products Crude Oil Petroleum Products Pentanes Plus Liquefied Petroleum Gases Ethane/Ethylene Propane/Propylene Normal Butane/Butylene Isobutane/Isobutylene Unfinished Oils Motor Gasoline Blend. Comp. (MGBC) MGBC - Reformulated MGBC - Reformulated RBOB MGBC - RBOB for Blending w/ Alcohol* MGBC - RBOB for Blending w/ Ether* MGBC - Reformulated GTAB* MGBC - Conventional MGBC - CBOB MGBC - Conventional GTAB MGBC - Conventional Other

  9. Integration of the geological/engineering model with production performance for Patrick Draw Field, Wyoming

    SciTech Connect

    Jackson, S.

    1993-03-01

    The NIPER Reservoir Assessment and Characterization Research Program incorporates elements of the near-term, mid-term and long-term objectives of the National Energy Strategy-Advanced Oil Recovery Program. The interdisciplinary NIPER team focuses on barrier island reservoirs, a high priority class of reservoirs, that contains large amounts of remaining oil in place located in mature fields with a high number of shut-in and abandoned wells. The project objectives are to: (1) identify heterogeneities that influence the movement and trapping of reservoir fluids in two examples of shoreline barrier reservoirs (Patrick Draw Field, WY and Bell Creek Field, MT); (2) develop geological and engineering reservoir characterization methods to quantify reservoir architecture and predict mobile oil saturation distribution for application of targeted infill drilling and enhanced oil recovery (EOR) processes; and (3) summarize reservoir and production characteristics of shoreline barrier reservoirs to determine similarities and differences. The major findings of the research include: (1) hydrogeochemical analytical techniques were demonstrated to be an inexpensive reservoir characterization tool that provides information on reservoir architecture and compartmentalization; (2) the formation water salinity in Patrick Draw Field varies widely across the field and can result in a 5 to 12% error in saturation values calculated from wireline logs if the salinity variations and corresponding resistivity values are not accounted for; and (3) an analysis of the enhanced oil recovery (EOR) potential of Patrick Draw Field indicates that CO[sub 2] flooding in the Monell Unit and horizontal drilling in the Arch Unit are potential methods to recover additional oil from the field.

  10. Integration of the geological/engineering model with production performance for Patrick Draw Field, Wyoming

    SciTech Connect

    Jackson, S.

    1993-03-01

    The NIPER Reservoir Assessment and Characterization Research Program incorporates elements of the near-term, mid-term and long-term objectives of the National Energy Strategy-Advanced Oil Recovery Program. The interdisciplinary NIPER team focuses on barrier island reservoirs, a high priority class of reservoirs, that contains large amounts of remaining oil in place located in mature fields with a high number of shut-in and abandoned wells. The project objectives are to: (1) identify heterogeneities that influence the movement and trapping of reservoir fluids in two examples of shoreline barrier reservoirs (Patrick Draw Field, WY and Bell Creek Field, MT); (2) develop geological and engineering reservoir characterization methods to quantify reservoir architecture and predict mobile oil saturation distribution for application of targeted infill drilling and enhanced oil recovery (EOR) processes; and (3) summarize reservoir and production characteristics of shoreline barrier reservoirs to determine similarities and differences. The major findings of the research include: (1) hydrogeochemical analytical techniques were demonstrated to be an inexpensive reservoir characterization tool that provides information on reservoir architecture and compartmentalization; (2) the formation water salinity in Patrick Draw Field varies widely across the field and can result in a 5 to 12% error in saturation values calculated from wireline logs if the salinity variations and corresponding resistivity values are not accounted for; and (3) an analysis of the enhanced oil recovery (EOR) potential of Patrick Draw Field indicates that CO{sub 2} flooding in the Monell Unit and horizontal drilling in the Arch Unit are potential methods to recover additional oil from the field.

  11. Recovery of Fresh Water Resources from Desalination of Brine Produced During Oil and Gas Production Operations

    SciTech Connect

    David B. Burnett; Mustafa Siddiqui

    2006-12-29

    Management and disposal of produced water is one of the most important problems associated with oil and gas (O&G) production. O&G production operations generate large volumes of brine water along with the petroleum resource. Currently, produced water is treated as a waste and is not available for any beneficial purposes for the communities where oil and gas is produced. Produced water contains different contaminants that must be removed before it can be used for any beneficial surface applications. Arid areas like west Texas produce large amount of oil, but, at the same time, have a shortage of potable water. A multidisciplinary team headed by researchers from Texas A&M University has spent more than six years is developing advanced membrane filtration processes for treating oil field produced brines The government-industry cooperative joint venture has been managed by the Global Petroleum Research Institute (GPRI). The goal of the project has been to demonstrate that treatment of oil field waste water for re-use will reduce water handling costs by 50% or greater. Our work has included (1) integrating advanced materials into existing prototype units and (2) operating short and long-term field testing with full size process trains. Testing at A&M has allowed us to upgrade our existing units with improved pre-treatment oil removal techniques and new oil tolerant RO membranes. We have also been able to perform extended testing in 'field laboratories' to gather much needed extended run time data on filter salt rejection efficiency and plugging characteristics of the process train. The Program Report describes work to evaluate the technical and economical feasibility of treating produced water with a combination of different separation processes to obtain water of agricultural water quality standards. Experiments were done for the pretreatment of produced water using a new liquid-liquid centrifuge, organoclay and microfiltration and ultrafiltration membranes for the

  12. Hydrocarbon Liquid Production via the bioCRACK Process and Catalytic Hydroprocessing of the Product Oil

    SciTech Connect

    Schwaiger, Nikolaus; Elliott, Douglas C.; Ritzberger, Jurgen; Wang, Huamin; Pucher, Peter; Siebenhofer, Matthaus

    2015-02-13

    Continuous hydroprocessing of liquid phase pyrolysis bio-oil, provided by BDI-BioEnergy International bioCRACK pilot plant at OMV Refinery in Schwechat/Vienna Austria was investigated. These hydroprocessing tests showed promising results using catalytic hydroprocessing strategies developed for unfractionated bio-oil. A sulfided base metal catalyst (CoMo on Al2O3) was evaluated. The bed of catalyst was operated at 400 °C in a continuous-flow reactor at a pressure of 12.1 MPa with flowing hydrogen. The condensed liquid products were analyzed and found that the hydrocarbon liquid was significantly hydrotreated so that nitrogen and sulfur were below the level of detection (<0.05), while the residual oxygen ranged from 0.7 to 1.2%. The density of the products varied from 0.71 g/mL up to 0.79 g/mL with a correlated change of the hydrogen to carbon atomic ratio from 2.1 down to 1.9. The product quality remained high throughout the extended tests suggesting minimal loss of catalyst activity through the test. These tests provided the data needed to assess the quality of liquid fuel products obtained from the bioCRACK process as well as the activity of the catalyst for comparison with products obtained from hydrotreated fast pyrolysis bio-oils from fluidized-bed operation.

  13. Hydrocarbon Liquid Production via the bioCRACK Process and Catalytic Hydroprocessing of the Product Oil

    DOE PAGES [OSTI]

    Schwaiger, Nikolaus; Elliott, Douglas C.; Ritzberger, Jurgen; Wang, Huamin; Pucher, Peter; Siebenhofer, Matthaus

    2015-02-13

    Continuous hydroprocessing of liquid phase pyrolysis bio-oil, provided by BDI-BioEnergy International bioCRACK pilot plant at OMV Refinery in Schwechat/Vienna Austria was investigated. These hydroprocessing tests showed promising results using catalytic hydroprocessing strategies developed for unfractionated bio-oil. A sulfided base metal catalyst (CoMo on Al2O3) was evaluated. The bed of catalyst was operated at 400 °C in a continuous-flow reactor at a pressure of 12.1 MPa with flowing hydrogen. The condensed liquid products were analyzed and found that the hydrocarbon liquid was significantly hydrotreated so that nitrogen and sulfur were below the level of detection (<0.05), while the residual oxygen rangedmore » from 0.7 to 1.2%. The density of the products varied from 0.71 g/mL up to 0.79 g/mL with a correlated change of the hydrogen to carbon atomic ratio from 2.1 down to 1.9. The product quality remained high throughout the extended tests suggesting minimal loss of catalyst activity through the test. These tests provided the data needed to assess the quality of liquid fuel products obtained from the bioCRACK process as well as the activity of the catalyst for comparison with products obtained from hydrotreated fast pyrolysis bio-oils from fluidized-bed operation.« less

  14. Impact of Tropical Cyclones on Gulf of Mexico Crude Oil and Natural Gas Production, The

    Reports and Publications

    2006-01-01

    This is a special analysis report on hurricanes and their effects on oil and natural gas production in the Gulf of Mexico region.

  15. Fact #758: December 17, 2012 U.S. Production of Crude Oil by State, 2011 |

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Department of Energy 8: December 17, 2012 U.S. Production of Crude Oil by State, 2011 Fact #758: December 17, 2012 U.S. Production of Crude Oil by State, 2011 Texas is by far the State that produces the most crude oil in the U.S., but 30 other States also produced oil in 2011. Alaska, California, North Dakota, and Oklahoma were next in the top five crude oil producing States. Eighteen States generated less than 20 million barrels, but altogether, those 18 States produced nearly 57 million

  16. Field performance of a laser fluorosensor for the detection of oil spills

    SciTech Connect

    O'Neil, R.A.; Buja-Bijunas, L.; Rayner, D.M.

    1980-03-15

    An airborne laser fluorosensor is described that was designed to detect and identify targets by means of the characteristic fluorescence emission spectrum. The first field trials of the sensor over marine oil and dye spills are reported. A correlation technique has been developed that, when applied to the data collected during these field trials, clearly differentiated among dye, the two crude oils, and the general fluorescence background of ocean water.

  17. A review of the Arun field gas production/cycling and LNG export project. [Sumatra, Indonesia

    SciTech Connect

    Alford, M.E.

    1983-03-01

    The Arun field was discovered by Mobil Oil Indonesia Inc. in late 1971 in its Bee block in the Aceh province on the north coast of Sumatra, Indonesia. Mobil's operations in this area are conducted under the terms of a production sharing agreement with Pertamina, the Indonesian state-owned oil and gas enterprise. The scope of operations covered by this paper is from production of gas and raw condensate in the field through stabilization and export of condensate and purification, liquefaction, and export of gas at the LNG plant at Blang Lancang, near Lho Seumawe (Sumatra) Indonesia. Mobil Oil Indonesia, Inc. is the field operator and P.T. Arun NGL Company operates the pipelines and LNG plant facilities. All the facilities which will be described are owned by Pertamina; P.T. Arun is owned by Pertamina, Mobil Oil Indonesia, and Japan Indonesia LNG company (JILCO). JILCO represents the five (5) original Japanese LNG purchasers. Brief descriptions are included of the geology, reservoir geometry, well producing characteristics, field producing and cycling facilities, and the treating, liquefaction and export facilities.

  18. World oil trends

    SciTech Connect

    Anderson, A. )

    1991-01-01

    This book provides data on many facets of the world oil industry topics include; oil consumption; oils share of energy consumption; crude oil production; natural gas production; oil reserves; prices of oil; world refining capacity; and oil tankers.

  19. Alaska Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Reservoir Discoveries in Old Fields Alaska Crude Oil

  20. On-farm production of soybean oil and its properties as a fuel

    SciTech Connect

    Suh, S.R.

    1983-01-01

    This study presents the design of a system for on-farm production of soybean oil for use as a fuel in compression ignition engines. The soybean oil production system consists of a heat exchanger to heat the beans with the exhaust gas of an engine, a screw press and a system for water degumming and drying the expressed crude oil. Optimum parameters of the oil production system were found. The rheological properties of soybean oil, ester of soybean oil and blends of the above with diesel fuel and diesel fuel additives are given. Data on soybean temperature, outlet gas temperature and thermal efficiency were obtained from a developed mathematical model of the heat exchanger. Chemical analyses show that crude oil from the press is similar to that of commercially degummed oil. The degumming process is not needed for the crude oil to be used as a fuel in compression ignition engines. Rheological properties of the soybean oil and soybean oil diesel fuel mixture show that the fluids have viscosities of time independent characteristics and are Newtonian fluids. Diesel fuel additives having low viscosities can be used to lower the viscosity of soybean oil and blends with diesel fuel but the effect is insignificant.

  1. INCREASED OIL PRODUCTION AND RESERVES UTILIZING SECONDARY/TERTIARY RECOVERY TECHNIQUES ON SMALL RESERVOIRS IN THE PARADOX BASIN, UTAH

    SciTech Connect

    Thomas C. Chidsey, Jr.

    2002-11-01

    The Paradox Basin of Utah, Colorado, and Arizona contains nearly 100 small oil fields producing from shallow-shelf carbonate buildups or mounds within the Desert Creek zone of the Pennsylvanian (Desmoinesian) Paradox Formation. These fields typically have one to four wells with primary production ranging from 700,000 to 2,000,000 barrels (111,300-318,000 m{sup 3}) of oil per field at a 15 to 20 percent recovery rate. Five fields in southeastern Utah were evaluated for waterflood or carbon-dioxide (CO{sub 2})-miscible flood projects based upon geological characterization and reservoir modeling. Geological characterization on a local scale focused on reservoir heterogeneity, quality, and lateral continuity as well as possible compartmentalization within each of the five project fields. The Desert Creek zone includes three generalized facies belts: (1) open-marine, (2) shallow-shelf and shelf-margin, and (3) intra-shelf, salinity-restricted facies. These deposits have modern analogs near the coasts of the Bahamas, Florida, and Australia, respectively, and outcrop analogs along the San Juan River of southeastern Utah. The analogs display reservoir heterogeneity, flow barriers and baffles, and lithofacies geometry observed in the fields; thus, these properties were incorporated in the reservoir simulation models. Productive carbonate buildups consist of three types: (1) phylloid algal, (2) coralline algal, and (3) bryozoan. Phylloid-algal buildups have a mound-core interval and a supra-mound interval. Hydrocarbons are stratigraphically trapped in porous and permeable lithotypes within the mound-core intervals of the lower part of the buildups and the more heterogeneous supramound intervals. To adequately represent the observed spatial heterogeneities in reservoir properties, the phylloid-algal bafflestones of the mound-core interval and the dolomites of the overlying supra-mound interval were subdivided into ten architecturally distinct lithotypes, each of which

  2. RESERVOIR CHARACTERIZATION OF UPPER DEVONIAN GORDON SANDSTONE, JACKSONBURG STRINGTOWN OIL FIELD, NORTHWESTERN WEST VIRGINIA

    SciTech Connect

    S. Ameri; K. Aminian; K.L. Avary; H.I. Bilgesu; M.E. Hohn; R.R. McDowell; D.L. Matchen

    2001-07-01

    The Jacksonburg-Stringtown oil field contained an estimated 88,500,000 barrels of oil in place, of which approximately 20,000,000 barrels were produced during primary recovery operations. A gas injection project, initiated in 1934, and a pilot waterflood, begun in 1981, yielded additional production from limited portions of the field. The pilot was successful enough to warrant development of a full-scale waterflood in 1990, involving approximately 8,900 acres in three units, with a target of 1,500 barrels of oil per acre recovery. Historical patterns of drilling and development within the field suggests that the Gordon reservoir is heterogeneous, and that detailed reservoir characterization is necessary for understanding well performance and addressing problems observed by the operators. The purpose of this work is to establish relationships among permeability, geophysical and other data by integrating geologic, geophysical and engineering data into an interdisciplinary quantification of reservoir heterogeneity as it relates to production. Conventional stratigraphic correlation and core description shows that the Gordon sandstone is composed of three parasequences, formed along the Late Devonian shoreline of the Appalachian Basin. The parasequences comprise five lithofacies, of which one includes reservoir sandstones. Pay sandstones were found to have permeabilities in core ranging from 10 to 200 mD, whereas non-pay sandstones have permeabilities ranging from below the level of instrumental detection to 5 mD; Conglomeratic zones could take on the permeability characteristics of enclosing materials, or could exhibit extremely low values in pay sandstone and high values in non-pay or low permeability pay sandstone. Four electrofacies based on a linear combination of density and scaled gamma ray best matched correlations made independently based on visual comparison of geophysical logs. Electrofacies 4 with relatively high permeability (mean value > 45 mD) was

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

    SciTech Connect

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

    1999-04-05

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

  4. Analysis of Crude Oil Production in the Arctic National Wildlife...

    Energy Information Administration (EIA) (indexed site)

    ... Background Federal law currently prohibits oil and natural gas development in ANWR. ANWR is located on the northern coast of Alaska due east of both Prudhoe Bay, the largest oil ...

  5. Venezuelan oil

    SciTech Connect

    Martinez, A.R. )

    1989-01-01

    Oil reserves have been known to exist in Venezuela since early historical records, however, it was not until the 20th century that the extensive search for new reserves began. The 1950's marked the height of oil exploration when 200 new oil fields were discovered, as well as over 60{percent} of proven reserves. Venezuela now produces one tone in seven of crude oil consumption and the country's abundant reserves such as the Bolivar Coastal field in the West of the country and the Orinoco Belt field in the East, will ensure it's continuing importance as an oil producer well into the 21st century. This book charts the historical development of Venezuela oil and provides a chronology of all the significant events which have shaped the oil industry of today. It covers all the technical, legal, economic and political factors which have contributed to the evolution of the industry and also gives information on current oil resources and production. Those events significant to the development of the industry, those which were influential in shaping future policy and those which precipitated further action are included. The book provides a source of reference to oil companies, oil economists and petroleum geologists.

  6. U.S. crude oil production expected to top 9 million barrels per day in December

    Energy Information Administration (EIA) (indexed site)

    crude oil production expected to top 9 million barrels per day in December U.S. crude oil production is expected to continue to increase through next year, despite the outlook for lower crude oil prices. In its new short-term forecast, the U.S. Energy Information Administration said monthly average oil production is on track to surpass 9 million barrels per day in December for the first time since 1986 and then rise to an average 9.4 million barrels a day next year. Even though that's down about

  7. U.S. crude oil production in July was the highest in more than two decades

    Energy Information Administration (EIA) (indexed site)

    crude oil production in July was the highest in more than two decades U.S. crude oil production in July reached 7.5 million barrels per day.....the highest output for any month since 1991.....according to the U.S. Energy Information Administration. EIA's new monthly forecast expects average crude oil production next year will climb to 8.2 million barrels per day....about 800,000 barrels per day higher than this year. Drilling for oil in tight rock formations is expected to account for most of

  8. Assessment of Alaska's North Slope Oil Field Capacity to Sequester CO{sub 2}

    SciTech Connect

    Umekwe, Pascal; Mongrain, Joanna; Ahmadi, Mohabbat; Hanks, Catherine

    2013-03-15

    The capacity of 21 major fields containing more than 95% of the North Slope of Alaska's oil were investigated for CO{sub 2} storage by injecting CO{sub 2} as an enhanced oil recovery (EOR) agent. These fields meet the criteria for the application of miscible and immiscible CO{sub 2}-EOR methods and contain about 40 billion barrels of oil after primary and secondary recovery. Volumetric calculations from this study indicate that these fields have a static storage capacity of 3 billion metric tons of CO{sub 2}, assuming 100% oil recovery, re-pressurizing the fields to pre-fracturing pressure and applying a 50% capacity reduction to compensate for heterogeneity and for water invasion from the underlying aquifer. A ranking produced from this study, mainly controlled by field size and fracture gradient, identifies Prudhoe, Kuparuk, and West Sak as possessing the largest storage capacities under a 20% safety factor on pressures applied during storage to avoid over-pressurization, fracturing, and gas leakage. Simulation studies were conducted using CO{sub 2} Prophet to determine the amount of oil technically recoverable and CO{sub 2} gas storage possible during this process. Fields were categorized as miscible, partially miscible, and immiscible based on the miscibility of CO{sub 2} with their oil. Seven sample fields were selected across these categories for simulation studies comparing pure CO{sub 2} and water-alternating-gas injection. Results showed that the top two fields in each category for recovery and CO{sub 2} storage were Alpine and Point McIntyre (miscible), Prudhoe and Kuparuk (partially miscible), and West Sak and Lisburne (immiscible). The study concludes that 5 billion metric tons of CO{sub 2} can be stored while recovering 14.2 billion barrels of the remaining oil.

  9. EIA - Analysis of Crude Oil Production in the Arctic National Wildlife

    Energy Information Administration (EIA) (indexed site)

    Refuge - Results Results Analysis of Crude Oil Production in the Arctic National Wildlife Refuge Figure 2. Domestic Crude Oil Production for the AEO2008 Reference Case and the Three ANWR Resource Cases, 2005-2030. (million barrels per day). Need help, contact the National Energy Information Center at 202-586-8800. table 2. Liquid Fuels Supply Impact of Opening ANWR 1002 Area to Petroleum Development under three Oil Resource Cases. Need help, contact the National Energy Informtion Center at

  10. Anaerobic thermophilic bacteria isolated from a Venezuelan oil field and its potential use in microbial improved oil recovery

    SciTech Connect

    Trebbau, G.; Fernandez, B.; Marin, A.

    1995-12-31

    The objective of this work is to determine the ability of indigenous bacteria from a Venezuelan oil field to grow under reservoir conditions inside a porous media, and to produce metabolites capable of recovering residual crude oil. For this purpose, samples of formation waters from a central-eastern Venezuelan oil reservoir were enriched with different carbon sources and a mineral basal media. Formation water was used as a source of trace metals. The enrichments obtained were incubated at reservoir temperature (71{degrees}C), reservoir pressure (1,200 psi), and under anaerobic conditions for both outside and inside porous media (Berea core). Growth and metabolic activity was followed outside porous media by measuring absorbance at 660 nm, increases in pressure, and decreases in pH. Inside porous media bacterial activity was determined by visual examination of the produced waters (gas bubbles and bacterial cells). All the carbohydrates tested outside porous media showed good growth at reservoir conditions. The pH was lowered, gases such as CO{sub 2} and CH{sub 4} were identified by GC. Surface tension was lowered in some enrichments by 30% when compared to controls. Growth was decreased inside porous media, but gases were produced and helped displace oil. In addition, 10% residual oil was recovered from the Berea core. Mathematical modeling was applied to the laboratory coreflood experiment to evaluate the reproducibility of the results obtained.

  11. Crude oil and alternate energy production forecasts for the twenty-first century: The end of the hydrocarbon era

    SciTech Connect

    Edwards, J.D.

    1997-08-01

    Predictions of production rates and ultimate recovery of crude oil are needed for intelligent planning and timely action to ensure the continuous flow of energy required by the world`s increasing population and expanding economies. Crude oil will be able to supply increasing demand until peak world production is reached. The energy gap caused by declining conventional oil production must then be filled by expanding production of coal, heavy oil and oil shales, nuclear and hydroelectric power, and renewable energy sources (solar, wind, and geothermal). Declining oil production forecasts are based on current estimated ultimate recoverable conventional crude oil resources of 329 billion barrels for the United States and close to 3 trillion barrels for the world. Peak world crude oil production is forecast to occur in 2020 at 90 million barrels per day. Conventional crude oil production in the United States is forecast to terminate by about 2090, and world production will be close to exhaustion by 2100.

  12. Increased Oil Production and Reserves Utilizing Secondary/Tertiary Recovery Techniques on Small Reservoirs in the Paradox Basin, Utah

    SciTech Connect

    Chidsey Jr., Thomas C.

    2003-02-06

    The primary objective of this project was to enhance domestic petroleum production by field demonstration and technology transfer of an advanced-oil-recovery technology in the Paradox Basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to approximately 100 additional small fields in the Paradox Basin alone, and result in increased recovery of 150 to 200 million barrels (23,850,000-31,800,000 m3) of oil. This project was designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon-dioxide-(CO2-) miscible flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place within the Navajo Nation, San Juan County, Utah.

  13. Increased Oil Production and Reserves Utilizing Secondary/Tertiary Recovery Techniques on Small Reservoirs in the Paradox Basin, Utah

    SciTech Connect

    Jr., Chidsey, Thomas C.; Allison, M. Lee

    1999-11-02

    The primary objective of this project is to enhance domestic petroleum production by field demonstration and technology transfer of an advanced- oil-recovery technology in the Paradox basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to approximately 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million barrels (23,850,000-31,800,000 m3) of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon-dioxide-(CO2-) miscible flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place within the Navajo Nation, San Juan County, Utah.

  14. Oil and gas production in the Amu Dar`ya Basin of Western Uzbekistan and Eastern Turkmenistan

    SciTech Connect

    Sagers, M.J.

    1995-05-01

    The resource base, development history, current output, and future outlook for oil and gas production in Turkmenistan and Uzbekistan are examined by a Western specialist with particular emphasis on the most important gas-oil province in the region, the Amu Dar`ya basin. Oil and gas have been produced in both newly independent countries for over a century, but production from the Amu Dar`ya province proper dates from the post-World War II period. Since that time, however, fields in the basin have provided the basis for a substantial natural gas industry (Uzbekistan and Turkmenistan consistently have trailed only Russia among the former Soviet republics in gas output during the last three decades). Despite high levels of current production, ample oil and gas potential (Turkmenistan, for example, ranks among the top five or six countries in the world in terms of gas reserves) contributes to the region`s prominence as an attractive area for Western investors. The paper reviews the history and status of several international tenders for the development of both gas and oil in the two republics. Sections on recent gas production trends and future outlook reveal considerable differences in consumption patterns and export potential in the region. Uzbekistan consumes most of the gas it produces, whereas Turkmenistan, with larger reserves and a smaller population, exported well over 85% of its output over recent years and appears poised to become a major exporter. A concluding section examines the conditions that will affect these countries` presence on world oil and gas markets over the longer term: reserves, domestic consumption, transportation bottlenecks, the likelihood of foreign investment, and future oil and gas demand. 33 refs., 1 fig., 3 tabs.

  15. Pampo, Linguado, and Badejo Fields: Their discoveries, appraisals, and early production systems

    SciTech Connect

    Tigre, C.A.; Possato, S.

    1983-05-01

    The three oil fields Pampo, Linguado and Badejo are located in the southwesternmost known producing areas of the offshore Brazilian Campos Basin. They were discovered as a result of reflection seismic survey and produce from fractured lower Cretaceous (Neocomian) basalts, coquinas of the Aptian Lagoa Feia Formation, carbonates of the Albian Macae Formation and from Eocene sandstones of the Carapebus Member of the Campos Formation. This work describes the prospects, their results, the main reservoirs, correlations, continuity and diagenetic problems. Two early production systems are in operation engaged in gathering a better knowledge of the fields for the planning of a definitive production system.

  16. Environmental benefits of advanced oil and gas exploration and production technology

    SciTech Connect

    1999-10-01

    THROUGHOUT THE OIL AND GAS LIFE CYCLE, THE INDUSTRY HAS APPLIED AN ARRAY OF ADVANCED TECHNOLOGIES TO IMPROVE EFFICIENCY, PRODUCTIVITY, AND ENVIRONMENTAL PERFORMANCE. THIS REPORT FOCUSES SPECIFICALLY ON ADVANCES IN EXPLORATION AND PRODUCTION (E&P) OPERATIONS.

  17. U.S. crude oil production expected to top 9 million barrels per...

    Energy Information Administration (EIA) (indexed site)

    Production in both of those areas is less sensitive to short-term price movements than is onshore production. In the Lower 48 states. Many oil companies have cut back on their ...

  18. 9000 wells planned for heavy oil field. [Canada

    SciTech Connect

    Not Available

    1981-05-01

    Beginning in 1983, Esso Resources Canada Ltd. will begin drilling the first of an estimated 9000 directional crude bitumen wells in the tar sands at Cold Lake, Alberta, Canada, the final wells being drilled in the year 2008. The area, covering 50 sq miles of extreme E. Alberta along the Saskatchewan border, contains one of the richest deposits of heavy oil sands in Canada. The company and future partners will drill the bitumen wells directionally into the shallow clearwater formation, which can be reached at approx. 100 m (330 ft). The formation contains an estimated 80 billion bbl of crude bitumen at a rate of 60,000 bpd for 25 yr. This volume of crude will be refined in an upgrading plant to 140,000 bpd of synthetic crude oil. When completed, the Cold Lake project will be one of the largest facilities for producing crude bitumen from wells in the world.

  19. Laboratory studies of oil spill behavior in broken ice fields. Final report Nov 80-Nov 81

    SciTech Connect

    Free, A.P.; Cox, J.C.; Schultz, L.A.

    1981-10-01

    This study examined the short-term behavior of oil spilled in or near a field of broken ice. The mechanics of oil seeping through the spaces between the ice blocks were examined, both on the level of a single straight gap and on the level of a random broken ice field, through experiments performed in ARCTEC, Incorporated's Ice Flume. The spreading of oil due to movement of the ice pack is discussed. The effects of the environment in the spill area, especially currents and winds, are taken into account throughout the study. The report gives information which permits the determination of the one-dimensional spread rate of oil spilled in a broken ice field, such as might be encountered in a natural lead or in a ship channel. The results are presented as a set of recommendations for use in oil spill response planning or for use by on-site response personnel in predicting the behavior of oil spilled in broken ice fields.

  20. IMPROVED OIL RECOVERY FROM UPPER JURASSIC SMACKOVER CARBONATES THROUGH THE APPLICATION OF ADVANCED TECHNOLOGIES AT WOMACK HILL OIL FIELD, CHOCTAW AND CLARKE COUNTIES, EASTERN GULF COASTAL PLAIN

    SciTech Connect

    Ernest A. Mancini

    2003-05-20

    Pruet Production Co. and the Center for Sedimentary Basin Studies at the University of Alabama, in cooperation with Texas A&M University, Mississippi State University, University of Mississippi, and Wayne Stafford and Associates are undertaking a focused, comprehensive, integrated and multidisciplinary study of Upper Jurassic Smackover carbonates (Class II Reservoir), involving reservoir characterization and 3-D modeling and an integrated field demonstration project at Womack Hill Oil Field Unit, Choctaw and Clarke Counties, Alabama, Eastern Gulf Coastal Plain. The principal objectives of the project are: increasing the productivity and profitability of the Womack Hill Field Unit, thereby extending the economic life of this Class II Reservoir and transferring effectively and in a timely manner the knowledge gained and technology developed from this project to producers who are operating other domestic fields with Class II Reservoirs. The principal research efforts for Year 3 of the project have been recovery technology analysis and recovery technology evaluation. The research focus has primarily been on well test analysis, 3-D reservoir simulation, microbial core experiments, and the decision to acquire new seismic data for the Womack Hill Field area. Although Geoscientific Reservoir Characterization and 3-D Geologic Modeling have been completed and Petrophysical and Engineering Characterization and Microbial Characterization are essentially on schedule, a no-cost extension until September 30, 2003, has been granted by DOE so that new seismic data for the Womack Hill Field can be acquired and interpreted to assist in the determination as to whether Phase II of the project should be implemented.

  1. World Oil Prices and Production Trends in AEO2009 (released in AEO2009)

    Reports and Publications

    2009-01-01

    The oil prices reported in Annual Energy Outlook 2009 (AEO) represent the price of light, low-sulfur crude oil in 2007 dollars. Projections of future supply and demand are made for "liquids," a term used to refer to those liquids that after processing and refining can be used interchangeably with petroleum products. In AEO2009, liquids include conventional petroleum liquids -- such as conventional crude oil and natural gas plant liquids -- in addition to unconventional liquids, such as biofuels, bitumen, coal-to-liquids (CTL), gas-to-liquids (GTL), extra-heavy oils, and shale oil.

  2. Fiber optic penetrator for offshore oil well exploration and production

    SciTech Connect

    Collins, J.C.; Warner, C.P.; Henkener, J.A.; Glauser, R.

    1986-07-01

    A fiber optic penetrator arrangement is described for an undersea wall structure of offshore oil well production apparatus, comprising: a. a generally cylindrical housing; b. a cofferdam associated with the undersea production apparatus and defining a generally cylindrical entrance port into which the penetrator is designed to be inserted and mounted; c. a sealing means for sealing the penetrator relative to the entrance port after insertion of the penetrator therein; d. an external bulkhead; e. a second bulkhead positioned internally of the external bulkead; f. a compression spring normally retaining the second bulkhead in a sealed position with the penetrator, the compressing spring being compressed between the second bulkhead and the external bulkhead; g. a breakaway connection affixed to the external bulkhead for coupling an optical fiber transmission cable to the external bulkhead, such that if the transmission cable is snagged or pulled, the external bulkhead will sever along with the breakaway connection so that the penetrator is not pulled from the cofferdam entrance port, the second bulkhead being held in position by ambient water pressure to become the primary bulkhead after the external bulkhead is severed.

  3. U.S. Crude Oil + Lease Condensate Reserves New Field Discoveries (Million

    Energy Information Administration (EIA) (indexed site)

    Barrels) New Field Discoveries (Million Barrels) U.S. Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 141 2010's 124 481 55 191 164 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discove

  4. U.S. Product Supplied for Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    2010 2011 2012 2013 2014 2015 View History Total Crude Oil and Petroleum Products 19,180 18,882 18,490 18,959 19,106 19,531 1973-2015 Crude Oil 0 0 0 0 0 0 1981-2015 Natural Gas Liquids and LRGs 2,265 2,237 2,301 2,495 2,448 2,549 1983-2015 Pentanes Plus 92 32 50 56 52 95 1983-2015 Liquefied Petroleum Gases 2,173 2,204 2,251 2,440 2,396 2,454 1973-2015 Ethane/Ethylene 880 950 958 990 1,048 1,072 1983-2015 Propane/Propylene 1,160 1,153 1,175 1,275 1,167 1,162 1973-2015 Normal Butane/Butylene 108

  5. East Coast (PADD 1) Imports of Crude Oil and Petroleum Products for

    Gasoline and Diesel Fuel Update

    & Other Liquids Reports Monthly Crude Oil and Natural Gas Production Release date: October 31, 2016 | Next release date: November 30, 2016 Crude oil Natural gas Crude Oil (thousand barrels per day) State/area Percent change Percent change Notes: Crude oil includes lease condensate. The sum of individual states may not equal total U.S. volumes due to independent rounding. A zero may indicate volume of less than 0.5 thousand barrels per day. Previous months' production volumes may have been

  6. Process and economic model of in-field heavy oil upgrading using aqueous pyrolysis

    SciTech Connect

    Thorsness, C. B., LLNL

    1997-01-21

    A process and economic model for aqueous pyrolysis in-field upgrading of heavy oil has been developed. The model has been constructed using the ASPEN PLUS chemical process simulator. The process features cracking of heavy oil at moderate temperatures in the presence of water to increase oil quality and thus the value of the oil. Calculations with the model indicate that for a 464 Mg/day (3,000 bbl/day) process, which increases the oil API gravity of the processed oil from 13.5{degree} to 22.4{degree}, the required value increase of the oil would need to be at least $2.80/Mg{center_dot}{degree}API($0.40/bbl{center_dot}{degree}API) to make the process economically attractive. This level of upgrading has been demonstrated in preliminary experiments with candidate catalysts. For improved catalysts capable of having the coke make and increasing the pyrolysis rate, a required price increase for the oil as low as $1.34/Mg{center_dot}{degree}API ($0.21/bbl{center_dot}{degree}API)has been calculated.

  7. Active hurricane season expected to shut-in higher amount of oil and natural gas production

    Energy Information Administration (EIA) (indexed site)

    Active hurricane season expected to shut-in higher amount of oil and natural gas production An above-normal 2013 hurricane season is expected to cause a median production loss of about 19 million barrels of U.S. crude oil and 46 billion cubic feet of natural gas production in the Gulf of Mexico, according to the new forecast from the U.S. Energy Information Administration. That's about one-third more than the amount of oil and gas production knocked offline during last year's hurricane season.

  8. U.S. oil production forecast revised up for 2016 and 2017

    Energy Information Administration (EIA) (indexed site)

    oil production forecast revised up for 2016 and 2017 U.S. crude oil production is expected to be higher this year and in 2017 than previously forecast, because of a slower decline in onshore production. In its new monthly forecast, the U.S. Energy Information Administration revised up its estimate for domestic oil production by about 110,000 barrels per day for 2016 and by 150,000 barrels per day next year. EIA said increased drilling activity in the Permian Basin area located in West Texas and

  9. Oil

    Energy.gov [DOE]

    The Energy Department works to ensure domestic and global oil supplies are environmentally sustainable and invests in research and technology to make oil drilling cleaner and more efficient.

  10. Activities of the Oil Implementation Task Force, December 1990--February 1991; Contracts for field projects and supporting research on enhanced oil recovery, April--June 1990

    SciTech Connect

    Tiedemann, H.A. )

    1991-03-01

    The Oil Implementation Task Force was appointed to implement the US DOE's new oil research program directed toward increasing domestic oil production by expanded research on near- or mid-term enhanced oil recovery methods. An added priority is to preserve access to reservoirs that have the largest potential for oil recovery, but that are threatened by the large number of wells abandoned each year. This report describes the progress of research activities in the following areas: chemical flooding; gas displacement; thermal recovery; resource assessment; microbial technology; geoscience technology; and environmental technology. (CK)

  11. A nuclear wind/solar oil-shale system for variable electricity and liquid fuels production

    SciTech Connect

    Forsberg, C.

    2012-07-01

    The recoverable reserves of oil shale in the United States exceed the total quantity of oil produced to date worldwide. Oil shale contains no oil, rather it contains kerogen which when heated decomposes into oil, gases, and a carbon char. The energy required to heat the kerogen-containing rock to produce the oil is about a quarter of the energy value of the recovered products. If fossil fuels are burned to supply this energy, the greenhouse gas releases are large relative to producing gasoline and diesel from crude oil. The oil shale can be heated underground with steam from nuclear reactors leaving the carbon char underground - a form of carbon sequestration. Because the thermal conductivity of the oil shale is low, the heating process takes months to years. This process characteristic in a system where the reactor dominates the capital costs creates the option to operate the nuclear reactor at base load while providing variable electricity to meet peak electricity demand and heat for the shale oil at times of low electricity demand. This, in turn, may enable the large scale use of renewables such as wind and solar for electricity production because the base-load nuclear plants can provide lower-cost variable backup electricity. Nuclear shale oil may reduce the greenhouse gas releases from using gasoline and diesel in half relative to gasoline and diesel produced from conventional oil. The variable electricity replaces electricity that would have been produced by fossil plants. The carbon credits from replacing fossil fuels for variable electricity production, if assigned to shale oil production, results in a carbon footprint from burning gasoline or diesel from shale oil that may half that of conventional crude oil. The U.S. imports about 10 million barrels of oil per day at a cost of a billion dollars per day. It would require about 200 GW of high-temperature nuclear heat to recover this quantity of shale oil - about two-thirds the thermal output of existing

  12. Disposal of oil field wastes into salt caverns: Feasibility, legality, risk, and costs

    SciTech Connect

    Veil, J.A.

    1997-10-01

    Salt caverns can be formed through solution mining in the bedded or domal salt formations that are found in many states. Salt caverns have traditionally been used for hydrocarbon storage, but caverns have also been used to dispose of some types of wastes. This paper provides an overview of several years of research by Argonne National Laboratory on the feasibility and legality of using salt caverns for disposing of oil field wastes, the risks to human populations from this disposal method, and the cost of cavern disposal. Costs are compared between the four operating US disposal caverns and other commercial disposal options located in the same geographic area as the caverns. Argonne`s research indicates that disposal of oil field wastes into salt caverns is feasible and legal. The risk from cavern disposal of oil field wastes appears to be below accepted safe risk thresholds. Disposal caverns are economically competitive with other disposal options.

  13. Potential Oil Production from the Coastal Plain of the Arctic National

    Energy Information Administration (EIA) (indexed site)

    Wildlife Refuge: Updated Assessment Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment 2. Analysis Discussion Resource Assessment The USGS most recent assessment of oil and gas resources of ANWR Coastal Plain (The Oil and Gas Resource Potential of the Arctic National Wildlife Refuge 1002 Area, Alaska, Open File Report 98-34, 1999) provided basic information used in this study. A prior assessment was completed in 1987 by the USGS.

  14. Contracts for field projects and supporting research on enhanced oil recovery. Reporting period July--September 1996

    SciTech Connect

    1997-12-01

    This report contains information on accomplishments completed during July through September 1997 on contracts for field projects and supporting research on Enhanced Oil Recovery.

  15. Preliminary Economics for the Production of Pyrolysis Oil from Lignin in a Cellulosic Ethanol Biorefinery

    SciTech Connect

    Jones, Susanne B.; Zhu, Yunhua

    2009-04-01

    Cellulosic ethanol biorefinery economics can be potentially improved by converting by-product lignin into high valued products. Cellulosic biomass is composed mainly of cellulose, hemicellulose and lignin. In a cellulosic ethanol biorefinery, cellulose and hemicellullose are converted to ethanol via fermentation. The raw lignin portion is the partially dewatered stream that is separated from the product ethanol and contains lignin, unconverted feed and other by-products. It can be burned as fuel for the plant or can be diverted into higher-value products. One such higher-valued product is pyrolysis oil, a fuel that can be further upgraded into motor gasoline fuels. While pyrolysis of pure lignin is not a good source of pyrolysis liquids, raw lignin containing unconverted feed and by-products may have potential as a feedstock. This report considers only the production of the pyrolysis oil and does not estimate the cost of upgrading that oil into synthetic crude oil or finished gasoline and diesel. A techno-economic analysis for the production of pyrolysis oil from raw lignin was conducted. comparing two cellulosic ethanol fermentation based biorefineries. The base case is the NREL 2002 cellulosic ethanol design report case where 2000 MTPD of corn stover is fermented to ethanol (NREL 2002). In the base case, lignin is separated from the ethanol product, dewatered, and burned to produce steam and power. The alternate case considered in this report dries the lignin, and then uses fast pyrolysis to generate a bio-oil product. Steam and power are generated in this alternate case by burning some of the corn stover feed, rather than fermenting it. This reduces the annual ethanol production rate from 69 to 54 million gallons/year. Assuming a pyrolysis oil value similar to Btu-adjusted residual oil, the estimated ethanol selling price ranges from $1.40 to $1.48 (2007 $) depending upon the yield of pyrolysis oil. This is considerably above the target minimum ethanol selling

  16. Lower 48 States Crude Oil + Lease Condensate Reserves New Field Discoveries

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Field Discoveries (Million Barrels) Lower 48 States Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 132 2010's 124 481 55 191 164 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate

  17. Ohio Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Reservoir Discoveries in Old Fields (Million Barrels) Ohio Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 3 5 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  18. Texas - RRC District 1 Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Texas - RRC District 1 Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 4 2010's 54 29 19 2 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  19. Texas - RRC District 10 Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Texas - RRC District 10 Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 1 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  20. Texas - RRC District 7C Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) C Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries TX, RRC District 7C

  1. Texas - RRC District 8 Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Texas - RRC District 8 Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 2 3 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  2. Texas - RRC District 8A Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) Texas - RRC District 8A Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 1 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  3. Texas - RRC District 9 Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) 9 Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries TX, RRC District 9

  4. Texas Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Reservoir Discoveries in Old Fields (Million Barrels) Texas Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 6 2010's 8 44 60 72 86 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  5. U.S. Federal Offshore Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) New Field Discoveries (Million Barrels) U.S. Federal Offshore Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 96 2010's 10 410 7 181 140 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus

  6. Kansas Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Reservoir Discoveries in Old Fields (Million Barrels) Kansas Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 3 2010's 4 5 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease

  7. Reactivation of an Idle Lease to Increase Heavy Oil Recovery through Application of Conventional Steam Drive Technology in a Low Dip Slope and Basin Reservoir in the Midway-Sunset Field, San Jaoquin Basin, California

    SciTech Connect

    Steven Schamel

    1998-02-27

    A previously idle portion of the Midway-Sunset field, the ARCO Western Energy Pru Fee property, is being brought back into commercial production through tight integration of geologic characterization, geostatistical modeling, reservoir simulation, and petroleum engineering. This property, shut-in over a decade ago as economically marginal using conventional cyclic steaming methods, has a 200-300 foot thick oil column in the Monarch Sand. However, the sand lacks effective steam barriers and has a thick water-saturation zone above the oil-water contact. These factors require an innovative approach to steam flood production design that will balance optimal total oil production against economically viable steam-oil ratios and production rates. The methods used in the Class III demonstration are accessible to most operators in the Midway-Sunset field and could be used to revitalize properties with declining production of heavy oils throughout the region. In January 1997 the project entered its second and main phase with the purpose of demonstrating whether steamflood can be a more effective mode of production of the heavy, viscous oils from the Monarch Sand reservoir than the more conventional cyclic steaming. The objective is not just to produce the pilot site within the Pru Fee property south of Taft, but to test which production parameters optimize total oil recovery at economically acceptable rates of production and production costs.

  8. Conformal field theories at nonzero temperature: Operator product...

    Office of Scientific and Technical Information (OSTI)

    nonzero temperature: Operator product expansions, Monte Carlo, and holography Citation Details In-Document Search Title: Conformal field theories at nonzero temperature: Operator ...

  9. Observable non-Gaussianity from gauge field production in slow...

    Office of Scientific and Technical Information (OSTI)

    Observable non-Gaussianity from gauge field production in slow roll inflation, and a challenging connection with magnetogenesis Citation Details In-Document Search Title: ...

  10. Gauge field production in axion inflation: Consequences for monodromy...

    Office of Scientific and Technical Information (OSTI)

    Gauge field production in axion inflation: Consequences for monodromy, non-Gaussianity in the CMB, and gravitational waves at interferometers Citation Details In-Document Search ...

  11. Decline in U.S. oil production wont be as steep

    Energy Information Administration (EIA) (indexed site)

    Decline in U.S. oil production won't be as steep Although total U.S. crude oil production is expected to continue declining, the drop in output this year and in 2017 won't be as steep, because of improved efficiency at drilling rigs and more drilling overall. In its new monthly forecast, the U.S. Energy Information Administration revised up its estimate for domestic daily oil output for this year by about 100,000 barrels to 8.8 million barrels per day. Daily production for next year was given a

  12. Non-OPEC oil production set to decline for the first time since 2008

    Energy Information Administration (EIA) (indexed site)

    Non-OPEC oil production set to decline for the first time since 2008 Total oil production from countries outside of OPEC, the Organization of the Petroleum Exporting Countries, is expected to decline next year for the first time since 2008. In its new monthly forecast, the U.S. Energy Information Administration said it expects non- OPEC oil production to grow by 1.1 million barrels per day this year....and then decline by 300,000 barrels per day next year. As a result, the rate of growth in

  13. USING CABLE SUSPENDED SUBMERSIBLE PUMPS TO REDUCE PRODUCTION COSTS TO INCREASE ULTIMATE RECOVERY IN THE RED MOUNTAIN FIELD IN SAM JUAN BASIN REGION

    SciTech Connect

    Don L. Hanosh

    2004-08-01

    A joint venture between Enerdyne LLC, a small independent oil and gas producer, and Pumping Solutions Inc., developer of a low volume electric submersible pump, suspended from a cable, both based in Albuquerque, New Mexico, has re-established marginal oil production from the Red Mountain Oil Field, located in the San Juan Basin, New Mexico by working over 17 existing wells and installing submersible pumps.

  14. EIS-0016: Cumulative Production/Consumption Effects of the Crude Oil Price Incentive Rulemakings, Programmatic

    Energy.gov [DOE]

    The U.S. Department of Energy prepared this Final Statement to FEA-FES-77-7 to assess the environmental and socioeconomic implications of a rulemaking on crude oil pricing incentives as pertains to the full range of oil production technologies (present as well as anticipated.)

  15. Western oil-shale development: a technology assessment. Volume 2: technology characterization and production scenarios

    SciTech Connect

    Not Available

    1982-01-01

    A technology characterization of processes that may be used in the oil shale industry is presented. The six processes investigated are TOSCO II, Paraho Direct, Union B, Superior, Occidental MIS, and Lurgi-Ruhrgas. A scanario of shale oil production to the 300,000 BPD level by 1990 is developed. (ACR)

  16. West Coast (PADD 5) Total Crude Oil and Products Imports

    Energy Information Administration (EIA) (indexed site)

    Distillate Fuel Oil Distillate F.O., 15 ppm and under Distillate F.O., 15 to 500 ppm Distillate F.O., Greater than 500 ppm Distillate F.O., 501 to 2000 ppm Distillate F.O., Greater than 2000 ppm Kerosene Finished Aviation Gasoline Aviation Gasoline Blending Components Kerosene-Type Jet Fuel Special Naphthas Residual Fuel Oil Residual F.O., Less than 0.31% Sulfur Residual F.O., 0.31 to 1% Sulfur Residual F.O., Greater than 1% Sulfur Naphtha for Petrochem. Feed. Use Other Oils for Petrochem. Feed.

  17. Improved Oil Recovery from Upper Jurassic Smackover Carbonates through the Application of Advanced Technologies at Womack Hill Oil Field, Choctaw and Clarke Counties, Eastern Gulf Coastal Plain

    SciTech Connect

    Ernest A. Mancini

    2003-12-31

    , multiwell productivity analysis, and reservoir simulation studies indicate that water injection continues to provide stable support to maintain production from wells in the western unitized area of the field and that the strong water drive present in the eastern area of the field is adequate to sustain production from this part of the field. Although the results from the microbial characterization and microbial core experiments are very promising, it is recommended that an immobilized enzyme technology project not be implemented in the Womack Hill Field Unit until live (freshly taken and properly preserved) cores from the Smackover reservoir in the field are acquired to confirm the microbial core experiments to date. From 3-D geologic modeling, reservoir performance analysis, and reservoir simulation, four areas in the Womack Hill Field were identified as prospective infill drilling sites to recover undrained oil from the field. It was determined that the two areas in the unit area probably can be effectively drained by perforating higher zones in the Smackover reservoir in currently producing wells. The two areas in the eastern (non-unitized) part of the field require the drilling of new wells. The successful drilling and testing of a well in 2003 by J. R. Pounds, Inc. has proven the oil potential of the easternmost site in the non-unitized part of the field. Pruet Production Co. acquired new 2-D seismic data to evaluate the oil potential of the westernmost site. Because of the effects of a fault shadow from the major fault bounding the southern border of the Womack Hill Field, it is difficult to evaluate conclusively this potential drill site. Pruet Production Co. has decided not to drill this new well at this time and to further evaluate the new 2-D seismic profiles after these data have been processed using a pre-stack migration technique. Pruet Production Co. has elected not to continue into Phase II of this project because they are not prepared to make a proposal to

  18. Improved Oil Recovery from Upper Jurassic Smackover Carbonates through the Application of Advanced Technologies at Womack Hill Oil Field, Choctaw and Clarke Counties, Eastern Gulf Costal Plain

    SciTech Connect

    Ernest A. Mancini

    2006-05-31

    , multiwell productivity analysis, and reservoir simulation studies indicate that water injection continues to provide stable support to maintain production from wells in the western unitized area of the field and that the strong water drive present in the eastern area of the field is adequate to sustain production from this part of the field. Although the results from the microbial characterization and microbial core experiments are very promising, it is recommended that an immobilized enzyme technology project not be implemented in the Womack Hill Field Unit until live (freshly taken and properly preserved) cores from the Smackover reservoir in the field are acquired to confirm the microbial core experiments to date. From 3-D geologic modeling, reservoir performance analysis, and reservoir simulation, four areas in the Womack Hill Field were identified as prospective infill drilling sites to recover undrained oil from the field. It was determined that the two areas in the unit area probably can be effectively drained by perforating higher zones in the Smackover reservoir in currently producing wells. The two areas in the eastern (non-unitized) part of the field require the drilling of new wells. The successful drilling and testing of a well in 2003 by J. R. Pounds, Inc. has proven the oil potential of the easternmost site in the non-unitized part of the field. Pruet Production Co. acquired new 2-D seismic data to evaluate the oil potential of the westernmost site. Because of the effects of a fault shadow from the major fault bounding the southern border of the Womack Hill Field, it is difficult to evaluate conclusively this potential drill site. Pruet Production Co. has decided not to drill this new well at this time and to further evaluate the new 2-D seismic profiles after these data have been processed using a pre-stack migration technique. Pruet Production Co. has elected not to continue into Phase II of this project because they are not prepared to make a proposal to

  19. Rocky Mountain (PADD 4) Total Crude Oil and Products Imports

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    Conventional Gasoline Blend. Comp. Fuel Ethanol (Renewable) Biomass-Based Diesel (Renewable) Distillate Fuel Oil Distillate F.O., 15 ppm and under Distillate F.O., 15 to 500 ppm ...

  20. Common Products Made from Oil and Natural Gas

    Office of Energy Efficiency and Renewable Energy (EERE)

    Educational poster developed by the Office of Fossil Energy that graphically displays items that are made from oil and gas. Appropriate for teachers and students in K-8th grade.

  1. EIA - Analysis of Crude Oil Production in the Arctic National...

    Annual Energy Outlook

    ANWR was created by the Alaska National Interest Lands Conservation Act (ANILCA) in 1980. Section 1002 of ANILCA deferred a decision on the management of oil and natural gas ...

  2. Development of Improved Oil Field Waste Injection Disposal Techniques

    SciTech Connect

    Terralog Technologies USA Inc.

    2001-12-17

    The goals of this DOE sponsored project are to: (1) assemble and analyze a comprehensive database of past waste injection operations; (2) develop improved diagnostic techniques for monitoring fracture growth and formation changes; (3) develop operating guidelines to optimize daily operations and ultimate storage capacity of the target formation; and (4) to test these improved models and guidelines in the field.

  3. Development of Improved Oil Field Waste Injection Disposal Techniques

    SciTech Connect

    Terralog Technologies

    2002-11-25

    The goals of this project have was to: (1) assemble and analyze a comprehensive database of past waste injection operations; (2) develop improved diagnostic techniques for monitoring fracture growth and formation changes; (3) develop operating guidelines to optimize daily operations and ultimate storage capacity of the target formation; and (4) to apply these improved models and guidelines in the field.

  4. Characteristics of enriched cultures for bio-huff-`n`-puff tests at Jilin oil field

    SciTech Connect

    Xiu-Yuan Wang; Gang Dai; Yan-Fen Xue; Shu-Hua Xie

    1995-12-31

    Three enriched cultures (48, 15a, and 26a), selected from more than 80 soil and water samples, could grow anaerobically in the presence of crude oil at 30{degrees}C and could ferment molasses to gases and organic acids. Oil recovery by culture 48 in the laboratory model experiment was enhanced by 25.2% over the original reserves and by 53.7% over the residual reserves. Enriched culture 48 was composed of at least 4 species belonging to the genera Eubacterium, Fusobacterium, and Bacteroides. This enriched culture was used as inoculum for MEOR field trials at Jilin oil field with satisfactory results. The importance of the role of these isolates in EOR was confirmed by their presence and behavior in the fluids produced from the microbiologically treated reservoir.

  5. U.S. monthly oil production tops 8 million barrels per day for the first time since 1988

    Energy Information Administration (EIA) (indexed site)

    oil production tops 8 million barrels per day for the first time since 1988 Estimated U.S. crude oil production in November topped 8 million barrels per day for the first time in 25 years, according to the new monthly energy forecast from the U.S. Energy Information Administration. Rising oil output from tight oil formations in North Dakota and Texas are playing a key role, with annual U.S. oil production expected to increase to an average of 8.5 million barrels per day next year. More oil

  6. Large-Scale Pyrolysis Oil Production: A Technology Assessment and Economic Analysis

    SciTech Connect

    Ringer, M.; Putsche, V.; Scahill, J.

    2006-11-01

    A broad perspective of pyrolysis technology as it relates to converting biomass substrates to a liquid bio-oil product and a detailed technical and economic assessment of a fast pyrolysis plant.

  7. Past, Present, and Future Production of Bio-oil (Journal Article...

    Office of Scientific and Technical Information (OSTI)

    Bio-oil is a liquid product produced by fast pyrol-ysis of biomass. The fast pyrolysis is performed by heating the biomass rapidly (2 sec) at temperatures ranging from 350 to 650 ...

  8. U.S. Crude Oil Production Forecast-Analysis of Crude Types

    Energy Information Administration (EIA) (indexed site)

    of Energy Washington, DC 20585 U.S. Energy Information Administration | U.S. Crude Oil Production Forecast-Analysis of Crude Types i This report was prepared by the U.S....

  9. Preliminary Technical and Legal Evaluation of Disposing of Nonhazardous Oil Field Waste into Salt Caverns

    SciTech Connect

    Ayers, Robert C.; Caudle, Dan; Elcock, Deborah; Raivel, Mary; Veil, John; and Grunewald, Ben

    1999-01-21

    This report presents an initial evaluation of the suitability, feasibility, and legality of using salt caverns for disposal of nonhazardous oil field wastes. Given the preliminary and general nature of this report, we recognize that some of our findings and conclusions maybe speculative and subject to change upon further research on this topic.

  10. Comparison of selected oil-field brines from fields in the Permian basin, West Texas-southeast New Mexico

    SciTech Connect

    White, H.G. III

    1992-04-01

    Stiff diagrams of oil-field brines from the west Texas Permian basin are identifiable within the geological framework. Plotted from a simple analysis of three cations and three anions, older Paleozoic waters can be categorized as either 'pristine' or modified, usually by a later influx of Permian or early Pennsylvanian water. These different plots can be segregated by geologic province. The Permian brines differ by age and also by environment (shelf, basin, etc.).

  11. Potential Oil Production from the Coastal Plain of the Arctic National

    Energy Information Administration (EIA) (indexed site)

    Wildlife Refuge: Updated Assessment Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment Executive Summary This Service Report, Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment, was prepared for the U.S. Senate Committee on Energy and Natural Resources at the request of Chairman Frank H. Murkowski in a letter dated March 10, 2000. The request asked the Energy Information

  12. Potential Oil Production from the Coastal Plain of the Arctic National

    Energy Information Administration (EIA) (indexed site)

    Wildlife Refuge: Updated Assessment Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment References Energy Information Administration, Annual Energy Outlook 2000, DOE/EIA-0383(2000) (Washington, DC, December 1999), Table A11. Energy Information Administration, Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge, SR/RNGD/87-01 (Washington, DC, September 1987). U.S. Department of Interior, Arctic National

  13. Total Crude Oil and Petroleum Products Imports by Area of Entry

    Energy Information Administration (EIA) (indexed site)

    by Area of Entry Product: Total Crude Oil and Petroleum Products Crude Oil Natural Gas Plant Liquids and Liquefied Refinery Gases Pentanes Plus Liquefied Petroleum Gases Ethane Ethylene Propane Propylene Normal Butane Butylene Isobutane Isobutylene Other Liquids Hydrogen/Oxygenates/Renewables/Other Hydrocarbons Oxygenates (excl. Fuel Ethanol) Methyl Tertiary Butyl Ether (MTBE) Other Oxygenates Renewable Fuels (incl. Fuel Ethanol) Fuel Ethanol Biomass-Based Diesel Fuel Other Renewable Diesel Fuel

  14. Texas - RRC District 5 Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  15. Texas - RRC District 7B Crude Oil + Lease Condensate Reserves New Field

    Energy Information Administration (EIA) (indexed site)

    Discoveries (Million Barrels) Reserves New Field Discoveries (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Field Discoveries

  16. Light oil yield improvement project at Granite City Division Coke/By-Product Plant

    SciTech Connect

    Holloran, R.A.

    1995-12-01

    Light oil removal from coke oven gas is a process that has long been proven and utilized throughout many North American Coke/By-Products Plants. The procedures, processes, and equipment requirements to maximize light oil recovery at the Granite City By-Products Plant will be discussed. The Light Oil Yield Improvement Project initially began in July, 1993 and was well into the final phase by February, 1994. Problem solving techniques, along with utilizing proven theoretical recovery standards were applied in this project. Process equipment improvements and implementation of Operator/Maintenance Standard Practices resulted in an average yield increase of 0.4 Gals./NTDC by the end of 1993.

  17. Optimize carbon dioxide sequestration, enhance oil recovery

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    Optimize carbon dioxide sequestration, enhance oil recovery Optimize carbon dioxide sequestration, enhance oil recovery The simulation provides an important approach to estimate the potential of storing carbon dioxide in depleted oil fields while simultaneously maximizing oil production. January 8, 2014 Schematic of a water-alternating-with-gas flood for CO2 sequestration and enhanced oil recovery. Schematic of a water-alternating-with-gas flood for CO2 sequestration and enhanced oil recovery.

  18. Optimize carbon dioxide sequestration, enhance oil recovery

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    Optimize carbon dioxide sequestration, enhance oil recovery Optimize carbon dioxide sequestration, enhance oil recovery The simulation provides an important approach to estimate the potential of storing carbon dioxide in depleted oil fields while simultaneously maximizing oil production. January 8, 2014 Schematic of a water-alternating-with-gas flood for CO2 sequestration and enhanced oil recovery. Schematic of a water-alternating-with-gas flood for CO2 sequestration and enhanced oil recovery.

  19. Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama -- Year 2. Annual report, March 1997--March 1998

    SciTech Connect

    Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Carroll, R.E.

    1998-09-01

    Gilbertown Field is the oldest oil field in Alabama and has produced oil from fractured chalk of the Cretaceous Selma Group and glauconitic sandstone of the Eutaw Formation. Nearly all of Gilbertown Field is still in primary recovery, although waterflooding has been attempted locally. The objective of this project is to analyze the geologic structure and burial history of Mesozoic and Tertiary strata in Gilbertown Field and adjacent areas in order to suggest ways in which oil recovery can be improved. Indeed, the decline of oil production to marginally economic levels in recent years has made this type of analysis timely and practical. Key technical advancements being sought include understanding the relationship of requisite strain to production in Gilbertown reservoirs, incorporation of synsedimentary growth factors into models of area balance, quantification of the relationship between requisite strain and bed curvature, determination of the timing of hydrocarbon generation, and identification of the avenues and mechanisms of fluid transport.

  20. Coupling the Alkaline-Surfactant-Polymer Technology and The Gelation Technology to Maximize Oil Production

    SciTech Connect

    Malcolm Pitts; Jie Qi; Dan Wilson; David Stewart; Bill Jones

    2005-10-01

    Gelation technologies have been developed to provide more efficient vertical sweep efficiencies for flooding naturally fractured oil reservoirs or more efficient areal sweep efficiency for those with high permeability contrast ''thief zones''. The field proven alkaline-surfactant-polymer technology economically recovers 15% to 25% OOIP more oil than waterflooding from swept pore space of an oil reservoir. However, alkaline-surfactant-polymer technology is not amenable to naturally fractured reservoirs or those with thief zones because much of injected solution bypasses target pore space containing oil. This work investigates whether combining these two technologies could broaden applicability of alkaline-surfactant-polymer flooding into these reservoirs. A prior fluid-fluid report discussed interaction of different gel chemical compositions and alkaline-surfactant-polymer solutions. Gel solutions under dynamic conditions of linear corefloods showed similar stability to alkaline-surfactant-polymer solutions as in the fluid-fluid analyses. Aluminum-polyacrylamide, flowing gels are not stable to alkaline-surfactant-polymer solutions of either pH 10.5 or 12.9. Chromium acetate-polyacrylamide flowing and rigid flowing gels are stable to subsequent alkaline-surfactant-polymer solution injection. Rigid flowing chromium acetate-polyacrylamide gels maintained permeability reduction better than flowing chromium acetate-polyacrylamide gels. Silicate-polyacrylamide gels are not stable with subsequent injection of either a pH 10.5 or a 12.9 alkaline-surfactant-polymer solution. Chromium acetate-xanthan gum rigid gels are not stable to subsequent alkaline-surfactant-polymer solution injection. Resorcinol-formaldehyde gels were stable to subsequent alkaline-surfactant-polymer solution injection. When evaluated in a dual core configuration, injected fluid flows into the core with the greatest effective permeability to the injected fluid. The same gel stability trends to subsequent

  1. Increased Oil Recovery from Mature Oil Fields Using Gelled Polymer Treatments

    SciTech Connect

    Willhite, G.P.; Green, D.W.; McCool, C.S.

    2001-01-22

    This report describes the progress of the first year of a three-year research program. This program is aimed at reducing barriers to the widespread use of gelled polymer treatments by (1) developing methods to predict gel behavior during placement in matrix rock and fractures, (2) determining the persistence of permeability reduction after gel placement, and (3) developing methods to design production well treatments to control water production.

  2. Total Crude Oil and Products Imports from All Countries

    Energy Information Administration (EIA) (indexed site)

    Other Renewable Fuels Distillate Fuel Oil Distillate F.O., 15 ppm and under Distillate F.O., 15 to 500 ppm Distillate F.O., Greater than 500 ppm Distillate F.O., 501 to 2000 ppm Distillate F.O., Greater than 2000 ppm Kerosene Finished Aviation Gasoline Aviation Gasoline Blending Components Kerosene-Type Jet Fuel Special Naphthas Residual Fuel Oil Residual F.O., Less than 0.31% Sulfur Residual F.O., 0.31 to 1% Sulfur Residual F.O., Greater than 1% Sulfur Naphtha for Petrochem. Feed. Use Other

  3. Energy and crude oil input requirements for the production of reformulated gasolines

    SciTech Connect

    Singh, M.; McNutt, B.

    1993-10-01

    The energy and crude oil requirements for the production of reformulated gasoline (RFG) are estimated. The scope of the study includes both the energy and crude oil embodied in the final product and the process energy required to manufacture the RFG and its components. The effects on energy and crude oil use of employing various oxygenates to meet the minimum oxygen-content level required by the Clean Air Act Amendments are evaluated. The analysis shows that production of RFG requires more total energy, but uses less crude oil, than that of conventional gasoline. The energy and crude oil use requirements of the different RFGs vary considerably. For the same emissions performance level, RFG with ethanol requires substantially more total energy and crude oil than does RFG with methyl tertiary butyl ether (MTBE) or ethyl tertiary butyl ether. A specific proposal by the US Environmental Protection Agency, designed to allow the use of ethanol in RFG, would increase the total energy required to produce RFG by 2% and the total crude oil required by 2.0 to 2.5% over the corresponding values for the base RFG with MTBE.

  4. Energy and crude oil input requirements for the production of reformulated gasolines

    SciTech Connect

    Singh, M.; McNutt, B.

    1993-11-01

    The energy and crude oil requirements for the production of reformulated gasolines (RFG) are estimated. Both the energy and crude oil embodied in the final product and the process energy required to manufacture the RFG and its components are included. The effects on energy and crude oil use of using various oxygenates to meet the minimum oxygen content level required by the Clean Air Act Amendments are evaluated. The analysis illustrates that production of RFG requires more total energy than that of conventional gasoline but uses less crude oil. The energy and crude oil use requirements of the different RFGs vary considerably. For the same emissions performance level, RFG with ethanol requires substantially more total energy and crude oil than RFG with MTBE or ETBE. A specific proposal by the EPA designed to allow the use of ethanol in RFG would increase the total energy required to produce RFG by 2% and the total crude oil required by 2.0 to 2.5% over that for the base RFG with MTBE.

  5. Oil production by entrained pyrolysis of biomass and processing of oil and char

    DOEpatents

    Knight, James A.; Gorton, Charles W.

    1990-01-02

    Entrained pyrolysis of lignocellulosic material proceeds from a controlled pyrolysis-initiating temperature to completion of an oxygen free environment at atmospheric pressure and controlled residence time to provide a high yield recovery of pyrolysis oil together with char and non-condensable, combustible gases. The residence time is a function of gas flow rate and the initiating temperature is likewise a function of the gas flow rate, varying therewith. A controlled initiating temperature range of about 400.degree. C. to 550.degree. C. with corresponding gas flow rates to maximize oil yield is disclosed.

  6. World heavy oil and bitumen riches - update 1983: Part two, production

    SciTech Connect

    Not Available

    1983-06-08

    Despite world recession, overabundance of conventional oil and light product supplies, softer oil prices, and certain important reversals in development policies, worldwide production of heavy and extra-heavy crude oil increased 11.3% in 1982 compared to 1981; latest 1983 data confirm this trend. For the top ten heavy-oil-producing nations, the increase was 17.7% over the same period, mainly due to increases in Venezuela, Mexico, and Nigeria. In 1981, world heavy and extra-heavy crude production was 6.1% of world conventional oil production; in 1982 it increased to 7.2%. Bitumen production in Canada, the only country with 1982 production figures, increased 46% over 1981. It is probable that further technological advances and experimentation in other countries, including the Soviet Union, have resulted in other bitumen production increases as well. Although multinational cooperation in research for extraction, upgrading, and transportation of heavy crudes and bitumens has not grown to the extent that many industry experts had hoped, several broad areas of cooperation stand supported and many of them have been strengthened. Such progress in the face of economic and political uncertainties are demonstrations of world leadership for the next petroleum age. This issue presents the Energy Detente fuel price/tax series and industrial fuel prices for June 1983 for countries of the Eastern Hemisphere.

  7. Application of turbidite facies of the Stevens Oil Zone for reservoir management, Elk Hills Field, California

    SciTech Connect

    Reid, S.A.; Thompson, T.W.; McJannet, G.S.

    1996-12-31

    A detailed depositional model for the uppermost sand reservoirs of the Stevens Oil Zone, Elk Hills Field, California, contains three facies: turbidite channel-fill sand bodies, overbank Sandstone and mudstone, and pelagic and hemipelagic siliceous shale. Sand bodies are the primary producing facies and consist of layered, graded sandstone with good permeability. The presence of incipient anticlines with subsea relief in the late Miocene resulted in deposition of lenticular and sinuous sand Was within structurally created channels. Relief of these structural channels was low when the earliest sand bodies were deposited, leading to a wide channel complex bounded by broad overbank deposits of moderate to low permeability. As deposition proceeded, increased structural relief constrained the channels, resulting in narrower sand body width and relatively abrupt channel terminations against very low permeability siliceous shale. With post-Miocene uplift and differential compaction, stratigraphic mounding of sand bodies helped create structural domes such as the 24Z reservoir. Stratigraphic traps including the 26R reservoir were also created. Such traps vary in seal quality from very effective to leaky, depending on the lateral transition from sand bodies to siliceous shale. Application of the Elk Hills turbidity model (1) provides a framework for monitoring production performance in the 24Z and Northwest Stevens waterflood projects; and for tracking gas migration into and out of the 26R reservoir, (2) helps b identify undeveloped locations in the 26R reservoir ideally suited for horizontal wells, (3) has led to the identification of two new production trends in the 29R area, and (4) makes possible the development of exploration plays in western Elk Hills.

  8. Application of turbidite facies of the Stevens Oil Zone for reservoir management, Elk Hills Field, California

    SciTech Connect

    Reid, S.A.; Thompson, T.W. ); McJannet, G.S. )

    1996-01-01

    A detailed depositional model for the uppermost sand reservoirs of the Stevens Oil Zone, Elk Hills Field, California, contains three facies: turbidite channel-fill sand bodies, overbank Sandstone and mudstone, and pelagic and hemipelagic siliceous shale. Sand bodies are the primary producing facies and consist of layered, graded sandstone with good permeability. The presence of incipient anticlines with subsea relief in the late Miocene resulted in deposition of lenticular and sinuous sand Was within structurally created channels. Relief of these structural channels was low when the earliest sand bodies were deposited, leading to a wide channel complex bounded by broad overbank deposits of moderate to low permeability. As deposition proceeded, increased structural relief constrained the channels, resulting in narrower sand body width and relatively abrupt channel terminations against very low permeability siliceous shale. With post-Miocene uplift and differential compaction, stratigraphic mounding of sand bodies helped create structural domes such as the 24Z reservoir. Stratigraphic traps including the 26R reservoir were also created. Such traps vary in seal quality from very effective to leaky, depending on the lateral transition from sand bodies to siliceous shale. Application of the Elk Hills turbidity model (1) provides a framework for monitoring production performance in the 24Z and Northwest Stevens waterflood projects; and for tracking gas migration into and out of the 26R reservoir, (2) helps b identify undeveloped locations in the 26R reservoir ideally suited for horizontal wells, (3) has led to the identification of two new production trends in the 29R area, and (4) makes possible the development of exploration plays in western Elk Hills.

  9. U.S. monthly oil production tops 8 million barrels per day for the first time since 1988

    Energy Information Administration (EIA) (indexed site)

    2014 hurricane season could lead to offshore oil, gas production shut-ins The government's weather experts are predicting a relatively mild hurricane season, but U.S. oil and natural gas production in the Gulf of Mexico could still be disrupted. The U.S. Energy Information Administration's mean estimate is that about 12 million barrels of offshore crude oil production and 30 billion cubic feet of natural gas production will go offline during the 2014 hurricane season. That's about 40 percent

  10. SUBTASK 1.7 EVALUATION OF KEY FACTORS AFFECTING SUCCESSFUL OIL PRODUCTION IN THE BAKKEN FORMATION, NORTH DAKOTA PHASE II

    SciTech Connect

    Darren D. Schmidt; Steven A. Smith; James A. Sorensen; Damion J. Knudsen; John A. Harju; Edward N. Steadman

    2011-10-31

    Production from the Bakken and Three Forks Formations continues to trend upward as forecasts predict significant production of oil from unconventional resources nationwide. As the U.S. Geological Survey reevaluates the 3.65 billion bbl technically recoverable estimate of 2008, technological advancements continue to unlock greater unconventional oil resources, and new discoveries continue within North Dakota. It is expected that the play will continue to expand to the southwest, newly develop in the northeastern and northwestern corners of the basin in North Dakota, and fully develop in between. Although not all wells are economical, the economic success rate has been near 75% with more than 90% of wells finding oil. Currently, only about 15% of the play has been drilled, and recovery rates are less than 5%, providing a significant future of wells to be drilled and untouched hydrocarbons to be pursued through improved stimulation practices or enhanced oil recovery. This study provides the technical characterizations that are necessary to improve knowledge, provide characterization, validate generalizations, and provide insight relative to hydrocarbon recovery in the Bakken and Three Forks Formations. Oil-saturated rock charged from the Bakken shales and prospective Three Forks can be produced given appropriate stimulation treatments. Highly concentrated fracture stimulations with ceramic- and sand-based proppants appear to be providing the best success for areas outside the Parshall and Sanish Fields. Targeting of specific lithologies can influence production from both natural and induced fracture conductivity. Porosity and permeability are low, but various lithofacies units within the formation are highly saturated and, when targeted with appropriate technology, release highly economical quantities of hydrocarbons.

  11. Carbon Capture and Sequestration (via Enhanced Oil Recovery) from a Hydrogen Production Facility in an Oil Refinery

    SciTech Connect

    Stewart Mehlman

    2010-06-16

    The project proposed a commercial demonstration of advanced technologies that would capture and sequester CO2 emissions from an existing hydrogen production facility in an oil refinery into underground formations in combination with Enhanced Oil Recovery (EOR). The project is led by Praxair, Inc., with other project participants: BP Products North America Inc., Denbury Onshore, LLC (Denbury), and Gulf Coast Carbon Center (GCCC) at the Bureau of Economic Geology of The University of Texas at Austin. The project is located at the BP Refinery at Texas City, Texas. Praxair owns and operates a large hydrogen production facility within the refinery. As part of the project, Praxair would construct a CO2 capture and compression facility. The project aimed at demonstrating a novel vacuum pressure swing adsorption (VPSA) based technology to remove CO2 from the Steam Methane Reformers (SMR) process gas. The captured CO2 would be purified using refrigerated partial condensation separation (i.e., cold box). Denbury would purchase the CO2 from the project and inject the CO2 as part of its independent commercial EOR projects. The Gulf Coast Carbon Center at the Bureau of Economic Geology, a unit of University of Texas at Austin, would manage the research monitoring, verification and accounting (MVA) project for the sequestered CO2, in conjunction with Denbury. The sequestration and associated MVA activities would be carried out in the Hastings field at Brazoria County, TX. The project would exceed DOE’s target of capturing one million tons of CO2 per year (MTPY) by 2015. Phase 1 of the project (Project Definition) is being completed. The key objective of Phase 1 is to define the project in sufficient detail to enable an economic decision with regard to proceeding with Phase 2. This topical report summarizes the administrative, programmatic and technical accomplishments completed in Phase 1 of the project. It describes the work relative to project technical and design activities

  12. Lubricant oil production: The proper marriage of process and catalyst technologies

    SciTech Connect

    Everett, G.L.; Suchanek, A.

    1996-12-01

    As the industry moves into the next millennium, higher product quality demands to meet the higher performance needs of modern engine technology and rising costs of traditional good quality lube crudes are driving lubricant base oil manufacturers to select hydroprocessing options versus traditional solvent refining techniques. This paper discusses how to properly select the best economic hydroprocessing technology necessary to produce high quality lubricant base oils and waxes. The economic success of such operations depends on the proper combination of process and catalyst technologies that maximizes yields of high quality products with minimum consumption of hydrogen resources and process utilities. This is particular true on the extreme end of the quality spectrum, namely, Very High Viscosity Index (VHVI) base oils and food grade white oils and waxes where there is no room for marginal product quality. Multiplicity of operations is also becoming more important as refiners try to upgrade their facilities with as little capital expense as possible, while at the same time, broaden their high valued product slate to recoup these expenses in the shortest possible payback period. Lyondell Licensing and Criterion Catalyst have put together an effective alliance based on years of development and commercial experience in both the process and catalyst areas to assist lubricant oil manufacturers in meeting these future challenges using as much existing equipment and infrastructure as is practical. Their experience will permit the proper fitting of the chemistry of hydroprocessing to make lubricant base oils to existing or new operations.

  13. Fission Product Transmutation in Mixed Radiation Fields

    SciTech Connect

    Harmon, Frank; Burgett, Erick; Starovoitova, Valeriia; Tsveretkov, Pavel

    2015-01-15

    Work under this grant addressed a part of the challenge facing the closure of the nuclear fuel cycle; reducing the radiotoxicity of lived fission products (LLFP). It was based on the possibility that partitioning of isotopes and accelerator-based transmutation on particular LLFP combined with geological disposal may lead to an acceptable societal solution to the problem of management. The feasibility of using photonuclear processes based on the excitation of the giant dipole resonance (GDR) by bremsstrahlung radiation as a cost effective transmutation method was accessed. The nuclear reactions of interest: (γ,xn), (n,γ), (γ,p) can be induced by bremsstrahlung radiation produced by high power electron accelerators. The driver of these processes would be an accelerator that produces a high energy and high power electron beam of ~ 100 MeV. The major advantages of such accelerators for this purpose are that they are essentially available “off the shelf” and potentially would be of reasonable cost for this application. Methods were examined that used photo produced neutrons or the bremsstrahlung photons only, or use both photons and neutrons in combination for irradiations of selected LLFP. Extrapolating the results to plausible engineering scale transmuters it was found that the energy cost for 129I and 99Tc transmutation by these methods are about 2 and 4%, respectively, of the energy produced from 1000MWe.

  14. Interpretation of the magnetic anomaly over the Omaha Oil Field, Gallatin County, Illinois

    SciTech Connect

    Sparlin, M.A. ); Lewis, R.D. . Waterways Experiment Station)

    1994-07-01

    A 40 nanoTesla (nT) magnetic anomaly identified in an aeromagnetic survey over southern Illinois contours as a localized magnetic high on the west flank of a regional magnetic low. This magnetic anomaly is generally coincident with the Omaha Oil Field in northwest Gallatin County, Illinois. It was initially assumed that cultural sources of steel associated with this oil field were the primary source of the magnetic feature; however, similar oil fields overflown by the survey do not exhibit magnetic anomalies in the data set. The Luther Rister et ux [number sign]1 well, drilled near the apex of the Omaha structural dome, encountered two zones of ultramafic intrusive rock containing 9.0% by volume magnetite. These intrusives were identified to be alnoeites which are a class of mantle-derived ultramafic rock that can be associated with the incipient stages of crustal rifting. A ground magnetic survey verified the presence of the anomaly, and provided detailed data for 3-D modeling of the source. Petrophysical evaluations, magnetic susceptibility measurements and thin section modal analysis were made on drill cuttings from the ultramafic intrusives encountered in the Luther Rister [number sign]1 well. These measurements were made to constrain the 3-D magnetic modeling by the petrophysical characteristics of the source. After removal of the regional magnetic field, the resulting 140 nT residual magnetic anomaly was successfully modeled using two ultramafic sills with an igneous feeder plug. The two igneous sills adequately account for the structural closure exhibited in the Omaha Oil Field and raise the interesting possibility of other hydrocarbon trapping structures generated by intrusives emplaced into the sedimentary section.

  15. U.S. monthly oil production tops 8 million barrels per day for the first time since 1988

    Energy Information Administration (EIA) (indexed site)

    to account for 91% of the growth in world oil production in 2015 The United States is expected to provide nine out of every 10 barrels of new global oil supplies in 2015. In its new forecast, the U.S. Energy Information Administration said it expects world oil production to rise by 1.3 million barrels per day next year....with U.S. daily oil output alone increasing by 1.2 million barrels. Rising U.S. oil production, along with more fuel-efficient vehicles on America's highways, is expected to

  16. Economics of on-farm production and use of vegetable oils for fuel

    SciTech Connect

    McIntosh, C.S.; Withers, R.V.; Smith, S.M.

    1982-01-01

    The technology of oilseed processing, on a small scale, is much simpler than that for ethanol production. This, coupled with the fact that most energy intensive farm operations use diesel powered equipment, has created substantial interest in vegetable oils as an alternative source of liquid fuel for agriculture. The purpose of this study was to estimate the impact on gross margins resulting from vegetable oil production and utilization in two case study areas, Latah and Power Counties, in Iadho. The results indicate that winter rape oil became a feasible alternative to diesel when the price of diesel reached $0.84 per liter in the Latah County model. A diesel price of $0.85 per liter was required in the Power County model before it became feasible to produce sunflower oil for fuel. 5 tables.

  17. World Oil Prices and Production Trends in AEO2008 (released in AEO2008)

    Reports and Publications

    2008-01-01

    Annual Energy Outlook 2008 (AEO) defines the world oil price as the price of light, low-sulfur crude oil delivered in Cushing, Oklahoma. Since 2003, both "above ground" and "below ground" factors have contributed to a sustained rise in nominal world oil prices, from $31 per barrel in 2003 to $69 per barrel in 2007. The AEO2008 reference case outlook for world oil prices is higher than in the AEO2007 reference case. The main reasons for the adoption of a higher reference case price outlook include continued significant expansion of world demand for liquids, particularly in non-OECD (Organization for Economic Cooperation and Development) countries, which include China and India; the rising costs of conventional non-OPEC (Organization of the Petroleum Exporting Countries) supply and unconventional liquids production; limited growth in non-OPEC supplies despite higher oil prices; and the inability or unwillingness of OPEC member countries to increase conventional crude oil production to levels that would be required for maintaining price stability. The Energy Information Administration will continue to monitor world oil price trends and may need to make further adjustments in future AEOs.

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

    SciTech Connect

    Riley, Ronald; Wicks, John; Perry, Christopher

    2009-12-30

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian “Clinton” sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test (“Huff-n-Puff”) was conducted on a well in Stark County to test the injectivity in a “Clinton”-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day “soak” period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the “Clinton” sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent

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

    SciTech Connect

    Ronald Riley; John Wicks; Christopher Perry

    2009-12-30

    The purpose of this study was to evaluate the efficacy of using CO2-enhanced oil recovery (EOR) in the East Canton oil field (ECOF). Discovered in 1947, the ECOF in northeastern Ohio has produced approximately 95 million barrels (MMbbl) of oil from the Silurian 'Clinton' sandstone. The original oil-in-place (OOIP) for this field was approximately 1.5 billion bbl and this study estimates by modeling known reservoir parameters, that between 76 and 279 MMbbl of additional oil could be produced through secondary recovery in this field, depending on the fluid and formation response to CO2 injection. A CO2 cyclic test ('Huff-n-Puff') was conducted on a well in Stark County to test the injectivity in a 'Clinton'-producing oil well in the ECOF and estimate the dispersion or potential breakthrough of the CO2 to surrounding wells. Eighty-one tons of CO2 (1.39 MMCF) were injected over a 20-hour period, after which the well was shut in for a 32-day 'soak' period before production was resumed. Results demonstrated injection rates of 1.67 MMCF of gas per day, which was much higher than anticipated and no CO2 was detected in gas samples taken from eight immediately offsetting observation wells. All data collected during this test was analyzed, interpreted, and incorporated into the reservoir characterization study and used to develop the geologic model. The geologic model was used as input into a reservoir simulation performed by Fekete Associates, Inc., to estimate the behavior of reservoir fluids when large quantities of CO2 are injected into the 'Clinton' sandstone. Results strongly suggest that the majority of the injected CO2 entered the matrix porosity of the reservoir pay zones, where it diffused into the oil. Evidence includes: (A) the volume of injected CO2 greatly exceeded the estimated capacity of the hydraulic fracture and natural fractures; (B) there was a gradual injection and pressure rate build-up during the test; (C) there was a subsequent, gradual flashout of

  20. EIA - Analysis of Crude Oil Production in the Arctic National Wildlife

    Energy Information Administration (EIA) (indexed site)

    Refuge Refuge Analysis of Crude Oil Production in the Arctic National Wildlife Refuge This report responds to a request from Senator Ted Stevens that the Energy Information Administration provide an assessment of Federal oil and natural gas leasing in the coastal plain of the Arctic National Wildlife Refuge (ANWR) in Alaska. Excel Spreadsheets Reference Reference. Need help, contact the National Energy Information Center at 202-586-8800. Mean ANWR Resource Mean ANWR Resource. Need help,

  1. EIA - Analysis of Crude Oil Production in the Arctic National Wildlife

    Energy Information Administration (EIA) (indexed site)

    Refuge - Contacts Contacts Analysis of Crude Oil Production in the Arctic National Wildlife Refuge Contacts This report was prepared by the staff of the Office of Integrated Analysis and Forecasting, Energy Information Administration (EIA). General questions concerning the report can be directed to John Conti (john.conti@eia.doe.gov, 202/586-2222), Director of the Office of Integrated Analysis and Forecasting, and Michael Schaal (michael.schaal@eia.doe.gov, 202/586-5590), Director of the Oil

  2. EIA - Analysis of Crude Oil Production in the Arctic National Wildlife

    Energy Information Administration (EIA) (indexed site)

    Refuge - Introduction Introduction Analysis of Crude Oil Production in the Arctic National Wildlife Refuge Introduction On December 6, 2007, Senator Ted Stevens requested that the Energy Information Administration (EIA) provide an assessment of Federal oil and natural gas leasing in the coastal plain of the Arctic National Wildlife Refuge (ANWR) in Alaska (Appendix A). In his request, Senator Stevens said that the analysis should develop "plausible scenarios for development of the Coast

  3. EIA - Analysis of Crude Oil Production in the Arctic National Wildlife

    Energy Information Administration (EIA) (indexed site)

    Refuge - Preface Preface Analysis of Crude Oil Production in the Arctic National Wildlife Refuge Preface On December 6, 2007, Senator Ted Stevens requested that the Energy Information Administration (EIA) provide an assessment of Federal oil and natural gas leasing in the coastal plain of the Arctic National Wildlife Refuge (ANWR) in Alaska (Appendix A). This report responds to that request. The legislation that established EIA in 1977 vested the organization with a degree of statutory

  4. The use of Devonian oil shales in the production of portland cement

    SciTech Connect

    Schultz, C.W.; Lamont, W.E.; Daniel, J.

    1991-12-31

    The Lafarge Corporation operates a cement plant at Alpena, Michigan in which Antrim shale, a Devonian oil shale, is used as part of the raw material mix. Using this precedent the authors examine the conditions and extent to which spent shale might be utilized in cement production. They conclude that the potential is limited in size and location but could provide substantial benefit to an oil shale operation meeting these criteria.

  5. The use of Devonian oil shales in the production of portland cement

    SciTech Connect

    Schultz, C.W.; Lamont, W.E. ); Daniel, J. )

    1991-01-01

    The Lafarge Corporation operates a cement plant at Alpena, Michigan in which Antrim shale, a Devonian oil shale, is used as part of the raw material mix. Using this precedent the authors examine the conditions and extent to which spent shale might be utilized in cement production. They conclude that the potential is limited in size and location but could provide substantial benefit to an oil shale operation meeting these criteria.

  6. Kepiting field production/storage barge; Design, installation, and operation

    SciTech Connect

    Carl, A.C.; Satar, S. ); Liles, S.P. )

    1990-04-01

    The Kepiting field is located in 295 ft (90 m) of water in the Natuna Sea, Indonesia. Development of this two-well field required innovative planning and involved unique designs of producing systems. The plan includes seafloor wells tied back to a spread-anchored, purpose-built, oil-process and -storage barge. The barge is designed to handle four producing wells and to process 10,000 B/D (1590 m{sup 3}/d) well fluid and 10 million scf/D (283 {times} 10{sup 3} std m{sup 3}/d) gas. Excess gas beyond barge-fuel needs and artificial-lift requirements is flared on the barge. Heated oil storage for 53,000 bbl (8430 m{sup 3}) is available. Processed crude is transported from the barge to a floating export terminal by a shuttle tanker. Kepiting field was operated profitably from Oct. 27, 1986, to Aug. 8, 1989, at which time the wells were plugged and the tieback risers disconnected. This paper discusses the design and construction of the barge and the operating philosophy and experience.

  7. Fluid and Rock Property Controls On Production And Seismic Monitoring Alaska Heavy Oils

    SciTech Connect

    Liberatore, Matthew; Herring, Andy; Prasad, Manika; Dorgan, John; Batzle, Mike

    2012-10-30

    The goal of this project is to improve recovery of Alaskan North Slope (ANS) heavy oil resources in the Ugnu formation by improving our understanding of the formation's vertical and lateral heterogeneities via core evaluation, evaluating possible recovery processes, and employing geophysical monitoring to assess production and modify production operations.

  8. Flexible riser and mooring system develops small oil fields in the North Sea

    SciTech Connect

    Thompson, A.M.; Holmes, G. ); Benstead, P.J. )

    1991-11-01

    This paper reports on the flexible riser and mooring system (FRAMS) which provides a technically straightforward, commercially attractive method of developing small oil fields. A passively moored 60,000-deadweight-ton (60,000-DWT) tanker with deck-mounted equipment provides a swivelless well fluid and injection water path from and to the wellheads. The system can be disconnected rapidly in severe weather.

  9. Risk assessment of nonhazardous oil-field waste disposal in salt caverns.

    SciTech Connect

    Elcock, D.

    1998-03-05

    In 1996, Argonne National Laboratory (ANL) conducted a preliminary technical and legal evaluation of disposing of nonhazardous oil-field wastes (NOW) into salt caverns. Argonne determined that if caverns are sited and designed well, operated carefully, closed properly, and monitored routinely, they could be suitable for disposing of oil-field wastes. On the basis of these findings, Argonne subsequently conducted a preliminary evaluation of the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from the NOW disposed of in domal salt caverns. Steps used in this evaluation included the following: identifying potential contaminants of concern, determining how humans could be exposed to these contaminants, assessing contaminant toxicities, estimating contaminant intakes, and calculating human cancer and noncancer risk estimates. Five postclosure cavern release scenarios were assessed. These were inadvertent cavern intrusion, failure of the cavern seal, failure of the cavern through cracks, failure of the cavern through leaky interbeds, and a partial collapse of the cavern roof. Assuming a single, generic, salt cavern and generic oil-field wastes, potential human health effects associated with constituent hazardous substances (arsenic, benzene, cadmium, and chromium) were assessed under each of these scenarios. Preliminary results provided excess cancer risk and hazard index (referring to noncancer health effects) estimates that were well within the US Environmental Protection Agency (EPA) target range for acceptable exposure risk levels. These results led to the preliminary conclusion that from a human health perspective, salt caverns can provide an acceptable disposal method for nonhazardous oil-field wastes.

  10. Disposal of NORM-Contaminated Oil Field Wastes in Salt Caverns

    SciTech Connect

    Blunt, D.L.; Elcock, D.; Smith, K.P.; Tomasko, D.; Viel, J.A.; and Williams, G.P.

    1999-01-21

    In 1995, the U.S. Department of Energy (DOE), Office of Fossil Energy, asked Argonne National Laboratory (Argonne) to conduct a preliminary technical and legal evaluation of disposing of nonhazardous oil field waste (NOW) into salt caverns. That study concluded that disposal of NOW into salt caverns is feasible and legal. If caverns are sited and designed well, operated carefully, closed properly, and monitored routinely, they can be a suitable means of disposing of NOW (Veil et al. 1996). Considering these findings and the increased U.S. interest in using salt caverns for NOW disposal, the Office of Fossil Energy asked Argonne to conduct further research on the cost of cavern disposal compared with the cost of more traditional NOW disposal methods and on preliminary identification and investigation of the risks associated with such disposal. The cost study (Veil 1997) found that disposal costs at the four permitted disposal caverns in the United States were comparable to or lower than the costs of other disposal facilities in the same geographic area. The risk study (Tomasko et al. 1997) estimated that both cancer and noncancer human health risks from drinking water that had been contaminated by releases of cavern contents were significantly lower than the accepted risk thresholds. Since 1992, DOE has funded Argonne to conduct a series of studies evaluating issues related to management and disposal of oil field wastes contaminated with naturally occurring radioactive material (NORM). Included among these studies were radiological dose assessments of several different NORM disposal options (Smith et al. 1996). In 1997, DOE asked Argonne to conduct additional analyses on waste disposal in salt caverns, except that this time the wastes to be evaluated would be those types of oil field wastes that are contaminated by NORM. This report describes these analyses. Throughout the remainder of this report, the term ''NORM waste'' is used to mean ''oil field waste

  11. Estimated human health risks of disposing of nonhazardous oil field waste in salt caverns

    SciTech Connect

    Tomasko, D.; Elcock, D.; Veil, J.

    1997-09-01

    Argonne National Laboratory (ANL) has completed an evaluation of the possibility that adverse human health effects (carcinogenic and noncarcinogenic) could result from exposure to contaminants released from nonhazardous oil field wastes (NOW) disposed in domal salt caverns. In this assessment, several steps were used to evaluate potential human health risks: identifying potential contaminants of concern, determining how humans could be exposed to these contaminants, assessing the contaminants` toxicities, estimating contaminant intakes, and, finally, calculating human cancer and noncancer risks.

  12. Western states enhanced oil shale recovery program: Shale oil production facilities conceptual design studies report

    SciTech Connect

    Not Available

    1989-08-01

    This report analyzes the economics of producing syncrude from oil shale combining underground and surface processing using Occidental's Modified-In-Situ (MIS) technology and Lawrence Livermore National Laboratory's (LLNL) Hot Recycled Solids (HRS) retort. These retorts form the basic technology employed for oil extraction from oil shale in this study. Results are presented for both Commercial and Pre-commercial programs. Also analyzed are Pre-commercialization cost of Demonstration and Pilot programs which will confirm the HRS and MIS concepts and their mechanical designs. These programs will provide experience with the circulating Fluidized Bed Combustor (CFBC), the MIS retort, the HRS retort and establish environmental control parameters. Four cases are considered: commercial size plant, demonstration size plant, demonstration size plant minimum CFBC, and a pilot size plant. Budget cost estimates and schedules are determined. Process flow schemes and basic heat and material balances are determined for the HRS system. Results consist of summaries of major equipment sizes, capital cost estimates, operating cost estimates and economic analyses. 35 figs., 35 tabs.

  13. Biocompetitive exclusion technology: A field system to control reservoir souring and increasing production

    SciTech Connect

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

    1995-12-31

    Biogenic formation of sulfide in reservoirs by Sulfate Reducing Bacteria (SRB) causes serious plugging, corrosion, and environmental safety problems. The production of sulfide can be decreased, and its concentration reduced, by the establishment and growth of an indigenous microbial population which results in a replacement of the SRB population. This approach to modify the reservoir ecology utilizing preexisting carbon sources coupled with the introduction of an alternate electron acceptor forms the basis of a new Biocompetitive Exclusion technology which has the potential to enhance oil recovery and decrease paraffin deposition and corrosion. Preliminary field results from an ongoing DOE-sponsored research program will be discussed.

  14. Clay mineralogy and its controls on production, Pennsylvanian upper Morrow sandstone, Farnsworth field, Ochiltree County, Texas

    SciTech Connect

    Munson, T.W. )

    1989-12-01

    Farnsworth field in Ochiltree County, Texas, is the most prolific upper Morrow oil field in the Anadarko basin, producing more than 36 million bbl of oil and 27 billion ft{sup 3} of gas since its discovery in 1955. The bulk of the production comes from an upper Morrow-aged sandstone locally referred to as the Buckhaults sandstone. The Buckhaults sandstone is a coarse to very coarse-grained, arkose to arkosic wacke. Grain-size distributions, sedimentary structure analysis, and sand-body geometry indicate that the Buckhaults was deposited in a fluvial-deltaic environment as distributary channel and distributary mouth-bar sands. Depositional strike is northwest to southeast. The source area for the Buckhaults sediments was primarily a plutonic igneous terrane, with a minor contribution from volcanic and reworked sedimentary rocks. The proposed source area is the Amarillo-Wichita uplift to the south. In addition, the Cimarron arch and/or Keyes dome to the west-northwest may also have contributed sediment to the study area. The large (average) grain size, the amount of feldspar present, and the overall immaturity of the Buckhaults sediments indicate a relatively short distance of transport. Detailed scanning electron microscopy and x-ray diffraction analysis of cores from the productive interval coupled with comparisons of varying completion practices across the field indicate a significant correlation between individual well performance, clay mineralogy, and completion technique.

  15. Revitalizing mature miocene reservoirs in NE Anzoategui: A sequence stratigraphic perspective in the Quiamare and La Celba oil fields

    SciTech Connect

    Galeazzi, S.; Paredes, S.; Dellape, D.; Moroder, G.

    1996-08-01

    A large proportion of the oil reserves discovered in NE Anzoategui are contained in the 3000-m-thick Lower to Middle Miocene strata of the Oficina Formation. Light oil and gas are contained in multiple sandstone reservoirs. Most producing zones are isolated by shale separators, and feature independent fluid contacts. Individual producing zones are laterally extensive, but locally they show interruptions and considerable internal heterogeneity. Reservoir compartmentalization is due to second or third order accommodation faulting and stratigraphic terminations. Sandstones yielding commercial production range in thicknesses from 10 to 50 ft, and contain intergranular porosities that vary from 6 to 24%. Conjugate-type subvertical fractures locally provide the difference between commercial and non-commercial flow rates in low porosity sandstones. Typically, drive style varies from dissolved gas drive and gas cap expansion to natural water drive where unaltered oil coexists with meteoric water. The Miocene series are widespread deposits represented by two major transgressive-regressive genetic packages. Observation of facies, parasequence stacking and stratal termination patterns suggests the presence of at least ten depositional sequences. Strata patterns, lithologic and paleontologic criteria indicate that sedimentation took place within a low relief (ramp-type) depositional setting, in depositional environments ranging from coastal plain through estuarine and shallow marine. Individual producing zones represent a variety of systems tracts, which include transgressive systems tracts, lowstand prograding complexes, and less commonly incised valley fill and highstand deposits. A sequence stratigraphic analysis of the reservoirs in the mature Quiamare oil field has led to the delineation and development of important additional shallow reserves.

  16. CO2 Storage and Enhanced Oil Recovery: Bald Unit Test Site, Mumford Hills Oil Field, Posey County, Indiana

    SciTech Connect

    Frailey, Scott M.; Krapac, Ivan G.; Damico, James R.; Okwen, Roland T.; McKaskle, Ray W.

    2012-03-30

    The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO2) injection test in a sandstone within the Clore Formation (Mississippian System, Chesterian Series) in order to gauge the large-scale CO2 storage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via miscible liquid CO2 flooding.

  17. An integrated approach to seismic stimulation of oil reservoirs: laboratory, field and theoretical results from DOE/industry collaborations.

    SciTech Connect

    Roberts, P. M.; Majer, Ernest Luther; Lo, W. C.; Sposito, Garrison,; Daley, T. M.

    2003-01-01

    It has been observed repeatedly that low-frequency (10-500 Hz) seismic stress waves can enhance oil production from depleted reservoirs . Until recently, the majority of these observations have been anecdotal or at the proof-of-concept level. The physics coupling stress waves to multiphase fluid flow behavior in porous media is still poorly understood, even though numerous underlying physical mechanisms have been proposed to explain the observations . Basic research on the phenomenon is being conducted through a U .S. Department of Energy funded collaboration between Lawrence Berkeley National Laboratory, the University of California at Berkeley, Los Alamos National Laboratory and the U .S . oil and gas industry . The project has focused on three main areas of research: (1) laboratory core flow experiments, (2) field seismic monitoring of downhole stimulation tests, and (3) theoretical modeling of the coupled stress/flow phenomenon . The major goal is to obtain a comprehensive scientific understanding of the seismic stimulation phenomenon so that field application technologies can be improved. Initial developments and experimental results in all three research focus areas confirm historic observations that the stimulated flow phenomenon is real and that a fundamental scientific understanding can be obtained through continued research . Examples of project results and developments are presented here.

  18. DOE-Sponsored Field Test Demonstrates Viability of Simultaneous CO2 Storage and Enhanced Oil Recovery in Carbonate Reservoirs

    Energy.gov [DOE]

    A field test conducted by a U.S. Department of Energy team of regional partners has demonstrated that using carbon dioxide in an enhanced oil recovery method dubbed "huff-and-puff" can help assess the carbon sequestration potential of geologic formations while tapping America's valuable oil resources.

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

    SciTech Connect

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

    1997-04-10

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

  20. Utah Crude Oil + Lease Condensate New Reservoir Discoveries in Old Fields

    Energy Information Administration (EIA) (indexed site)

    (Million Barrels) New Reservoir Discoveries in Old Fields (Million Barrels) Decade Year-0 Year-1 Year-2 Year-3 Year-4 Year-5 Year-6 Year-7 Year-8 Year-9 2000's 0 2010's 0 0 0 0 0 - = No Data Reported; -- = Not Applicable; NA = Not Available; W = Withheld to avoid disclosure of individual company data. Release Date: 11/19/2015 Next Release Date: 12/31/2016 Referring Pages: Crude Oil plus Lease Condensate New Reservoir Discoveries in Old Fields

  1. ,"U.S. Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels)"

    Energy Information Administration (EIA) (indexed site)

    New Field Discoveries (Million Barrels)" ,"Click worksheet name or tab at bottom for data" ,"Worksheet Name","Description","# Of Series","Frequency","Latest Data for" ,"Data 1","U.S. Crude Oil + Lease Condensate Reserves New Field Discoveries (Million Barrels)",1,"Annual",2014 ,"Release Date:","11/19/2015" ,"Next Release Date:","12/31/2016" ,"Excel File

  2. U.S. monthly oil production tops 8 million barrels per day for the first time since 1988

    Energy Information Administration (EIA) (indexed site)

    Snow and cold cut into U.S. crude oil production this winter This winter's harsh weather conditions temporarily slowed U.S. crude oil production. In its new forecast....the U.S. Energy Information Administration said oil production in the Bakken formation in North Dakota and Montana hit 1 million barrels per day last November. However, winter storms caused a drop in the oil output from the Bakken formation during December. Production in the Bakken region is forecast to return to 1 million

  3. Applications of EOR (enhanced oil recovery) technology in field projects--1990 update

    SciTech Connect

    Pautz, J.F.; Thomas, R.D.

    1991-01-01

    Trends in the type and number of US enhanced oil recovery (EOR) projects are analyzed for the period from 1980 through 1989. The analysis is based on current literature and news media and the Department of Energy (DOE) EOR Project Data Base, which contains information on over 1,348 projects. The characteristics of the EOR projects are grouped by starting date and process type to identify trends in reservoir statistics and applications of process technologies. Twenty-two EOR projects starts were identified for 1989 and ten project starts for 1988. An obvious trend over recent years has been the decline in the number of project starts since 1981 until 1988 which corresponds to the oil price decline during that period. There was a modest recovery in 1989 of project starts, which lags the modest recovery of oil prices in 1987 that was reconfirmed in 1989. During the time frame of 1980 to 1989, there has been a gradual improvement in costs of operation for EOR technology. The perceived average cost of EOR has gone down from a $30/bbl range to low $20/bbl. These costs of operation seems to stay just at the price of oil or slightly above to result in marginal profitability. The use of polymer flooding has drastically decreased both in actual and relative numbers of project starts since the oil price drop in 1986. Production from polymer flooding is down more than 50%. Long-term plans for large, high-cost projects such as CO{sub 2} flooding in West Texas, steamflooding in California, and hydrocarbon flooding on the North Slope have continued to be implemented. EOR process technologies have been refined to be more cost effective as shown by the continued application and rising production attributable to EOR. 8 refs., 6 figs., 13 tabs.

  4. Increased oil production and reserves utilizing secondary/tertiary recovery techniques on small reservoirs in the Paradox basin, Utah. Annual report

    SciTech Connect

    Chidsey, T.C. Jr.

    1997-02-01

    The Paradox basin of Utah, Colorado, and Arizona contains nearly 100 small oil fields producing from carbonate buildups or mounds within the Pennsylvanian (Desmoinesian) Paradox Formation. These fields typically have one to four wells with primary production ranging from 700,000 to 2,000,000 barrels of oil per field at a 15 to 20% recovery rate. At least 200 million barrels of oil is at risk of being unrecovered in these small fields because of inefficient recovery practices and undrained heterogeneous reservoirs. Five fields (Anasazi, mule, Blue Hogan, heron North, and Runway) within the Navajo Nation of southeastern utah are being evaluated for waterflood or carbon-dioxide-miscible flood projects based upon geological characterization and reservoir modeling. The results can be applied to other fields in the Paradox basin and the Rocky Mountain region, the Michigan and Illinois basins, and the Midcontinent. The reservoir engineering component of the work completed to date included analysis of production data and well tests, comprehensive laboratory programs, and preliminary mechanistic reservoir simulation studies. A comprehensive fluid property characterization program was completed. Mechanistic reservoir production performance simulation studies were also completed.

  5. Spot Prices for Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    0/07/16 10/14/16 10/21/16 10/28/16 11/04/16 11/11/16 View History Crude Oil WTI - Cushing, Oklahoma 49.48 50.29 50.56 49.36 45.51 44.61 1986-2016 Brent - Europe 49.52 49.94 50.33 48.95 44.63 43.09 1987-2016 Conventional Gasoline New York Harbor, Regular 1.506 1.503 1.549 1.534 1.529 1.459 1986-2016 U.S. Gulf Coast, Regular 1.517 1.501 1.500 1.454 1.393 1.273 1986-2016 RBOB Regular Gasoline Los Angeles 1.647 1.581 1.631 1.625 1.662 1.502 2003-2016 No. 2 Heating Oil New York Harbor 1.496 1.499

  6. Residual-oil-saturation-technology test, Bell Creek Field, Montana. Final report

    SciTech Connect

    Not Available

    1981-06-01

    A field test was conducted of the technology available to measure residual oil saturation following waterflood secondary oil recovery processes. The test was conducted in a new well drilled solely for that purpose, located immediately northwest of the Bell Creek Micellar Polymer Pilot. The area where the test was conducted was originally drilled during 1968, produced by primary until late 1970, and was under line drive waterflood secondary recovery until early 1976, when the area was shut in at waterflood depletion. This report presents the results of tests conducted to determine waterflood residual oil saturation in the Muddy Sandstone reservoir. The engineering techniques used to determine the magnitude and distribution of the remaining oil saturation included both pressure and sidewall cores, conventional well logs (Dual Laterolog - Micro Spherically Focused Log, Dual Induction Log - Spherically Focused Log, Borehole Compensated Sonic Log, Formation Compensated Density-Compensated Neutron Log), Carbon-Oxygen Logs, Dielectric Logs, Nuclear Magnetism Log, Thermal Decay Time Logs, and a Partitioning Tracer Test.

  7. A Fuzzy Feed-Forward/Feedback Control System for a Three-Phase Oil Field Centrifuge.

    SciTech Connect

    Parkinson, W. J. ,; Smith, R. E.; Mortensen, F. N.; Wantuck, P. J.; Ross, Timothy J.; Jamshidi, Mohammad; Miller, N.

    2002-01-01

    A set of fuzzy controllers was designed and applied to a commercial three-phase oil field centrifuge. This centrifuge is essentially a one of a kind unit. It is used to recover oil from tank bottoms and oil field and/or refinery sludge. It is unique because it can separate oily emulsions into three separate phases, oil, water, and solids, in one operation. The centrifuge is a large but portable device. It is moved form site to site and is used to separate a large variety of waste emulsions. The centrifuge feedstock varies significantly from site to site and often varies significantly during the daily operation. In this application, fuzzy logic was used on a class of problems not easily solved by classical control techniques. The oil field centrifuge is a highly nonlinear system, with a time varying input. We have been unable to develop a physical-mathematical model of the portion of the centrifuge operation that actually separates the oil, water, and solids. For this portion of the operation we developed a fuzzy feedback control system that modeled a skilled operator's knowledge and actions as opposed to the physical model of the centrifuge itself. Because of the variable feed we had to develop a feed-forward controller that would sense and react to feed changes prior to the time that the actual change reached the centrifuge separation unit. This portion of the control system was also a fuzzy controller designed around the knowledge of a skilled operator. In addition to the combined feed-forward and feedback control systems, we developed a soft-sensor that was used to determine the value of variables needed for the feed-forward control system. These variables could not actually be measured but were calculated from the measurement of other variables. The soft-sensor was developed with a combination of a physical model of the feed system and a skilled operator's expert knowledge. Finally the entire control system is tied together with a fuzzy-SPC (Statistical Process

  8. Biological treatment process for removing petroleum hydrocarbons from oil field produced waters

    SciTech Connect

    Tellez, G.; Khandan, N.

    1995-12-31

    The feasibility of removing petroleum hydrocarbons from oil fields produced waters using biological treatment was evaluated under laboratory and field conditions. Based on previous laboratory studies, a field-scale prototype system was designed and operated over a period of four months. Two different sources of produced waters were tested in this field study under various continuous flow rates ranging from 375 1/D to 1,800 1/D. One source of produced water was an open storage pit; the other, a closed storage tank. The TDS concentrations of these sources exceeded 50,000 mg/l; total n-alkanes exceeded 100 mg/l; total petroleum hydrocarbons exceeded 125 mg/l; and total BTEX exceeded 3 mg/l. Removals of total n-alkanes, total petroleum hydrocarbons, and BTEX remained consistently high over 99%. During these tests, the energy costs averaged $0.20/bbl at 12 bbl/D.

  9. Venezuela offshore oil and gas production development: Past, present and future

    SciTech Connect

    Perez La Salvia, H.; Schwartz, E.; Contreras, M.; Rodriguez, J.I.; Febres, G.; Gajardo, E.

    1995-12-01

    This paper presents a short history of offshore oil and gas production in Venezuela starting in Lake Maracaibo in 1923. The main emphasis has been the results of the recent R and D and the exploratory offshore programs in areas like Orinoco Delta located in the Atlantic Ocean, Northeast and Northwest Venezuela in the Caribbean sea. In the R and D offshore program the main objectives were: (1) To establish the local environmental, oceanographical, geotechnical and seismicity conditions for the Venezuelan Continental Platform. (2) To give a technical support to the PDVSA Operating Affiliates during the exploratory programs including: (a) to develop accurate drilling vessel positioning systems; (b) evaluation of sea bottom geotechnical conditions for safely operating the jack-ups and drilling vessels involved in the exploratory wells and (c) to identify those areas which because of their special nature require further investigation to establish preliminary type of platforms required for the areas to be developed or to evaluate other solutions proposed by Foreign Consultant Engineering Companies to the PDVSA Operating Affiliated Companies. The main objective of PDVSA for the coming future will be to develop the North of Paria Gas Field through the initially named Christopher Columbus Project now Sucre Gas, S.A., a consortium conformed by LaGoven, S.A. Shell, Exxon and Mitsubishi. objective of this paper is to give an idea of the history of the Venezuelan Oil and Gas Offshore development giving emphasis to the results of the INTEVEP S.A. Red offshore program and to show some results of the particular characteristics of oceanographical, environmental, geotechnical and seismic conditions in the main areas evaluated during the exploratory program: Orinoco Delta, Gulf of Paria and North of Paria.

  10. U.S. Domestic Oil Production Exceeds Imports for First Time in 18 Years |

    Office of Energy Efficiency and Renewable Energy (EERE) (indexed site)

    Department of Energy Domestic Oil Production Exceeds Imports for First Time in 18 Years U.S. Domestic Oil Production Exceeds Imports for First Time in 18 Years November 15, 2013 - 3:47pm Addthis Source: Energy Information Administration Short Term Energy Outlook. Chart by Daniel Wood. Allison Lantero Allison Lantero Digital Content Specialist, Office of Public Affairs In February 1995, The Brady Bunch Movie and Billy Madison were in movie theaters, "Creep" by TLC was at the top of

  11. Corrosion-resistant alloy products for oil and gas industries by the HIP clad process

    SciTech Connect

    Bishop, M.

    1984-10-01

    Sour gas wells, which have extremely corrosive environments, are occurring more and more frequently as oil companies are forced to drill deeper wells to find new reserves. This places a premium on tubular goods and wellhead components that can withstand the hydrogen sulfide (H/sub 2/S), brine, and sulphur found in sour gas. The oil industry is currently injecting water or oil-base inhibitors into the bottom of the wells to prevent corrosion of the tubulars and wellhead components. The inhibitor coats the steel, as it flows upward with the oil or gas, protecting it from corrosion. Unfortunately, it is often uneconomical to transport inhibitors to offshore rigs, and high temperature wells can cause the inhibitors to break down and render them useless. Because of these problems, products made from corrosion-resistant alloys are being developed and tested. One of the most important developments in this area is the use of cladding.

  12. COUPLING THE ALKALINE-SURFACTANT-POLYMER TECHNOLOGY AND THE GELATION TECHNOLOGY TO MAXIMIZE OIL PRODUCTION

    SciTech Connect

    Malcolm Pitts; Jie Qi; Dan Wilson

    2004-10-01

    Gelation technologies have been developed to provide more efficient vertical sweep efficiencies for flooding naturally fractured oil reservoirs or more efficient areal sweep efficiency for those with high permeability contrast ''thief zones''. The field proven alkaline-surfactant-polymer technology economically recovers 15% to 25% OOIP more oil than waterflooding from swept pore space of an oil reservoir. However, alkaline-surfactant-polymer technology is not amenable to naturally fractured reservoirs or those with thief zones because much of injected solution bypasses target pore space containing oil. This work investigates whether combining these two technologies could broaden applicability of alkaline-surfactant-polymer flooding into these reservoirs. A prior fluid-fluid report discussed interaction of different gel chemical compositions and alkaline-surfactant-polymer solutions. Gel solutions under dynamic conditions of linear corefloods showed similar stability to alkaline-surfactant-polymer solutions as in the fluid-fluid analyses. Aluminum-polyacrylamide, flowing gels are not stable to alkaline-surfactant-polymer solutions of either pH 10.5 or 12.9. Chromium acetate-polyacrylamide flowing and rigid flowing gels are stable to subsequent alkaline-surfactant-polymer solution injection. Rigid flowing chromium acetate-polyacrylamide gels maintained permeability reduction better than flowing chromium acetate-polyacrylamide gels. Silicate-polyacrylamide gels are not stable with subsequent injection of either a pH 10.5 or a 12.9 alkaline-surfactant-polymer solution. Neither aluminum citrate-polyacrylamide nor silicate-polyacrylamide gel systems produced significant incremental oil in linear corefloods. Both flowing and rigid flowing chromium acetate-polyacrylamide gels produced incremental oil with the rigid flowing gel producing the greatest amount. Higher oil recovery could have been due to higher differential pressures across cores. None of the gels tested

  13. ,"Total Crude Oil and Petroleum Products Net Receipts by Pipeline...

    Energy Information Administration (EIA) (indexed site)

    Net Receipts by Pipeline, Tanker, Barge and Rail between PAD Districts" ,"Click worksheet ... and Petroleum Products Net Receipts by Pipeline, Tanker, Barge and Rail between PAD ...

  14. Increased Oil Production and Reserves Utilizing Secondary/Tertiary Recovery Techniques on Small Reservoirs in the Paradox Basin, Utah

    SciTech Connect

    Allison, M. Lee; Chidsey, Jr., Thomas

    1999-11-03

    The primary objective of this project is to enhance domestic petroleum production by demonstration and technology transfer of an advanced oil recovery technology in the Paradox basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to about 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million bbl of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon dioxide-(CO-) flood 2 project. The field demonstration, monitoring of field performance, and associated validation activities will take place in the Paradox basin within the Navajo Nation. The results of this project will be transferred to industry and other researchers through a petroleum extension service, creation of digital databases for distribution, technical workshops and seminars, field trips, technical presentations at national and regional professional meetings, and publication in newsletters and various technical or trade journals.

  15. Increased Oil Production and Reserves Utilizing Secondary/Tertiary Recovery Techniques on Small Reservoirs in the Paradox Basin, Utah.

    SciTech Connect

    Chidsey, T.C. Jr.; Lorenz, D.M.; Culham, W.E.

    1997-10-15

    The primary objective of this project is to enhance domestic petroleum production by demonstration and technology transfer of an advanced oil recovery technology in the Paradox basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to approximately 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million barrels of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon dioxide- (CO{sub 2}-) flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place in the Paradox basin within the Navajo Nation. The results of this project will be transferred to industry and other researchers through a petroleum extension service, creation of digital databases for distribution, technical workshops and seminars, field trips, technical presentations at national and regional professional meetings, and publication in newsletters and various technical or trade journals.

  16. Screening of industrial wastewaters as feedstock for the microbial production of oils for biodiesel production and high-quality pigments

    SciTech Connect

    Schneider, Teresa; Graeff-Honninger, Simone; French, William Todd; Hernandez, Rafael; Claupein, Wilhelm; Holmes, William E.; Merkt, Nikolaus

    2012-01-01

    The production of biodiesel has notably increased over the past decade. Currently, plant oil is the main feedstock for biodiesel production, but, due to concerns related to the competition with food production, alternative oil feedstocks have to be found. Oleaginous yeasts are known to produce high amounts of lipids, but no integrated process from microbial fermentation to final biodiesel production has reached commercial realization yet due to economic constraints. Therefore, growth and lipid production of red yeast Rhodotorula glutinis was tested on low-cost substrates, namely, wastewaters from potato, fruit juice, and lettuce processing. Additionally, the production of carotenoids as high-value by-products was examined. All evaluated wastewaters met the general criteria for microbial lipid production. However, no significant increase in lipid content was observed, probably due to lack of available carbon in wastewaters from fruit juice and lettuce processing, and excess of available nitrogen in potato processing wastewater, respectively. During growth on wastewaters from fruit juice and lettuce processing the carotenoid content increased significantly in the first 48 hours. The relations between carbon content, nitrogen content, and carotenoid production need to be further assessed. For economic viability, lipid and carotenoid production needs to be increased significantly. Lastly, the screening of feedstocks should be extended to other wastewaters.

  17. Screening of industrial wastewaters as feedstock for the microbial production of oils for biodiesel production and high-quality pigments

    DOE PAGES [OSTI]

    Schneider, Teresa; Graeff-Honninger, Simone; French, William Todd; Hernandez, Rafael; Claupein, Wilhelm; Holmes, William E.; Merkt, Nikolaus

    2012-01-01

    The production of biodiesel has notably increased over the past decade. Currently, plant oil is the main feedstock for biodiesel production, but, due to concerns related to the competition with food production, alternative oil feedstocks have to be found. Oleaginous yeasts are known to produce high amounts of lipids, but no integrated process from microbial fermentation to final biodiesel production has reached commercial realization yet due to economic constraints. Therefore, growth and lipid production of red yeast Rhodotorula glutinis was tested on low-cost substrates, namely, wastewaters from potato, fruit juice, and lettuce processing. Additionally, the production of carotenoids as high-valuemore » by-products was examined. All evaluated wastewaters met the general criteria for microbial lipid production. However, no significant increase in lipid content was observed, probably due to lack of available carbon in wastewaters from fruit juice and lettuce processing, and excess of available nitrogen in potato processing wastewater, respectively. During growth on wastewaters from fruit juice and lettuce processing the carotenoid content increased significantly in the first 48 hours. The relations between carbon content, nitrogen content, and carotenoid production need to be further assessed. For economic viability, lipid and carotenoid production needs to be increased significantly. Lastly, the screening of feedstocks should be extended to other wastewaters.« less

  18. U.S. Exports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    2010 2011 2012 2013 2014 2015 View History Total 2,353 2,986 3,205 3,621 4,176 4,738 1973-2015 Crude Oil 42 47 67 134 351 465 1910-2015 Natural Gas Plant Liquids and Liquefied Refinery Gases 164 249 314 468 703 966 1983-2015 Pentanes Plus 32 101 118 137 166 183 1984-2015 Liquefied Petroleum Gases 132 148 196 332 537 783 1973-2015 Ethane/Ethylene 0 0 0 38 65 1983-2015 Propane/Propylene 109 124 171 302 423 615 1973-2015 Normal Butane/Butylene 22 24 26 30 76 97 1983-2015 Isobutane/Isobutylene 7

  19. U.S. Imports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    2010 2011 2012 2013 2014 2015 View History Total 11,793 11,436 10,598 9,859 9,241 9,449 1973-2015 Crude Oil 9,213 8,935 8,527 7,730 7,344 7,363 1910-2015 Natural Gas Plant Liquids and Liquefied Refinery Gases 179 183 170 182 143 156 1983-2015 Pentanes Plus 26 48 29 34 14 11 1983-2015 Liquefied Petroleum Gases 153 135 141 148 128 145 1973-2015 Ethane 1993-2007 Ethylene 0 0 0 0 0 0 1993-2015 Propane 93 82 85 103 89 104 1995-2015 Propylene 29 28 31 24 19 19 1993-2015 Normal Butane 12 8 9 6 7 7

  20. U.S. Exports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 View History Total 5,002 5,154 5,658 5,240 5,209 5,114 1973-2016 Crude Oil 508 591 662 383 474 657 1920-2016 Natural Gas Plant Liquids and Liquefied Refinery Gases 1,079 1,147 1,367 1,144 1,164 1,059 1981-2016 Pentanes Plus 200 220 228 208 208 212 1984-2016 Liquefied Petroleum Gases 879 927 1,139 936 956 847 1973-2016 Ethane/Ethylene 85 86 94 80 90 105 1981-2016 Propane/Propylene 673 700 894 742 755 676 1973-2016 Normal Butane/Butylene 117 132 148 108

  1. U.S. Imports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 View History Total 10,002 9,829 10,183 10,076 10,507 10,311 1973-2016 Crude Oil 8,042 7,637 7,946 7,611 8,092 8,035 1920-2016 Natural Gas Plant Liquids and Liquefied Refinery Gases 144 116 136 116 149 169 1981-2016 Pentanes Plus 0 0 19 0 23 31 1981-2016 Liquefied Petroleum Gases 144 116 116 116 127 138 1973-2016 Ethane 1993-2016 Ethylene 1993-2015 Propane 98 80 81 69 76 93 1995-2016 Propylene 24 23 20 27 29 24 1993-2016 Normal Butane 5 0 2 6 7 10

  2. PADD 1 Stocks of Crude Oil and Petroleum Products

    Gasoline and Diesel Fuel Update

    18,290 17,961 18,180 18,018 18,125 17,282 1990-2016 Commercial Crude Oil (Incl. Lease Stock) 1990-2016 Total Motor Gasoline 57,932 60,907 62,874 60,969 55,592 56,167 1990-2016 Finished Motor Gasoline 4,744 4,978 5,028 5,125 4,576 4,856 1994-2016 Reformulated 29 28 25 28 33 29 1993-2016 Blended with Fuel Ethanol 29 28 25 28 33 29 2004-2016 Conventional 4,715 4,950 5,003 5,097 4,543 4,827 1994-2016 Blended with Fuel Ethanol 62 53 53 53 44 44 2004-2016 Blended with Fuel Ethanol, Greater than Ed55 0

  3. U.S. Exports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    2010 2011 2012 2013 2014 2015 View History Total 858,685 1,089,848 1,172,965 1,321,787 1,524,170 1,729,378 1981-2015 Crude Oil 15,198 17,158 24,693 48,968 128,233 169,741 1870-2015 Natural Gas Plant Liquids and Liquefied Refinery Gases 59,842 90,968 115,054 170,941 256,587 352,618 1981-2015 Pentanes Plus 11,792 36,837 43,136 49,883 60,533 66,642 1984-2015 Liquefied Petroleum Gases 48,050 54,131 71,918 121,058 196,054 285,976 1981-2015 Ethane/Ethylene 0 0 0 13,820 23,619 1983-2015

  4. U.S. Exports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 View History Total 155,073 154,624 175,388 157,194 161,473 158,545 1981-2016 Crude Oil 15,742 17,736 20,511 11,489 14,684 20,370 1920-2016 Natural Gas Plant Liquids and Liquefied Refinery Gases 33,450 34,405 42,385 34,311 36,076 32,838 1981-2016 Pentanes Plus 6,195 6,600 7,067 6,226 6,433 6,571 1984-2016 Liquefied Petroleum Gases 27,254 27,805 35,318 28,085 29,643 26,267 1981-2016 Ethane/Ethylene 2,621 2,587 2,923 2,414 2,802 3,256 1981-2016

  5. U.S. Imports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    2010 2011 2012 2013 2014 2015 View History Total 4,304,533 4,174,210 3,878,852 3,598,454 3,372,904 3,448,734 1981-2015 Crude Oil 3,362,856 3,261,422 3,120,755 2,821,480 2,680,626 2,687,409 1910-2015 Natural Gas Plant Liquids and Liquefied Refinery Gases 65,314 66,851 62,192 66,290 52,031 56,789 1981-2015 Pentanes Plus 9,498 17,681 10,680 12,241 5,186 4,009 1981-2015 Liquefied Petroleum Gases 55,816 49,170 51,512 54,049 46,845 52,780 1981-2015 Ethane 1993-2007 Ethylene 135 119 115 123 129 36

  6. U.S. Imports of Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    Mar-16 Apr-16 May-16 Jun-16 Jul-16 Aug-16 View History Total 310,060 294,858 315,660 302,286 325,716 319,629 1981-2016 Crude Oil 249,300 229,100 246,323 228,320 250,845 249,099 1920-2016 Natural Gas Plant Liquids and Liquefied Refinery Gases 4,462 3,491 4,213 3,475 4,624 5,238 1981-2016 Pentanes Plus 5 4 604 4 702 953 1981-2016 Liquefied Petroleum Gases 4,457 3,487 3,609 3,471 3,922 4,285 1981-2016 Ethane 1993-2016 Ethylene 1993-2015 Propane 3,045 2,413 2,497 2,060 2,346 2,893 1995-2016

  7. Oil and gas taxation in Algeria: exploration and production activities

    SciTech Connect

    Frilet, M.

    1982-09-01

    The Algerian taxation scheme for foreign companies involved in the petroleum sector is profoundly different depending on whether the company is directly involved in exploration and production or is merely acting as a service company or contractor. This article discusses Algerian taxation of foreign companies directly involved in production and exploration.

  8. Selectively reducing offshore royalty rates in the Gulf of Mexico could increase oil production and federal government revenue

    SciTech Connect

    Bowsher, C.A.

    1985-05-10

    The US government leases large areas in the Outer Continental Shelf in the Gulf of Mexico for the development of oil resources and receives royalties on the oil produced. Conventional methods of oil recovery have recovered or are expected to recover about half of the 16 billion barrels of oil discovered in this area. Other oil recovery methods, collectively known as enhanced oil recovery (EOR), could potentially increase production by about 1 billion barrels of oil. EOR in the Gulf is expensive and does not appear to be economically justified in most cases. Under existing economic conditions and federal policies, GAO's review indicates that utilizing EOR methods will probably produce only about 10 percent of the additional recoverable oil. However, financial incentives in the form of royalty reductions could increase both oil production and federal government revenue if applied on a project-by-project basis. Universal applications of royalty reduction for EOR, however, while achieving increased oil production, would not increase federal government revenue. GAO recommends that the Department of the Interior's Minerals Management Service initiate action that would allow for selective royalty reductions for EOR projects in the Gulf in instances where both total oil production and federal government revenue will increase. 6 figs., 1 tab.

  9. Oil Production Capacity Expansion Costs for the Persian Gulf

    Reports and Publications

    1996-01-01

    Provides estimates of development and operating costs for various size fields in countries surrounding the Persian Gulf. In addition, a forecast of the required reserve development and associated costs to meet the expected demand through the year 2010 is presented.

  10. Improved Oil Recovery from Upper Jurassic Smackover Carbonates through the Application of Advanced Technologies at Womack Hill Oil Field, Choctaw and Clarke Counties, Alabama, Eastern Gulf Coastal Plan (Phase II)

    SciTech Connect

    Ernest A. Mancini; Joe Benson; David Hilton; David Cate; Lewis Brown

    2006-05-29

    The principal research efforts for Phase II of the project were drilling an infill well strategically located in Section 13, T. 10 N., R. 2 W., of the Womack Hill Field, Choctaw and Clarke Counties, Alabama, and obtaining fresh core from the upper Smackover reservoir to test the feasibility of implementing an immobilized enzyme technology project in this field. The Turner Land and Timber Company 13-10 No. 1 well was successfully drilled and tested at a daily rate of 132 barrels of oil in Section 13. The well has produced 27,720 barrels of oil, and is currently producing at a rate of 60 barrels of oil per day. The 13-10 well confirmed the presence of 175,000 barrels of attic (undrained) oil in Section 13. As predicted from reservoir characterization, modeling and simulation, the top of the Smackover reservoir in the 13-10 well is structurally high to the tops of the Smackover in offsetting wells, and the 13-10 well has significantly more net pay than the offsetting wells. The drilling and testing of the 13-10 well showed that the eastern part of the field continues to have a strong water drive and that there is no need to implement a pressure maintenance program in this part of the Womack Hill Field at this time. The success achieved in drilling and testing the 13-10 infill well demonstrates the benefits of building a geologic model to target areas in mature fields that have the potential to contain undrained oil, thus increasing the productivity and profitability of these fields. Microbial cultures that grew at 90 C and converted ethanol to acid were recovered from fresh cuttings from the Smackover carbonate reservoir in an analogous field to the Womack Hill Field in southwest Alabama; however, no viable microorganisms were found in the Smackover cores recovered from the drilling of the 13-10 well in Womack Hill Field. Further evaluation is, therefore, required prior to implementing an immobilized enzyme technology project in the Womack Hill Field.

  11. Catalytic Hydroprocessing of Biomass Fast Pyrolysis Bio-oil to Produce Hydrocarbon Products

    SciTech Connect

    Elliott, Douglas C.; Hart, Todd R.; Neuenschwander, Gary G.; Rotness, Leslie J.; Zacher, Alan H.

    2009-10-01

    Catalytic hydroprocessing has been applied to biomass fast pyrolysis liquid product (bio-oil) in a bench-scale continuous-flow fixed-bed reactor system. The intent of the research was to develop process technology to convert the bio-oil into a petroleum refinery feedstock to supplement fossil energy resources and to displace imported feedstock. The project was a cooperative research and development agreement among UOP LLC, the National Renewable Energy Laboratory and the Pacific Northwest National Laboratory (PNNL). This paper is focused on the process experimentation and product analysis undertaken at PNNL. The paper describes the experimental methods used and relates the results of the product analyses. A range of catalyst formulations were tested over a range of operating parameters including temperature, pressure, and flow-rate with bio-oil derived from several different biomass feedstocks. Effects of liquid hourly space velocity and catalyst bed temperature were assessed. Details of the process results were presented including mass and elemental balances. Detailed analysis of the products were provided including elemental composition, chemical functional type determined by mass spectrometry, and product descriptors such as density, viscosity and Total Acid Number (TAN). In summation, the paper provides an understanding of the efficacy of hydroprocessing as applied to bio-oil.

  12. Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama. Final report, March 1996--September 1998

    SciTech Connect

    Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Carroll, R.E.; Groshong, R.H.; Jin, G.

    1998-12-01

    This project was designed to analyze the structure of Mesozoic and Tertiary strata in Gilbertown Field and adjacent areas to suggest ways in which oil recovery can be improved. The Eutaw Formation comprises 7 major flow units and is dominated by low-resistivity, low-contrast play that is difficult to characterize quantitatively. Selma chalk produces strictly from fault-related fractures that were mineralized as warm fluid migrated from deep sources. Resistivity, dipmeter, and fracture identification logs corroborate that deformation is concentrated in the hanging-wall drag zones. New area balancing techniques were developed to characterize growth strata and confirm that strain is concentrated in hanging-wall drag zones. Curvature analysis indicates that the faults contain numerous fault bends that influence fracture distribution. Eutaw oil is produced strictly from footwall uplifts, whereas Selma oil is produced from fault-related fractures. Clay smear and mineralization may be significant trapping mechanisms in the Eutaw Formation. The critical seal for Selma reservoirs, by contrast, is where Tertiary clay in the hanging wall is juxtaposed with poorly fractured Selma chalk in the footwall. Gilbertown Field can be revitalized by infill drilling and recompletion of existing wells. Directional drilling may be a viable technique for recovering untapped oil from Selma chalk. Revitalization is now underway, and the first new production wells since 1985 are being drilled in the western part of the field.

  13. New ceramic-epoxy technology for oil and gas drilling and production

    SciTech Connect

    Boyd, J.L.; Freeman, J.E.

    1997-08-01

    For the past ten years, an environmentally friendly, low V.O.C., high solids ceramic filled epoxy resin coating system has been successfully used to extend the useful life of pipe and equipment used for oil and gas service. This unique chemistry provides mechanical performance characteristics which withstand damage and abuse in oilfield use. Successful applications and field histories are summarized.

  14. Method and apparatus for stimulating oil well production

    SciTech Connect

    Brieger, E.F.

    1981-08-25

    A system for cleaning perforations in a well bore where the perforations are located below a packer means on a production tubing. A tool on a string of pipe has packer means for sealing off the cross-section of the production tubing and the pressure in the annulus between the string of pipe and production tubing is reduced. The tool has a bypass passage across the packer means which opens upon the reaching of a predetermined pressure across the packer means and the high volume pressure from the earth formations suddenly flows through the tool and cleaning of the perforations is effected.

  15. EIA revises up forecast for U.S. 2013 crude oil production by 70,000 barrels per day

    Energy Information Administration (EIA) (indexed site)

    EIA revises up forecast for U.S. 2013 crude oil production by 70,000 barrels per day The forecast for U.S. crude oil production keeps going higher. The U.S. Energy Information Administration revised upward its projection for crude oil output in 2013 by 70,000 barrels per day and for next year by 190,000 barrels per day. U.S. oil production is now on track to average 7.5 million barrels per day this year and rise to 8.4 million barrels per day in 2014, according to EIA's latest monthly forecast.

  16. U.S. monthly oil production tops 8 million barrels per day for the first time since 1988

    Energy Information Administration (EIA) (indexed site)

    U.S. crude oil production expected to hit four-decade high during 2015 U.S. crude oil production over the next two years is expected to grow to its highest level since the early 1970s. Oil output increased by 1 million barrels per day in 2013...and is expected to repeat that growth rate during 2014....according to the new forecast from the U.S. Energy Information Administration. U.S. crude oil production is forecast to average 8.5 million barrels per day this year and then rise to 9.3 million

  17. U.S. monthly oil production tops 8 million barrels per day for the first time since 1988

    Energy Information Administration (EIA) (indexed site)

    monthly crude oil production highest in 26 years with bigger oil flows still to come U.S. crude oil production averaged 8.3 million barrels per day in April....the highest monthly level in 26 years....and output is expected to keep growing. In its new monthly forecast, the U.S. Energy Information Administration expects oil production to average 8.5 million barrels per day this year and increase to 9.2 million barrels per day next year. That would be the highest annual output level since 1972.

  18. Probabilistic Risk Based Decision Support for Oil and Gas Exploration and Production Facilities in Sensitive Ecosystems

    SciTech Connect

    Greg Thoma; John Veil; Fred Limp; Jackson Cothren; Bruce Gorham; Malcolm Williamson; Peter Smith; Bob Sullivan

    2009-05-31

    This report describes work performed during the initial period of the project 'Probabilistic Risk Based Decision Support for Oil and Gas Exploration and Production Facilities in Sensitive Ecosystems.' The specific region that is within the scope of this study is the Fayetteville Shale Play. This is an unconventional, tight formation, natural gas play that currently has approximately 1.5 million acres under lease, primarily to Southwestern Energy Incorporated and Chesapeake Energy Incorporated. The currently active play encompasses a region from approximately Fort Smith, AR east to Little Rock, AR approximately 50 miles wide (from North to South). The initial estimates for this field put it almost on par with the Barnett Shale play in Texas. It is anticipated that thousands of wells will be drilled during the next several years; this will entail installation of massive support infrastructure of roads and pipelines, as well as drilling fluid disposal pits and infrastructure to handle millions of gallons of fracturing fluids. This project focuses on gas production in Arkansas as the test bed for application of proactive risk management decision support system for natural gas exploration and production. The activities covered in this report include meetings with representative stakeholders, development of initial content and design for an educational web site, and development and preliminary testing of an interactive mapping utility designed to provide users with information that will allow avoidance of sensitive areas during the development of the Fayetteville Shale Play. These tools have been presented to both regulatory and industrial stakeholder groups, and their feedback has been incorporated into the project.

  19. Spot Prices for Crude Oil and Petroleum Products

    Energy Information Administration (EIA) (indexed site)

    Product by Area 100416 100516 100616 100716 101016 101116 View History Crude ... Brent - Europe 48.81 49.57 50.14 50.49 51.54 50.48 1987-2016 Conventional Gasoline New ...

  20. Cushing, Oklahoma Stocks of Crude Oil and Petroleum Products

    Gasoline and Diesel Fuel Update

    Petroleum Product Price Formation November 8, 2016 | Washington, DC An analysis of the factors that influence product prices, with chart data updated monthly, quarterly and annually Gasoline spot prices 2 Sources: U.S. Energy Information Administration, Bloomberg L.P. November 8, 2016 dollars per gallon, nominal Chicago CBOB New York Harbor Conventional gasoline Gulf Coast Conventional gasoline Los Angeles CARBOB Northwest Europe gasoline Singapore gasoline 2002 2003 2004 2005 2006 2007 2008

  1. Field Laboratory in the Osage Reservation -- Determination of the Status of Oil and Gas Operations: Task 1. Development of Survey Procedures and Protocols

    SciTech Connect

    Carroll, Herbert B.; Johnson, William I.

    1999-04-27

    Procedures and protocols were developed for the determination of the status of oil, gas, and other mineral operations on the Osage Mineral Reservation Estate. The strategy for surveying Osage County, Oklahoma, was developed and then tested in the field. Two Osage Tribal Council members and two Native American college students (who are members of the Osage Tribe) were trained in the field as a test of the procedures and protocols developed in Task 1. Active and inactive surface mining operations, industrial sites, and hydrocarbon-producing fields were located on maps of the county, which was divided into four more or less equal areas for future investigation. Field testing of the procedures, protocols, and training was successful. No significant damage was found at petroleum production operations in a relatively new production operation and in a mature waterflood operation.

  2. Increased oil production and reserves utilizing secondary/tertiary recovery techniques on small reservoirs in the Paradox Basin, Utah, Class II

    SciTech Connect

    Chidsey, Thomas C.

    2000-07-28

    The primary objective of this project is to enhance domestic petroleum production by field demonstration and technology transfer of an advanced-oil-recovery technology in the Paradox basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to approximately 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million barrels (23,850,000-31,800,000 m{sup 3}) of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon-dioxide-miscible flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place within the Navajo Nation, San Juan County, Utah.

  3. Thermal upgrading of residual oil to light product and heavy residual fuel

    SciTech Connect

    Yan, T.Y.; Shu, P.

    1986-08-05

    The method is described of upgrading residual oil boiling in the range of 1050/sup 0/F+ comprising: thermally cracking the residual oil at a temperature of 650/sup 0/-900/sup 0/F, a pressure of 0-100 psig, and a residence time of 0.1 to 5 hours at the highest severity in the range between about 1,000-18,000 seconds, as expressed in equivalent reaction time at 800/sup 0/F, sufficient to convert at least about 50 wt% of the residual oil to light products, substantially without the formation of solid coke; recovering separate fractions of light product and emulsifiable heavy bottom product which has a fusion temperature below about 150/sup 0/C and a quinoline-insoluble content between about 10 wt% and 30 wt% and wherein the highest severity is determined by a functional relationship between the asphaltene content of the residual oil feedstock and the heavy bottom product yield and quinoline-insoluble content.

  4. Water Treatment in Oil and Gas Production | GE Global Research

    U.S. Department of Energy (DOE) - all webpages (Extended Search)

    Water Treatment and Reuse in Unconventional Gas Production Click to email this to a friend (Opens in new window) Share on Facebook (Opens in new window) Click to share (Opens in new window) Click to share on LinkedIn (Opens in new window) Click to share on Tumblr (Opens in new window) Water Treatment and Reuse in Unconventional Gas Production A key challenge in tapping vast reserves of natural gas from shale deposits is treating the water that is used to bring this gas to the surface. GE

  5. Identification, Verification, and Compilation of Produced Water Management Practices for Conventional Oil and Gas Production Operations

    SciTech Connect

    Rachel Henderson

    2007-09-30

    The project is titled 'Identification, Verification, and Compilation of Produced Water Management Practices for Conventional Oil and Gas Production Operations'. The Interstate Oil and Gas Compact Commission (IOGCC), headquartered in Oklahoma City, Oklahoma, is the principal investigator and the IOGCC has partnered with ALL Consulting, Inc., headquartered in Tulsa, Oklahoma, in this project. State agencies that also have partnered in the project are the Wyoming Oil and Gas Conservation Commission, the Montana Board of Oil and Gas Conservation, the Kansas Oil and Gas Conservation Division, the Oklahoma Oil and Gas Conservation Division and the Alaska Oil and Gas Conservation Commission. The objective is to characterize produced water quality and management practices for the handling, treating, and disposing of produced water from conventional oil and gas operations throughout the industry nationwide. Water produced from these operations varies greatly in quality and quantity and is often the single largest barrier to the economic viability of wells. The lack of data, coupled with renewed emphasis on domestic oil and gas development, has prompted many experts to speculate that the number of wells drilled over the next 20 years will approach 3 million, or near the number of current wells. This level of exploration and development undoubtedly will draw the attention of environmental communities, focusing their concerns on produced water management based on perceived potential impacts to fresh water resources. Therefore, it is imperative that produced water management practices be performed in a manner that best minimizes environmental impacts. This is being accomplished by compiling current best management practices for produced water from conventional oil and gas operations and to develop an analysis tool based on a geographic information system (GIS) to assist in the understanding of watershed-issued permits. That would allow management costs to be kept in line with

  6. Feasibility study of enhanced oil recovery for fields in decline. Export trade information (Final)

    SciTech Connect

    Not Available

    1991-08-01

    The report, generated by Scientific Software-Intercomp, Inc. for Yacimientos Petroliferos Fiscales Bolivianos, documents the results of a feasibility study which addressed the viability of developing petroleum areas in Bolivia. The primary objective of the project was to describe the reservoirs that have been discovered and their reserves, describe which would be the best alternatives for development of these reservoirs, and to determine the best alternatives for development of all the reserves together. The report, volume 4 of 4, concerns the feasibility of enhancing the oil or condensate recovery from a chosen group of fields (Yapacani, Humberto Suarez Roca, Vibora, La Pena, San Roque, and Camiri).

  7. Potential Oil Production from the Coastal Plain of the Arctic National

    Energy Information Administration (EIA) (indexed site)

    Wildlife Refuge: Updated Assessment Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment Glossary ANILCA: Alaska National Interest Lands Conservation Act ANS: Alaskan North Slope ANWR: Arctic National Wildlife Refuge BBbls: billion barrels Bbls: barrels Daily Petroleum Production Rate: The amount of petroleum extracted per day from a well, group of wells, region, etc. (usually expressed in barrels per day) EIA: Energy Information

  8. Potential Oil Production from the Coastal Plain of the Arctic National

    Energy Information Administration (EIA) (indexed site)

    Wildlife Refuge: Updated Assessment Potential Oil Production from the Coastal Plain of the Arctic National Wildlife Refuge: Updated Assessment 3. Summary The 1.5 million-acre coastal plain of the 19 million-acre Arctic National Wildlife Refuge is the largest unexplored, potentially productive geologic onshore basin in the United States. The primary area of the coastal plain is the 1002 Area of ANWR established when ANWR was created. A decision on permitting the exploration and development

  9. The boomerang area: An example of oil and gas fields related to a transfer zone development

    SciTech Connect

    Specht, M.; Colletta, B.; Letouzey, J. ); Baby, P. ); Oller, J.; Montemuro, G. ); Guillier, B. )

    1993-02-01

    We present results of a study realized from petroleum data of Yacimientos Petroliferos Fiscales Bolivianos of the most important transfer zone of the Bolivian Andean belt: the Santa Cruz transfer zone. Frontal part of the Bolivian Andean belt consists of a thick series (6 to 8 km) of paleozoic to cenozoic sedimentary rocks thrusted eastwards on a sole thrust located in paleozoic series. The frontal part of the belt, globally N-S oriented, undergoes an important deviation East of Santa Cruz with a left lateral offset of 100 Km. Taking into account the E-W shortening direction, this transfer zone can be interpreted as a lateral ramp. The Santa Cruz transfer zone coincide with a set of small oil and gas fields whereas frontal structures lack hydrocarbon occurrences. We are then faced with a two-fold problem: (1) what is the origin of the transfer zone (2) why are the oil and gas concentrated in the transfer zone Our synthesis shows that the transfer zone is superimposed on the limit of a detached Paleozoic basin whose border direction is oblique to the regional shortening direction. We then interpret the oil and gas formation in two steps: (1) source rock maturation and hydrocarbon migration towards the top of the Paleozoic sedimentary wedge before Andean deformation. (2) hydrocarbon dismigration towards anticlinal structures developed during the lateral ramp propagation. In order to test our interpretation we performed a set of analog model experiments whose 3D visualization was analyzed by computerized X-ray tomography.

  10. Heavy oil reservoirs in the Tulare Fold Belt, Cymric-McKittrick fields, Kern County, California

    SciTech Connect

    Farley, T. )

    1990-05-01

    The Tulare fold belt is a series of asymmetric, generally northeast-verging anticlines and synclines in the Pliocene-Pleistocene Tulare Formation that trend northwestward through the Cymric-McKittrick fields. Anticlines within the deformed belt generally originated as fault propagation folds above decollements, the most important of which is the regional decollement on top of the Amnicola sand, the basal Tulare unit. The Amnicola decollement is the northeast subsurface extension of the McKittrick thrust, a low-angle fault that has displaced the Miocene Antelope shale over the Pliocene San Joaquin Formation and locally over the Tulare Formation. The Amnicola decollement is itself deformed by folding related to a younger, deeper decollement near the base of the San Joaquin Formation that merges westward with the Amnicola decollement and defines a zone of faulting associated with the McKittrick thrust Heavy oil reservoirs in the Tulare Formation are currently undergoing active development by thermal recovery techniques. In general, the geometry of heavy oil reservoirs is determined by location within the Tulare fold belt combined with the position of a subhorizontal fluid level trap that forms the updip limit of fluid-saturated rock Reservoir geometry is complicated by complex local structure, discontinuous stratigraphy, and partial depletion of heavy oil reservoirs by fluid withdrawal due to gravity drainage. Proper resolution of fold geometry, fault geometry, and position of the fluid level trap is crucial to the design and monitoring of thermal recovery projects within the Tulare fold belt.

  11. An evaluation of gas field rules in light of current conditions and production practices in the Panhandle non-associated gas fields

    SciTech Connect

    Brady, C.L.; O`Rear, C.H.

    1996-09-01

    During the early years of development in the Panhandle fields the Rule of Capture was king. Under the Rule of Capture each property owner has the right to drill as many wells as desired at any location. Adjacent property owners protect their rights by doing the same. Courts adopted the Rule of Capture to protect mineral owners from liability due to migration of oil and gas across property boundary lines. This general practice {open_quotes}to go and do likewise{close_quotes} generally leads to enormous economic and natural resource waste. Established to offset the waste created under the Rule of Capture is the doctrine of Correlative Rights. Correlative Rights is the fight of each mineral owner to obtain oil and gas from a common source of supply under lawful operations conducted from his property. However, each mineral owner has a duty to every other mineral owner not to extract oil and gas in a manner injurious to the common source of supply. This paper will examine the historical context of these common law principles with regard to the Panhandle non-associated gas fields. Discovered in 1917, the Panhandle fields are ideal to evaluate the merit of statutes and regulations enacted in response to production practices. As in many Texas fields, proration in the Panhandle fields is the primary mechanism to protect correlative rights and prevent waste. Signed and made effective May 1989, the current field rules pre-date much of the enhanced recovery techniques that use well-head vacuum compression. This paper reviews the gas rules in the 1989 Texas Railroad Commission order in light of current reservoir conditions and production practices.

  12. Locally smeared operator product expansions in scalar field theory

    DOE PAGES [OSTI]

    Monahan, Christopher; Orginos, Kostas

    2015-04-01

    We propose a new locally smeared operator product expansion to decompose non-local operators in terms of a basis of smeared operators. The smeared operator product expansion formally connects nonperturbative matrix elements determined numerically using lattice field theory to matrix elements of non-local operators in the continuum. These nonperturbative matrix elements do not suffer from power-divergent mixing on the lattice, which significantly complicates calculations of quantities such as the moments of parton distribution functions, provided the smearing scale is kept fixed in the continuum limit. The presence of this smearing scale complicates the connection to the Wilson coefficients of the standardmore » operator product expansion and requires the construction of a suitable formalism. We demonstrate the feasibility of our approach with examples in real scalar field theory.« less

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

    SciTech Connect

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

    1997-10-21

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

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

    SciTech Connect

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

    1998-01-26

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

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

    SciTech Connect

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

    1998-04-22

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

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

    SciTech Connect

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

    1997-07-28

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

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

    SciTech Connect

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

    1998-01-26

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

  18. Producing Light Oil from a Frozen Reservoir: Reservoir and Fluid Characterization of Umiat Field, National Petroleum Reserve, Alaska

    SciTech Connect

    Hanks, Catherine

    2012-12-31

    Umiat oil field is a light oil in a shallow, frozen reservoir in the Brooks Range foothills of northern Alaska with estimated oil-in-place of over 1 billion barrels. Umiat field was discovered in the 1940’s but was never considered viable because it is shallow, in the permafrost, and far from any transportation infrastructure. The advent of modern drilling and production techniques has made Umiat and similar fields in northern Alaska attractive exploration and production targets. Since 2008 UAF has been working with Renaissance Alaska Inc. and, more recently, Linc Energy, to develop a more robust reservoir model that can be combined with rock and fluid property data to simulate potential production techniques. This work will be used to by Linc Energy as they prepare to drill up to 5 horizontal wells during the 2012-2013 drilling season. This new work identified three potential reservoir horizons within the Cretaceous Nanushuk Formation: the Upper and Lower Grandstand sands, and the overlying Ninuluk sand, with the Lower Grandstand considered the primary target. Seals are provided by thick interlayered shales. Reserve estimates for the Lower Grandstand alone range from 739 million barrels to 2437 million barrels, with an average of 1527 million bbls. Reservoir simulations predict that cold gas injection from a wagon-wheel pattern of multilateral injectors and producers located on 5 drill sites on the crest of the structure will yield 12-15% recovery, with actual recovery depending upon the injection pressure used, the actual Kv/Kh encountered, and other geologic factors. Key to understanding the flow behavior of the Umiat reservoir is determining the permeability structure of the sands. Sandstones of the Cretaceous Nanushuk Formation consist of mixed shoreface and deltaic sandstones and mudstones. A core-based study of the sedimentary facies of these sands combined with outcrop observations identified six distinct facies associations with distinctive permeability

  19. Hydrocarbon Liquid Production via Catalytic Hydroprocessing of Phenolic Oils Fractionated from Fast Pyrolysis of Red Oak and Corn Stover

    SciTech Connect

    Elliott, Douglas C.; Wang, Huamin; Rover, Majorie; Whitmer, Lysle; Smith, Ryan; Brown, Robert C.

    2015-04-13

    Phenolic oils were produced from fast pyrolysis of two different biomass feedstocks, red oak and corn stover and evaluated in hydroprocessing tests for production of liquid hydrocarbon products. The phenolic oils were produced with a bio-oil fractionating process in combination with a simple water wash of the heavy ends from the fractionating process. Phenolic oils derived from the pyrolysis of red oak and corn stover were recovered with yields (wet biomass basis) of 28.7 wt% and 14.9 wt%, respectively, and 54.3% and 58.6% on a carbon basis. Both precious metal catalysts and sulfided base metal catalyst were evaluated for hydrotreating the phenolic oils, as an extrapolation from whole bio-oil hydrotreatment. They were effective in removing heteroatoms with carbon yields as high as 81% (unadjusted for the 90% carbon balance). There was nearly complete heteroatom removal with residual O of only 0.4% to 5%, while N and S were reduced to less than 0.05%. Use of the precious metal catalysts resulted in more saturated products less completely hydrotreated compared to the sulfided base metal catalyst, which was operated at higher temperature. The liquid product was 42-52% gasoline range molecules and about 43% diesel range molecules. Particulate matter in the phenolic oils complicated operation of the reactors, causing plugging in the fixed-beds especially for the corn stover phenolic oil. This difficulty contrasts with the catalyst bed fouling and plugging, which is typically seen with hydrotreatment of whole bio-oil. This problem was substantially alleviated by filtering the phenolic oils before hydrotreating. More thorough washing of the phenolic oils during their preparation from the heavy ends of bio-oil or on-line filtration of pyrolysis vapors to remove particulate matter before condensation of the bio-oil fractions is recommended.

  20. Hydrocarbon Liquid Production via Catalytic Hydroprocessing of Phenolic Oils Fractionated from Fast Pyrolysis of Red Oak and Corn Stover

    DOE PAGES [OSTI]

    Elliott, Douglas C.; Wang, Huamin; Rover, Majorie; Whitmer, Lysle; Smith, Ryan; Brown, Robert C.

    2015-04-13

    Phenolic oils were produced from fast pyrolysis of two different biomass feedstocks, red oak and corn stover and evaluated in hydroprocessing tests for production of liquid hydrocarbon products. The phenolic oils were produced with a bio-oil fractionating process in combination with a simple water wash of the heavy ends from the fractionating process. Phenolic oils derived from the pyrolysis of red oak and corn stover were recovered with yields (wet biomass basis) of 28.7 wt% and 14.9 wt%, respectively, and 54.3% and 58.6% on a carbon basis. Both precious metal catalysts and sulfided base metal catalyst were evaluated for hydrotreatingmore » the phenolic oils, as an extrapolation from whole bio-oil hydrotreatment. They were effective in removing heteroatoms with carbon yields as high as 81% (unadjusted for the 90% carbon balance). There was nearly complete heteroatom removal with residual O of only 0.4% to 5%, while N and S were reduced to less than 0.05%. Use of the precious metal catalysts resulted in more saturated products less completely hydrotreated compared to the sulfided base metal catalyst, which was operated at higher temperature. The liquid product was 42-52% gasoline range molecules and about 43% diesel range molecules. Particulate matter in the phenolic oils complicated operation of the reactors, causing plugging in the fixed-beds especially for the corn stover phenolic oil. This difficulty contrasts with the catalyst bed fouling and plugging, which is typically seen with hydrotreatment of whole bio-oil. This problem was substantially alleviated by filtering the phenolic oils before hydrotreating. More thorough washing of the phenolic oils during their preparation from the heavy ends of bio-oil or on-line filtration of pyrolysis vapors to remove particulate matter before condensation of the bio-oil fractions is recommended.« less