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1

Recovery rates, enhanced oil recovery and technological limits  

Science Journals Connector (OSTI)

...Oman-initial results and future plans. In Proc. SP EOR Conf...Moradi-Araghi, A . 2000 A review of thermally stable gels...through EOR: policy and regulatory considerations for greenhouse...TE Burchfield. 1989 Review of microbial technology...enhanced-oil-recovery technologies: a review of the past present and...

2014-01-01T23:59:59.000Z

2

Recovery rates, enhanced oil recovery and technological limits  

Science Journals Connector (OSTI)

...significantly extend global oil reserves once oil prices are high enough to make these techniques...last plan on the assumption that the oil price is likely to remain relatively high...1970s at a time of relatively high oil prices. Improved oil recovery (IOR) is...

2014-01-01T23:59:59.000Z

3

NETL: Natural Gas Resources, Enhanced Oil Recovery, Deepwater Technology  

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

and Natural Gas Projects and Natural Gas Projects Index of Research Project Summaries Use the links provided below to access detailed DOE/NETL project information, including project reports, contacts, and pertinent publications. Search Natural Gas and Oil Projects Current Projects Natural Gas Resources Shale Gas Environmental Other Natural Gas Resources Ehanced Oil Recovery CO2 EOR Environmental Other EOR & Oil Resources Deepwater Technology Offshore Architecture Safety & Environmental Other Deepwater Technology Methane Hydrates DOE/NETL Projects Completed Projects Completed Natural Gas Resources Completed Enhanced Oil Recovery Completed Deepwater Technology Completed E&P Technologies Completed Environmental Solutions Completed Methane Hydrates Completed Transmission & Distribution

4

Oil recovery; Technology that tames large spills  

SciTech Connect (OSTI)

This paper reports that the threat of oil spills is growing with the increasing use of larger tankers, the expansion of offshore oil exploration, and-as was demonstrated recently in the Persian Gulf-the dangers of war and terrorism. Aware of the environmental havoc that massive spills can cause, engineers are working hard to devise effective methods of scooping oil from the water's surface and cleaning contaminated shorelines. Techniques are being developed, which combine mechanical, chemical, and biological processes to contain spills.

Valenti, M.

1991-05-01T23:59:59.000Z

5

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology  

SciTech Connect (OSTI)

Objectives are listed and technical progress is summarized for contracts for field projects and supporting research on: chemical flooding, carbon dioxide injection, thermal/heavy oil, extraction technology, improved drilling technology, residual oil, and microbial enhanced oil recovery. (DLC)

Linville, B. (ed.)

1980-10-01T23:59:59.000Z

6

OPTICAL FIBER SENSOR TECHNOLOGIES FOR EFFICIENT AND ECONOMICAL OIL RECOVERY  

SciTech Connect (OSTI)

Efficient recovery of petroleum reserves from existing oil wells has been proven to be difficult due to the lack of robust instrumentation that can accurately and reliably monitor processes in the downhole environment. Commercially available sensors for measurement of pressure, temperature, and fluid flow exhibit shortened lifetimes in the harsh downhole conditions, which are characterized by high pressures (up to 20 kpsi), temperatures up to 250 C, and exposure to chemically reactive fluids. Development of robust sensors that deliver continuous, real-time data on reservoir performance and petroleum flow pathways will facilitate application of advanced recovery technologies, including horizontal and multilateral wells. This is the final report for the four-year program ''Optical Fiber Sensor Technologies for Efficient and Economical Oil Recovery'', funded by the National Petroleum Technology Office of the U.S. Department of Energy, and performed by the Center for Photonics Technology of the Bradley Department of Electrical and Computer Engineering at Virginia Tech from October 1, 1999 to March 31, 2003. The main objective of this research program was to develop cost-effective, reliable optical fiber sensor instrumentation for real-time monitoring of various key parameters crucial to efficient and economical oil production. During the program, optical fiber sensors were demonstrated for the measurement of temperature, pressure, flow, and acoustic waves, including three successful field tests in the Chevron/Texaco oil fields in Coalinga, California, and at the world-class oil flow simulation facilities in Tulsa, Oklahoma. Research efforts included the design and fabrication of sensor probes, development of signal processing algorithms, construction of test systems, development and testing of strategies for the protection of optical fibers and sensors in the downhole environment, development of remote monitoring capabilities allowing real-time monitoring of the field test data from virtually anywhere in the world, and development of novel data processing techniques. Comprehensive testing was performed to systematically evaluate the performance of the fiber optic sensor systems in both lab and field environments.

Anbo Wang; Kristie L. Cooper; Gary R. Pickrell

2003-06-01T23:59:59.000Z

7

Optical Fiber Sensor Technologies for Efficient and Economical Oil Recovery  

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

Optical Fiber Sensor Technologies for Optical Fiber Sensor Technologies for Efficient and Economical Oil Recovery Final Technical Report Reporting Period Start Date: 1 October 1998 Reporting Period End Date: 31 March 2003 Principal Investigator: Anbo Wang Principal Report Authors: Kristie L. Cooper, Gary R. Pickrell, Anbo Wang Report Issued: June 2003 DOE Award Number: DE-FT26-98BC15167 Submitted by: Center for Photonics Technology Bradley Department of Electrical and Computer Engineering Virginia Polytechnic Institute & State University Blacksburg, VA 24061-0111 ii Disclaimer: This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government nor any agency thereof, nor any of their employees, makes any warranty, express or implied, or assumes any legal liability or

8

Supporting technology for enhanced oil recovery: Chemical flood predictive model  

SciTech Connect (OSTI)

The Chemical Flood Predictive Model (CFPM) was developed by Scientific Software-Intercomp for the US Department of Energy and was used in the National Petroleum Council's (NPC) 1984 survey of US enhanced oil recovery potential (NPC, 1984). The CFPM models micellar (surfactant)-polymer (MP) floods in reservoirs which have been previously waterflooded to residual oil saturation. Thus, only true tertiary floods are considered. An option is available in the model which allows a rough estimate of oil recovery by caustic (alkaline) or caustic-polymer processes. This ''caustic'' option, added for the NPC survey, is not modeled as a separate process. Rather, the caustic and caustic-polymer oil recoveries are computed simply as 15% and 40%, respectively, of the MP oil recovery. In the CFPM, an oil rate versus time function for a single pattern is computed and the results are passed to the economic routines. To estimate multi-pattern project behavior, a pattern development schedule must be specified. After-tax cash flow is computed by combining revenues with capital costs for drilling, conversion and upgrading of wells, chemical handling costs, fixed and variable operating costs, injectant costs, depreciation, royalties, severance, state, federal, and windfall profit taxes, cost and price inflation rates, and the discount rate. A lumped parameter uncertainty routine is used to estimate risk, and allows for variation in computed project performance within an 80% confidence interval. The CFPM uses theory and the results of numerical simulation to predict MP oil recovery in five-spot patterns. Oil-bank and surfactant breakthrough and project life are determined from fractional flow theory. A Koval-type factor, based on the Dykstra-Parsons (1950) coefficient, is used to account for the effects of reservoir heterogeneity on surfactant and oil bank velocities. 18 refs., 17 figs., 27 tabs.

Ray, R.M.; Munoz, J.D.

1986-12-01T23:59:59.000Z

9

Bartlesville Energy Technology Center enhanced oil recovery project data base  

SciTech Connect (OSTI)

The BETC Enhanced Oil Recovery Data Base is currently being developed to provide an information resource to accelerate the advancement and applications of EOR technology. The primary initial sources of data have been the Incentive and Cost-Shared Programs. The data base presently contains information on 607 EOR projects. This includes 410 of the approximately 423 projects which operators originally applied for certification with the Incentive Program; 20 EOR projects under the Cost-Shared Program; and a data base relating to 177 projects developed by Gulf Universities Research Consortium. In addition, relevant data from all previous DOE-funded contractor EOR data bases will be integrated into the BETC data base. Data collection activities from publicly available information sources is continuing on an on-going basis to insure the accuracy and timeliness of the information within the data base. The BETC data base is being developed utilizing a commercial data base management system. The basic structure of the data base is presented as Appendix I. This data base includes information relating to reservoir characteristics, process-specific data, cost information, production data, and contact persons for each project. The preliminary list of data elements and the current density of occurrence is presented as Appendix II. A basic profile of the types of projects contained within the developmental data base is contained in Appendix III. Appendix IV presents a number of system output reports to illustrate potential data base applications. Plans to eventually place the data base in a computer system which would be publicly accessible are currently under active consideration. A list of Incentive projects processed to date by BETC is provided as Appendix V. Appendix VI gives a detailed report by EOR Process for all projects in the BETC's Enhanced Oil Recovery Data Base.

Not Available

1982-03-01T23:59:59.000Z

10

New CO2 Enhanced Recovery Technology Could Greatly Boost U.S. Oil |  

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

CO2 Enhanced Recovery Technology Could Greatly Boost U.S. Oil CO2 Enhanced Recovery Technology Could Greatly Boost U.S. Oil New CO2 Enhanced Recovery Technology Could Greatly Boost U.S. Oil March 3, 2006 - 11:40am Addthis WASHINGTON , D.C. - The Department of Energy (DOE) released today reports indicating that state-of-the-art enhanced oil recovery techniques could significantly increase recoverable oil resources of the United States in the future. According to the findings, 89 billion barrels or more could eventually be added to the current U.S. proven reserves of 21.4 billion barrels. "These promising new technologies could further help us reduce our reliance on foreign sources of oil," Energy Secretary Samuel W. Bodman said. "By using the proven technique of carbon sequestration, we get the double

11

Supporting technology for enhanced oil recovery - EOR thermal processes  

SciTech Connect (OSTI)

This report contains the results of efforts under the six tasks of the Eighth Amendment and Extension of Annex IV, Enhanced Oil Recovery Thermal Processes of the Venezuela/USA Agreement. The report is presented in sections and each section contains one or more reports prepared by various individuals or groups describing the results of efforts under each of the tasks. A statement of each task, taken from the agreement, is presented on the first page of each section.

NONE

1995-03-01T23:59:59.000Z

12

Supporting technology for enhanced oil recovery: Polymer predictive model  

SciTech Connect (OSTI)

The Polymer Flood Predictive Model (PFPM) was developed by Scientific Software-Intercomp for the National Petroleum Council's (NPC) 1984 survey of US enhanced oil recovery potential (NPC, 1984). The PFPM is switch-selectable for either polymer or waterflooding, and an option in the model allows the calculation of the incremental oil recovery and economics of polymer relative to waterflooding. The architecture of the PFPM is similar to that of the other predictive models in the series: in-situ combustion, steam drive (Aydelotte and Pope, 1983), chemical flooding (Paul et al., 1982) and CO/sub 2/ miscible flooding (Paul et al., 1984). In the PFPM, an oil rate versus time function for a single pattern is computed and then is passed to the economic calculations. Data for reservoir and process development, operating costs, and a pattern schedule (if multiple patterns are desired) allow the computation of discounted cash flow and other measures of profitability. The PFPM is a three-dimensional (stratified, five-spot), two-phase (water and oil) model which computes water from breakthrough and oil recovery using fractional flow theory, and models areal and vertical sweeps using a streamtube approach. A correlation based on numerical simulation results is used to model the polymer slug size effect. The physical properties of polymer fluids, such as adsorption, permeability reduction, and non-Newtonian effects, are included in the model. Pressure drop between the injector and producer is kept constant, and the injectivity at each time step is calculated based on the mobility in each streamtube. Heterogeneity is accounted for by either entering detailed layer data or using the Dykstra-Parsons coefficient for a reservoir with a log-normal permeability distribution. 24 refs., 27 figs., 59 tabs.

Not Available

1986-12-01T23:59:59.000Z

13

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program-based on advanced reservoir management methods- can significantly improve oil recovery. The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

Murphy, M.B.

1997-10-30T23:59:59.000Z

14

ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

Mark B. Murphy

2003-10-31T23:59:59.000Z

15

ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

Mark B. Murphy

2004-01-31T23:59:59.000Z

16

Nanoparticle technology for heavy oil in-situ upgrading and recovery enhancement: Opportunities and challenges  

Science Journals Connector (OSTI)

Abstract With more than 170 billion barrels of estimated oil sands reserves in Canada, Canada has the third largest oil reserves in the world. However, more than 80% of oil sand’s reserves are located deep underground and could not be accessed by surface mining. Nonetheless, a number of in-situ recovery methods have been developed to extract heavy oil and bitumen from deep reservoirs. Once produced, bitumen is transferred to upgraders converting low quality oil to synthetic crude oil. However, in the present context, heavy oil and bitumen exploitation process is not just high-energy and water intensive, but also it has significant environmental footprints as it produces significant amount of gaseous emissions and wastewater. In addition, the level of contaminants in bitumen requires special equipment, and has also environmental repercussions. Recently, nanotechnology has emerged as an alternative technology for in-situ heavy oil upgrading and recovery enhancement. Nanoparticle catalysts (nanocatalysts) are one of the important examples on nanotechnology applications. Nanocatalysts portray unique catalytic and sorption properties due to their exceptionally high surface area-to-volume ratio and active surface sites. In-situ catalytic conversion or upgrading of heavy oil with the aid of multi-metallic nanocatalysts is a promising cost effective and environmentally friendly technology for production of high quality oils that meet pipeline and refinery specifications. Further, nanoparticles could be employed as inhibitors for preventing or delaying asphaltene precipitation and subsequently enhance oil recovery. Nevertheless, as with any new technologies, there are a number of challenges facing the employment of nanoparticles for in-situ catalytic upgrading and recovery enhancement. The main goal of this article is to provide an overview of nanoparticle technology usage for enhancing the in-situ catalytic upgrading and recovery processes of crude oil. Furthermore, the article sheds lights on the advantages of employment of nanoparticles in heavy oil industry and addresses some of the limitations and challenges facing this new technology.

Rohallah Hashemi; Nashaat N. Nassar; Pedro Pereira Almao

2014-01-01T23:59:59.000Z

17

Enhanced Oil Recovery | Department of Energy  

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

Enhanced Oil Recovery Enhanced Oil Recovery Thanks in part to innovations supported by the Office of Fossil Energy's National Energy Technology Laboratory over the past 30 years,...

18

of oil yields from enhanced oil recovery  

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

oil yields from enhanced oil recovery (EOR) and CO oil yields from enhanced oil recovery (EOR) and CO 2 storage capacity in depleted oil reservoirs. The primary goal of the project is to demonstrate that remaining oil can be economically produced using CO 2 -EOR technology in untested areas of the United States. The Citronelle Field appears to be an ideal site for concurrent CO 2 storage and EOR because the field is composed of sandstone reservoirs

19

ADVANCED OIL RECOVERY TECHNOLOGIES FOR IMPROVED RECOVERY FROM SLOPE BASIN CLASTIC RESERVOIRS, NASH DRAW BRUSHY CANYON POOL, EDDY COUNTY, NM  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program-based on advanced reservoir management methods-can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry. This is the twenty-eighth quarterly progress report on the project. Results obtained to date are summarized.

Mark B. Murphy

2002-09-30T23:59:59.000Z

20

Characterization of oil and gas reservoirs and recovery technology deployment on Texas State Lands  

SciTech Connect (OSTI)

Texas State Lands oil and gas resources are estimated at 1.6 BSTB of remaining mobile oil, 2.1 BSTB, or residual oil, and nearly 10 Tcf of remaining gas. An integrated, detailed geologic and engineering characterization of Texas State Lands has created quantitative descriptions of the oil and gas reservoirs, resulting in delineation of untapped, bypassed compartments and zones of remaining oil and gas. On Texas State Lands, the knowledge gained from such interpretative, quantitative reservoir descriptions has been the basis for designing optimized recovery strategies, including well deepening, recompletions, workovers, targeted infill drilling, injection profile modification, and waterflood optimization. The State of Texas Advanced Resource Recovery program is currently evaluating oil and gas fields along the Gulf Coast (South Copano Bay and Umbrella Point fields) and in the Permian Basin (Keystone East, Ozona, Geraldine Ford and Ford West fields). The program is grounded in advanced reservoir characterization techniques that define the residence of unrecovered oil and gas remaining in select State Land reservoirs. Integral to the program is collaboration with operators in order to deploy advanced reservoir exploitation and management plans. These plans are made on the basis of a thorough understanding of internal reservoir architecture and its controls on remaining oil and gas distribution. Continued accurate, detailed Texas State Lands reservoir description and characterization will ensure deployment of the most current and economically viable recovery technologies and strategies available.

Tyler, R.; Major, R.P.; Holtz, M.H. [Univ. of Texas, Austin, TX (United States)] [and others

1997-08-01T23:59:59.000Z

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


21

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 26, quarter ending March 31, 1981  

SciTech Connect (OSTI)

Objectives and technical progress are summarized for field projects and supporting research in chemical flooding, CO/sub 2/ injection, thermal/heavy oil recovery, resource assessment, extraction technology, microbial enhanced oil recovery, and improved drilling technology. (DLC)

Linville, B. (ed.)

1981-07-01T23:59:59.000Z

22

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress Review No. 31, quarter ending June 30, 1982  

SciTech Connect (OSTI)

Progress reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, resource assessment technology, extraction technology, environmental, petroleum technology, microbial enhanced oil recovery, oil recovery by gravity mining, improved drilling technology, and general supporting research.

Linville, B. (ed.)

1982-10-01T23:59:59.000Z

23

Bartlesville Energy Technology Center enhanced oil recovery project data base  

SciTech Connect (OSTI)

A comprehensive EOR project data base that is validated, integrated, and continuously maintained and updated is being developed at BETC. The data base, which is not currently available to the public, provides an information resource to accelerate the advancement and applications of EOR technology. The primary sources of data have been specific EOR Projects certified in the Incentives Program, the DOE Cost-Shared Tertiary Program, and a data base of ongoing EOR projects supplied by Gulf Universities Research Consortium (GURC). Information from these sources has provided an extensive basis for the development of a comprehensive data base relating the key parameters for EOR projects in the United States. The sources and types of data within the data base are organized in a manner which will facilitate information transfer within the petroleum industry. 28 references, 3 figures, 2 tables.

French, T.R.; Ray, R.M.

1984-01-01T23:59:59.000Z

24

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 28  

SciTech Connect (OSTI)

Highlights of progress during the quarter ending September 30, 1981 are summarized. Field projects and supporting research in the following areas are reported: chemical flooding; carbon dioxide injection; thermal processes/heavy oil (steam and in-situ combustion); resource assessment technology; extraction technology; environmental; petroleum technology; microbial enhanced oil recovery; and improved drilling technology. A list of BETC publications with abstracts, published during the quarter is included. (DMC)

Linville, B.

1982-01-01T23:59:59.000Z

25

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 32, quarter ending September 30, 1982  

SciTech Connect (OSTI)

Progress reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, resource assessment technology, extraction technology, environmental and safety, microbial enhanced oil recovery, oil recovery by gravity mining, improved drilling technology, and general supporting research.

Linville, B. (ed.)

1983-01-01T23:59:59.000Z

26

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 33, quarter ending December 31, 1982  

SciTech Connect (OSTI)

Progress reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, resource assessment technology, extraction technology, environmental and safety, microbial enhanced oil recovery, oil recovery by gravity mining, improved drilling technology, and general supporting research.

Linville, B. (ed.)

1983-04-01T23:59:59.000Z

27

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 36 for quarter ending September 30, 1983  

SciTech Connect (OSTI)

Progress reports for the quarter ending September 30, 1983, are presented for field projects and supported research for the following: chemical flooding; carbon dioxide injection; thermal/heavy oil; resource assessment technology; extraction technology; environmental and safety; microbial enhanced oil recovery; oil recovery by gravity mining; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1984-03-01T23:59:59.000Z

28

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM  

SciTech Connect (OSTI)

The Nash Draw Brushy Canyon Pool in Eddy County New Mexico was a cost-shared field demonstration project in the U.S. Department of Energy Class III Program. A major goal of the Class III Program was to stimulate the use of advanced technologies to increase ultimate recovery from slope-basin clastic reservoirs. Advanced characterization techniques were used at the Nash Draw Pool (NDP) project to develop reservoir management strategies for optimizing oil recovery from this Delaware reservoir. The objective of the project was to demonstrate that a development program, which was based on advanced reservoir management methods, could significantly improve oil recovery at the NDP. Initial goals were (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to other oil and gas producers. Analysis, interpretation, and integration of recently acquired geological, geophysical, and engineering data revealed that the initial reservoir characterization was too simplistic to capture the critical features of this complex formation. Contrary to the initial characterization, a new reservoir description evolved that provided sufficient detail regarding the complexity of the Brushy Canyon interval at Nash Draw. This new reservoir description was used as a risk reduction tool to identify 'sweet spots' for a development drilling program as well as to evaluate pressure maintenance strategies. The reservoir characterization, geological modeling, 3-D seismic interpretation, and simulation studies have provided a detailed model of the Brushy Canyon zones. This model was used to predict the success of different reservoir management scenarios and to aid in determining the most favorable combination of targeted drilling, pressure maintenance, well stimulation, and well spacing to improve recovery from this reservoir. An Advanced Log Analysis technique developed from the NDP project has proven useful in defining additional productive zones and refining completion techniques. This program proved to be especially helpful in locating and evaluating potential recompletion intervals, which has resulted in low development costs with only small incremental increases in lifting costs. To develop additional reserves at lower costs, zones behind pipe in existing wells were evaluated using techniques developed for the Brushy Canyon interval. These techniques were used to complete uphole zones in thirteen of the NDP wells. A total of 14 recompletions were done: four during 1999, four during 2000, two during 2001, and four during 2002-2003. These workovers added reserves of 332,304 barrels of oil (BO) and 640,363 MCFG (thousand cubic feet of gas) at an overall weighted average development cost of $1.87 per BOE (barrel of oil equivalent). A pressure maintenance pilot project in a developed area of the field was not conducted because the pilot area was pressure depleted, and the reservoir in that area was found to be compartmentalized and discontinuous. Economic analyses and simulation studies indicated that immiscible injection of lean hydrocarbon gas for pressure maintenance was not warranted at the NDP and would need to be considered for implementation in similar fields very soon after production has started. Simulation studies suggested that the injection of miscible carbon dioxide (CO{sub 2}) could recover significant quantities of oil at the NDP, but a source of low-cost CO{sub 2} was not available in the area. Results from the project indicated that further development will be under playa lakes and potash areas that were beyond the regions covered by well control and are not accessible with vertical wells. These areas, covered by 3-D seismic surveys that were obtained as part of the project, were accessed with combinations of deviated/horizontal wells. Three directional/horizontal wells have been drilled and completed to develop reserves under surface-restricted areas and potash mines. The third

Mark B. Murphy

2005-09-30T23:59:59.000Z

29

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico, Class III  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

Murphy, Michael B.

2002-02-21T23:59:59.000Z

30

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico, Class III  

SciTech Connect (OSTI)

The overall objective of this project was to demonstrate that a development program-based on advanced reservoir management methods-can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan included developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals were (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the U.S. oil and gas industry.

Murphy, Mark B.

2002-01-16T23:59:59.000Z

31

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 22, quarter ending March 31, 1980  

SciTech Connect (OSTI)

This report contains statements of objectives and summaries of technical progress on all DOE contracts pertaining to enhanced oil recovery and improved drilling techniques. Subject categories include chemical flooding; carbon dioxide injection; thermal recovery of heavy oil; resource assessment; improved drilling technology; residual oil; environmental; petroleum technology; and microbial enhanced oil recovery. An index containing the names of the companies and institutions involved is included. Current publications resulting from the DOE contractual program are listed. (DMC)

Linville, B. (ed.)

1980-07-01T23:59:59.000Z

32

Supporting technology for enhanced oil recovery: Third ammendment and extension to Annex IV enhanced oil recovery thermal processes  

SciTech Connect (OSTI)

This report contains the results of efforts under the seven tasks of the Third Amendment and Extension of Annex IV, Enhanced Oil Recovery Thermal Processes of the Venezuela/USA Agreement. The report is presented in sections (for each of the tasks) and each section contains one or more reports prepared by various individuals or groups describing the results of effort under each of the tasks. A statement of each task, taken from the agreement, is presented on the first page of each section. The tasks are numbered 25 through 31. The first, second, and third reports on Annex IV, ((Venezuela-MEM/USA-DOE Fossil Energy Report IV-1, IV-2, and IV-3 (DOE/BETC/SP-83/15, DOE/BC-84/6/SP, and DOE/BC-86/2/SP)) contain the results from the first 24 tasks. Those reports are dated April 1983, August 1984, and March 1986. Selected papers have been processed for inclusion in the Energy Data Base.

Peterson, G.; Munoz, J.D.

1987-07-01T23:59:59.000Z

33

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM  

SciTech Connect (OSTI)

The Nash Draw Brushy Canyon Pool in Eddy County New Mexico is a cost-shared field demonstration project in the US Department of Energy Class II Program. A major goal of the Class III Program is to stimulate the use of advanced technologies to increase ultimate recovery from slope-basin clastic reservoirs. Advanced characterization techniques are being used at the Nash Draw project to develop reservoir management strategies for optimizing oil recovery from this Delaware reservoir. Analysis, interpretation, and integration of recently acquired geologic, geophysical, and engineering data revealed that the initial reservoir characterization was too simplistic to capture the critical features of this complex formation. Contrary to the initial characterization, a new reservoir description evolved that provided sufficient detail regarding the complexity of the Brushy Canyon interval at Nash Draw. This new reservoir description is being used as a risk reduction tool to identify ''sweet spots'' for a development drilling program as well as to evaluate pressure maintenance strategies. The reservoir characterization, geological modeling, 3-D seismic interpretation, and simulation studies have provided a detailed model of the Brushy Canyon zones. This model was used to predict the success of different reservoir management scenarios and to aid in determining the most favorable combination of targeted drilling, pressure maintenance, well simulation, and well spacing to improve recovery from this reservoir.

Murphy, Mark B.

1999-02-24T23:59:59.000Z

34

RMOTC - Testing - Enhanced Oil Recovery  

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

Enhanced Oil Recovery Enhanced Oil Recovery Notice: As of July 15th 2013, the Department of Energy announced the intent to sell Naval Petroleum Reserve Number 3 (NPR3). The sale of NPR-3 will also include the sale of all equipment and materials onsite. A decision has been made by the Department of Energy to complete testing at RMOTC by July 1st, 2014. RMOTC will complete testing in the coming year with the currently scheduled testing partners. For more information on the sale of NPR-3 and sale of RMOTC equipment and materials please join our mailing list here. RMOTC will play a significant role in continued enhanced oil recovery (EOR) technology development and field demonstration. A scoping engineering study on Naval Petroleum Reserve No. 3's (NPR-3) enhanced oil recovery

35

Outlook for enhanced oil recovery  

SciTech Connect (OSTI)

This paper reviews the potential for enhanced oil recovery, the evolutionary nature of the recovery processes being applied in oilfields today, key parameters that describe the technology state-of-the-art for each of the major oil recovery processes, and the nature and key outputs from the current Department of Energy research program on enhanced oil recovery. From this overview, it will be seen that the DOE program is focused on the analysis of ongoing tests and on long-range, basic research to support a more thorough understanding of process performance. Data from the program will be made available through reports, symposia, and on-line computer access; the outputs are designed to allow an independent producer to evaluate his own project as an effort to transfer rapidly the technology now being developed.

Johnson, H.R.

1982-01-01T23:59:59.000Z

36

Determination of technology transfer requirements for enhanced oil recovery. Final report  

SciTech Connect (OSTI)

A detailed field study was conducted to determine the technical information needs of current and potential users of enhanced oil recovery data. Under the direction of the Bartlesville Energy Technology Center (BETC), the study (1) identifies groups which have a need for EOR-related information, (2) delineate the specific information needs of each user-group, and (3) outlines methods for improved transfer of appropriate information to the end users. This study also assesses attitudes toward the EOR-related efforts of the US Department of Energy (DOE) and the BETC, and the role each should play in facilitating the commercialization of EOR processes. More than 300 users and potential users of EOR information were surveyed. Included in the survey sample were representatives of major oil companies, independent oil companies, engineering consulting firms, university and private research organizations, financial institutions and federal, state, and local policy-making bodies. In-depth questionnaires were specifically designed for each group. This study analyzes each group's position pertaining to (1) current level of EOR activity or interest, (2) current and projected EOR information needs, (3) assessments of the BETC's current information services and suggestions for improvement, (4) delineation of technical and economic constraints to increased EOR activity, and (5) steps the DOE might take to enhance the attractiveness of commercial EOR operations.

Wilson, T.D.; Scott, J.P.

1980-09-01T23:59:59.000Z

37

Contracts and grants for cooperative research on enhanced oil recovery and improved drilling technology. Progress review No. 20, quarter ending September 30, 1979  

SciTech Connect (OSTI)

The contracts and grants for field projects and supporting research on enhanced oil recovery and improved drilling technology are arranged according to: chemical flooding; carbon dioxide injection; thermal/heavy oil; resource assessment technology; improved drilling technology; residual oil; environmental; and petroleum techology.

Linville, B. (ed.)

1980-01-01T23:59:59.000Z

38

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 34, quarter ending March 31, 1983  

SciTech Connect (OSTI)

Progress achieved for the quarter ending March 1983 are presented for field projects and supporting research for the following: chemical flooding; carbon dioxide injection; and thermal/heavy oil. In addition, progress reports are presented for: resource assessment technology; extraction technology; environmental and safety; microbial enhanced oil recovery; oil recovered by gravity mining; improved drilling technology; and general supporting research. (ATT)

Linville, B. (ed.) [ed.

1983-07-01T23:59:59.000Z

39

Optimize carbon dioxide sequestration, enhance oil recovery  

E-Print Network [OSTI]

- 1 - Optimize carbon dioxide sequestration, enhance oil recovery January 8, 2014 Los Alamos simulation to optimize carbon dioxide (CO2) sequestration and enhance oil recovery (CO2-EOR) based on known production. Due to carbon capture and storage technology advances, prolonged high oil prices

40

Imbibition assisted oil recovery  

E-Print Network [OSTI]

analyzed in detail to investigate oil recovery during spontaneous imbibition with different types of boundary conditions. The results of these studies have been upscaled to the field dimensions. The validity of the new definition of characteristic length...

Pashayev, Orkhan H.

2004-11-15T23:59:59.000Z

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


41

Progress review No. 24: contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress report, quarter ending September 30, 1980  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection and thermal/heavy oil, as well as for the following areas of research: extraction technology; resource assessment technology; environmental; petroleum technology; microbial enhanced oil recovery; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1981-02-01T23:59:59.000Z

42

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM  

SciTech Connect (OSTI)

Advanced reservoir characterization techniques are being used at the Nash Draw Brushy Canyon Pool project to develop reservoir management strategies for optimizing oil recovery from this Delaware reservoir. The reservoir characterization, geologic modeling, 3-D seismic interpretation, and simulation studies have provided a detailed model of the Brushy Canyon zones. This model was used to predict the success of different reservoir management scenarios and to aid in determining the most favorable combination of targeted drilling, pressure maintenance, well stimulation, and well spacing to improve recovery from this reservoir.

Murphy, M.B.

1999-02-01T23:59:59.000Z

43

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 35, quarter ending June 30, 1983  

SciTech Connect (OSTI)

Progress reports are presented for field projects and supporting research for the following: chemical flooding; carbon dioxide injection; thermal/heavy oil; resource assessment technology; extraction technology; environmental and safety; microbial enhanced oil recovery; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1983-10-01T23:59:59.000Z

44

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 30, quarter ending March 31, 1982  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, as well as for the following areas of research: resource assessment technology; extraction technology; microbial enhanced oil recovery; improved drilling technology, and general supporting research.

Linville, B. (ed.)

1982-07-01T23:59:59.000Z

45

Progress review No. 25: contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress report, quarter ending December 31, 1980  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, as well as for the following areas of research: resource assessment technology; extraction technology; environmental; microbial enhanced oil recovery; improving drilling technology; and general supporting research.

Linville, B. (ed.)

1981-05-01T23:59:59.000Z

46

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 27, for quarter ending June 30, 1981  

SciTech Connect (OSTI)

Reports are presented of contracts for field projects and supporting research on chemical flooding, carbon dioxide injection, thermal/heavy oil, as well as for the following areas of research: resource assessment technology; extraction technology; environmental; microbial enhanced oil recovery; improved drilling technology; and general supporting research.

Linville, B. (ed.)

1981-09-01T23:59:59.000Z

47

New surfactant classes for enhanced oil recovery and their tertiary oil recovery potential  

E-Print Network [OSTI]

commercial scale projects were also executed. Nowadays, because of the high oil price, this technology hasNew surfactant classes for enhanced oil recovery and their tertiary oil recovery potential Stefan States a b s t r a c ta r t i c l e i n f o Article history: Received 23 February 2009 Accepted 14

Goddard III, William A.

48

Enhanced Oil Recovery and Other Oil Resources projects  

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

Enhanced Oil Recovery and Other Oil Resources Enhanced Oil Recovery and Other Oil Resources Enhanced Oil Recovery and Other Oil Resources CO2 EOR | Other EOR & Oil Resources | Environmental | Completed Oil Projects Project Number Project Name Primary Performer DE-FE0013723 Development of Nanoparticle-Stabilized Foams To Improve Performance of Water-less Hydraulic Fracturing The University of Texas at Austin DE-FE0010799 Small Molecular Associative Carbon Dioxide (CO2) Thickeners for Improved Mobility Control University of Pittsburgh DE-FE0006011 Development of Real Time Semi-autonomous Geophysical Data Acquisition and Processing System to Monitor Flood Performance White River Technologies DE-FE0005979 Nanoparticle-stabilized CO2 Foam for CO2 EOR Application New Mexico Institute of Mining and Technology

49

Supporting technology for enhanced oil recovery: EOR thermal processes. Seventh Amendment and Extension to Annex 4, Enhanced oil recovery thermal processes  

SciTech Connect (OSTI)

This report contains the results of efforts under the six tasks of the Seventh Amendment and Extension of Annex IV, Enhanced Oil Recovery Thermal Processes of the Venezuela/USA Agreement. The report is presented in sections (for each of the 6 tasks) and each section contains one or more reports prepared by various individuals or groups describing the results of efforts under each of the tasks. A statement of each task, taken from the agreement, is presented on the first page of each section. The tasks are numbered 50 through 55. The first, second, third, fourth, fifth, sixth and seventh reports on Annex IV, Venezuela MEM/USA-DOE Fossil Energy Report IV-1, IV-2, IV-3, IV-4, IV-5 and IV-6 (DOE/BETC/SP-83/15, DOE/BC-84/6/SP, DOE/BC-86/2/SP, DOE/BC-87/2/SP, DOE/BC-89/l/SP, DOE/BC-90/l/SP, and DOE/BC-92/l/SP) contain the results for the first 49 tasks. Those reports are dated April 1983, August 1984, March 1986, July 1987, November 1988, December 1989, and October 1991, respectively. Each task report has been processed separately for inclusion in the Energy Science and Technology Database.

Reid, T B [USDOE Bartlesville Project Office, OK (United States)] [USDOE Bartlesville Project Office, OK (United States); Colonomos, P [INTEVEP, Filial de Petroleos de Venezuela, SA, Caracas (Venezuela)] [INTEVEP, Filial de Petroleos de Venezuela, SA, Caracas (Venezuela)

1993-02-01T23:59:59.000Z

50

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 29, quarter ending December 31, 1981  

SciTech Connect (OSTI)

Highlights of progress accomplished during the quarter ending December, 1981, are summarized in this report. Discussion is presented under the following headings: chemical flooding - field projects; chemical flooding - supporting research; carbon dioxide injection - field projects; carbon dioxide injection - supporting research; thermal/heavy oil - field projects and supporting research; resource assessment technology; extraction technology; environmental aspects; petroleum processing technology; microbial enhanced oil recovery; and improved drilling technology. (DMC)

Linville, B. (ed.)

1982-05-01T23:59:59.000Z

51

Fossil Energy Research Benefits Enhanced Oil Recovery  

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

Energy Research Benefits Energy Research Benefits Enhanced Oil Recovery EOR helps increase domestic oil supplies while also providing a way to safely and permanently store CO 2 underground. Enhanced Oil Recovery (EOR) is a way to squeeze out additional, hard- to-recover barrels of oil remaining in older fields following conventional production operations. It can also be used to permanently store carbon dioxide (CO 2 ) underground. Thanks in part to innovations supported by the Office of Fossil Energy's National Energy Technology Laboratory (NETL) over the past 30 years, the United States is a world leader in the number of EOR projects (200) and volume of oil production (over

52

Enhanced Oil Recovery | Department of Energy  

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

Enhanced Oil Recovery Enhanced Oil Recovery Cross-section illustrating how carbon dioxide and water can be used to flush residual oil from a subsurface rock formation between...

53

Effects of Microwave Radiation on Oil Recovery  

Science Journals Connector (OSTI)

A variety of oil recovery methods have been developed and applied to mature and depleted reservoirs in order to improve the efficiency. Microwave radiation oil recovery method is a relatively new method and has been of great interest in the recent years. Crude oil is typically co?mingled with suspended solids and water. To increase oil recovery it is necessary to remove these components. The separation of oil from water and solids using gravitational settling methods is typically incomplete. Oil?in?water and oil?water?solid emulsions can be demulsified and separated into their individual layers by microwave radiation. The data also show that microwave separation is faster than gravity separation and can be faster than conventional heating at many conditions. After separation of emulsion into water and oil layers water can be discharged and oil is collected. High?frequency microwave recycling process can recover oil and gases from oil shale residual oil drill cuttings tar sands oil contaminated dredge/sediments tires and plastics with significantly greater yields and lower costs than are available utilizing existing known technologies. This process is environmentally friendly fuel?generating recycler to reduce waste cut emissions and save energy. This paper presents a critical review of Microwave radiation method for oil recovery.

2011-01-01T23:59:59.000Z

54

Biochemically enhanced oil recovery and oil treatment  

DOE Patents [OSTI]

This invention relates to the preparation of new, modified organisms, through challenge growth processes, that are viable in the extreme temperature, pressure and pH conditions and salt concentrations of an oil reservoir and that are suitable for use in microbial enhanced oil recovery. The modified microorganisms of the present invention are used to enhance oil recovery and remove sulfur compounds and metals from the crude oil. 62 figures.

Premuzic, E.T.; Lin, M.

1994-03-29T23:59:59.000Z

55

Biochemically enhanced oil recovery and oil treatment  

DOE Patents [OSTI]

This invention relates to the preparation of new, modified organisms, through challenge growth processes, that are viable in the extreme temperature, pressure and pH conditions and salt concentrations of an oil reservoir and that are suitable for use in microbial enhanced oil recovery. The modified microorganisms of the present invention are used to enhance oil recovery and remove sulfur compounds and metals from the crude oil.

Premuzic, Eugene T. (East Moriches, NY); Lin, Mow (Rocky Point, NY)

1994-01-01T23:59:59.000Z

56

Horizontal oil well applications and oil recovery assessment. Volume 1: Success of horizontal well technology, Final report  

SciTech Connect (OSTI)

Horizontal technology has been applied in over 110 formations in the USA. Volume I of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i.e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the USA. and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the USA. and 88 in Canada. Operators responses were analyzed for trends in technical and economic success based on lithology (clastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed.

Deskins, W.G.; McDonald, W.J.; Knoll, R.G.; Springer, S.J.

1995-03-01T23:59:59.000Z

57

Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report (seventh quarter), April 1--June 30, 1997  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program -- based on advanced reservoir management methods -- can significantly improve oil recovery. The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the US oil and gas industry. Results obtained to date are summarized.

NONE

1997-07-30T23:59:59.000Z

58

Supporting Technology for Enhanced Oil Recovery-EOR Thermal Processes Report IV-12  

SciTech Connect (OSTI)

This report contains the results of efforts under the six tasks of the Ninth Amendment and Extension of Annex IV, Enhanced Oil Recovery Thermal Processes of the Venezuela/USA Agreement. The report is presented in sections (for each of the 6 tasks) and each section contains one or more reports prepared by various individuals or groups describing the results of efforts under each of the tasks. A statement of each task, taken from the agreement, is presented on the first page of each section. The tasks are numbered 62 through 67. The first, second, third, fourth, fifth, sixth, seventh, eight, and ninth reports on Annex IV, [Venezuela MEM/USA-DOE Fossil Energy Report IV-1, IV-2, IV-3, IV-4, IV-5, IV-6, IV-7, and IV-8 (DOE/BETC/SP-83/15, DOE/BC-84/6/SP, DOE/BC-86/2/SP, DOE/BC-87/2/SP, DOE/BC-89/1/SP, DOE/BC-90/1/SP) DOE/BC-92/1/SP, DOE/BC-93/3/SP, and DOE/BC-95/3/SP] contain the results from the first 61 tasks. Those reports are dated April 1983, August 1984, March 1986, July 1! 987, November 1988, December 1989, October 1991, February 1993, and March 1995 respectively.

Izequeido, Alexandor

2001-04-01T23:59:59.000Z

59

Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report, January 1--March 31, 1998  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program--based on advanced reservoir management methods--can significantly improve oil recovery at the Nash Draw Pool (NDP). The plan includes developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the US oil and gas industry. Results obtained to date are summarized for the following: geostatistics and reservoir mapping; reservoir engineering; reservoir characterization/reservoir simulation; miscible recovery simulations; and technology transfer.

NONE

1998-04-30T23:59:59.000Z

60

Advanced Oil Recovery Technologies for Improved Recovery From Slope Basin Clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico  

SciTech Connect (OSTI)

The overall goal of this project is to demonstrate that an advanced development drilling and pressure maintenance program based on advanced reservoir management methods can significantly improve oil recovery. The plan included developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced methods. A key goal is to transfer advanced methodologies to oil and gas producers in the Permian Basin and elsewhere, and throughout the US oil and gas industry.

Mark B. Murphy

1998-04-30T23:59:59.000Z

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


61

Advanced Oil Recovery Technologies for Improved Recovery From Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico  

SciTech Connect (OSTI)

The overall goal of this project is to demonstrate that an advanced development drilling and pressure maintenance program based on advanced reservoir management methods can significantly improve oil recovery. The plan included developing a control area using standard reservoir management techniques and comparing its performance to an area developed using advanced methods. A key goal is to transfer advanced methodologies to oil and gas producers in the Permian Basin and elsewhere, and throughout the US oil and gas industry.

Mark B. Murphy

1997-04-30T23:59:59.000Z

62

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 (OSTI)

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.

Ernest A. Mancini

2003-05-20T23:59:59.000Z

63

Summary - Caustic Recovery Technology  

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

Caustic Recovery Technology Caustic Recovery Technology ETR Report Date: July 2007 ETR-7 United States Department of Energy Office of Environmental Management (DOE-EM) External Technical Review of Caustic Recovery Technology Why DOE-EM Did This Review The Department of Energy (DOE) Environmental Management Office (EM-21) has been developing caustic recovery technology for application to the Hanford Waste Treatment Plant (WTP) to reduce the amount of Low Activity Waste (LAW) vitrified. Recycle of sodium hydroxide with an efficient caustic recovery process could reduce the amount of waste glass produced by greater than 30%. The Ceramatec Sodium (Na), Super fast Ionic CONductors (NaSICON) membrane has shown promise for directly producing 50% caustic with high sodium selectivity. The external review

64

Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report, October 1--December 31, 1996 (fifth quarter)  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program--based on advanced reservoir management methods--can significantly improve oil recovery. The plan includes developing a control area using standard reservoir management techniques while comparing its performance to an area developed using advanced reservoir management methods. Specific goals are (1) to demonstrate that an advanced development drilling and pressure maintenance program, can significantly improve oil recovery compared to existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers in the Permian Basin and elsewhere throughout the US oil and gas industry. Results so far are described on geology, engineering, 3-D seismic, reservoir characterization and simulation, and technology transfer.

NONE

1997-01-31T23:59:59.000Z

65

Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report, July 1--September 30, 1996 (fourth quarter)  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery. The demonstration plan includes developing a control area using standard reservoir management techniques and comparing the performance of the control area with an area developed using advanced reservoir management methods. Specific goals to attain the objective are: (1) to demonstrate that a development drilling program and pressure maintenance program, based on advanced reservoir management methods, can significantly improve oil recovery compared with existing technology applications, and (2) to transfer the advanced methodologies to oil and gas producers in the Permian Basin and elsewhere in the US oil and gas industry. Results obtained to date are summarized on the following: geology, engineering, 3-D seismic, reservoir characterization and simulation, and technology transfer.

NONE

1996-10-31T23:59:59.000Z

66

Review of ASP EOR (alkaline surfactant polymer enhanced oil recovery) technology in the petroleum industry: Prospects and challenges  

Science Journals Connector (OSTI)

Abstract Owing to the inefficiency of the conventional primary and secondary recovery methods to yield above 20–40% of the OOIP (original oil in place) as incremental oil, the need for EOR (Enhanced Oil Recovery) techniques to recover a higher proportion of the OOIP has become imperative. ASP (Alkaline/Surfactant/Polymer) is one of such techniques that has proven successful due to its ability to improve displacement and sweep efficiency. Alkaline–surfactant–polymer (ASP) flooding is a combination process in which alkali, surfactant and polymer are injected at the same slug. Because of the synergy of these three components, ASP is widely practiced in both pilot and field operations with the objective of achieving optimum chemistry at large injection volumes for minimum cost. Despite its popularity as a potentially cost-effective chemical flooding method, it is not without its limitations. This paper therefore focuses on the reviews of the application of ASP flooding process in oil recovery in the petroleum industry and its limitations in maximizing oil recovery from onshore and offshore reservoirs. Also discussed are technical solutions to some of these challenges.

Abass A. Olajire

2014-01-01T23:59:59.000Z

67

Enhanced Oil Recovery | Department of Energy  

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

Enhanced Oil Recovery Enhanced Oil Recovery Enhanced Oil Recovery Cross-section illustrating how carbon dioxide and water can be used to flush residual oil from a subsurface rock formation between wells. Cross-section illustrating how carbon dioxide and water can be used to flush residual oil from a subsurface rock formation between wells. Crude oil development and production in U.S. oil reservoirs can include up to three distinct phases: primary, secondary, and tertiary (or enhanced) recovery. During primary recovery, the natural pressure of the reservoir or gravity drive oil into the wellbore, combined with artificial lift techniques (such as pumps) which bring the oil to the surface. But only about 10 percent of a reservoir's original oil in place is typically produced during primary recovery. Secondary recovery techniques extend a

68

Caustic Recovery Technology | Department of Energy  

Office of Environmental Management (EM)

Caustic Recovery Technology Caustic Recovery Technology Full Document and Summary Versions are available for download Caustic Recovery Technology Summary - Caustic Recovery...

69

Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report, April 1, 1996--June 30, 1996  

SciTech Connect (OSTI)

The overall objective of this project is to demonstrate that a development program based on advanced reservoir management methods can significantly improve oil recovery. The demonstration plan includes developing a control area using standard reservoir management techniques and comparing the performance of the control area with an area developed using advanced reservoir management methods. Specific goals to attain the objective are: (1) to demonstrate that a development drilling program and pressure maintenance program, based on advanced reservoir management methods, can significantly improve oil recovery compared with existing technology applications, and (2) to transfer the advanced methodologies to oil and gas producers in the Permian Basin and elsewhere in the U.S. oil and gas industry.

Murphy, M.B.

1996-07-26T23:59:59.000Z

70

Microbial enhancement of oil recovery: Recent advances  

SciTech Connect (OSTI)

During recent years, systematic, scientific, and engineering effort by researchers in the United States and abroad, has established the scientific basis for Microbial Enhanced Oil Recovery (MEOR) technology. The successful application of MEOR technology as an oil recovery process is a goal of the Department of Energy (DOE). Research efforts involving aspects of MEOR in the microbiological, biochemical, and engineering fields led DOE to sponsor an International Conference at Brookhaven National Laboratory in 1992, to facilitate the exchange of information and a discussion of ideas for the future research emphasis. At this, the Fourth International MEOR Conference, where international attendees from 12 countries presented a total of 35 papers, participants saw an equal distribution between research'' and field applications.'' In addition, several modeling and state-of-the-art'' presentations summed up the present status of MEOR science and engineering. Individual papers in this proceedings have been process separately for inclusion in the Energy Science and Technology Database.

Premuzic, E.T.; Woodhead, A.D.; Vivirito, K.J. (eds.)

1992-01-01T23:59:59.000Z

71

Shale oil recovery process  

DOE Patents [OSTI]

A process of producing within a subterranean oil shale deposit a retort chamber containing permeable fragmented material wherein a series of explosive charges are emplaced in the deposit in a particular configuration comprising an initiating round which functions to produce an upward flexure of the overburden and to initiate fragmentation of the oil shale within the area of the retort chamber to be formed, the initiating round being followed in a predetermined time sequence by retreating lines of emplaced charges developing further fragmentation within the retort zone and continued lateral upward flexure of the overburden. The initiating round is characterized by a plurality of 5-spot patterns and the retreating lines of charges are positioned and fired along zigzag lines generally forming retreating rows of W's. Particular time delays in the firing of successive charges are disclosed.

Zerga, Daniel P. (Concord, CA)

1980-01-01T23:59:59.000Z

72

A field laboratory for improved oil recovery  

SciTech Connect (OSTI)

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.

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

1992-09-01T23:59:59.000Z

73

Method for enhanced oil recovery  

DOE Patents [OSTI]

The present invention is directed to an improved method for enhanced recovery of oil from relatively "cold" reservoirs by carbon dioxide flooding. In oil reservoirs at a temperature less than the critical temperature of 87.7.degree. F. and at a pore pressure greater than the saturation pressure of carbon dioxide at the temperature of the reservoir, the carbon dioxide remains in the liquid state which does not satisfactorily mix with the oil. However, applicants have found that carbon dioxide can be vaporized in situ in the reservoir by selectively reducing the pore pressure in the reservoir to a value less than the particular saturated vapor pressure so as to greatly enhance the mixing of the carbon dioxide with the oil.

Comberiati, Joseph R. (Morgantown, WV); Locke, Charles D. (Morgantown, WV); Kamath, Krishna I. (Chicago, IL)

1980-01-01T23:59:59.000Z

74

Enhanced oil recovery projects data base  

SciTech Connect (OSTI)

A comprehensive enhanced oil recovery (EOR) project data base is maintained and updated at the Bartlesville Project Office of the Department of Energy. This data base provides an information resource that is used to analyze the advancement and application of EOR technology. The data base has extensive information on 1,388 EOR projects in 569 different oil fields from 1949 until the present, and over 90% of that information is contained in tables and graphs of this report. The projects are presented by EOR process, and an index by location is provided.

Pautz, J.F.; Sellers, C.A.; Nautiyal, C.; Allison, E.

1992-04-01T23:59:59.000Z

75

Enhanced Oil Recovery to Fuel Future Oil Demands | GE Global...  

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

to Fuel Future Oil Demands Enhanced Oil Recovery to Fuel Future Oil Demands Trevor Kirsten 2013.10.02 I'm Trevor Kirsten and I lead a team of GE researchers that investigate a...

76

Applications of advanced petroleum production technology and water alternating gas injection for enhanced oil recovery - Mattoon Oil Field, Illinois. Final report  

SciTech Connect (OSTI)

Phase I results of a C0{sub 2}-assisted oil recovery demonstration project in selected Cypress Sandstone reservoirs at Mattoon Field, Illinois are reported. The design and scope of this project included C0{sub 2} injectvity testing in the Pinnell and Sawyer units, well stimulaton treatments with C0{sub 2} in the Strong unit and infill well drilling, completion and oil production. The field activities were supported by extensive C0{sub 2}-oil-water coreflood experiments, CO{sub 2} oil-phase interaction experiments, and integrated geologic modeling and reservoir simulations. The progress of the project was made public through presentations at an industry meeting and a DOEs contractors` symposium, through quarterly reports and one-to-one consultations with interested operators. Phase II of this project was not implemented. It would have been a water-alternating-gas (WAG) project of longer duration.

Baroni, M. [American Oil Recovery, Inc., Decatur, IL (United States)

1995-09-01T23:59:59.000Z

77

CO2 Enhanced Oil Recovery Feasibility Evaluation for East Texas Oil Field  

E-Print Network [OSTI]

Carbon dioxide enhanced oil recovery (CO2-EOR) has been undergoing for four decades and is now a proven technology. CO2-EOR increases oil recovery, and in the meantime reduces the greenhouse gas emissions by capture CO2 underground. The objectives...

Lu, Ping

2012-08-31T23:59:59.000Z

78

Enhanced oil recovery using hydrogen peroxide injection  

SciTech Connect (OSTI)

NOVATEC received an US Patent on a novel method to recovery viscous oil by hydrogen peroxide injection. The process appears to offer several significant improvements over existing thermal methods of oil recovery. Tejas joined NOVATEC to test the process in the laboratory and to develop oil field applications and procedures.

Moss, J.T. Jr.; Moss, J.T.

1995-02-01T23:59:59.000Z

79

Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico. Annual report, September 25, 1995--September 24, 1996  

SciTech Connect (OSTI)

The basic driver for this project is the low recovery observed in Delaware reservoirs, such as the Nash Draw Pool (NDP). This low recovery is caused by low reservoir energy, less than optimum permeabilities and porosities, and inadequate reservoir characterization and reservoir management strategies which are typical of projects operated by independent producers. Rapid oil decline rates and high gas/oil ratios are typically observed in the first year of primary production. Based on the production characteristics that have been observed in similar Delaware fields, pressure maintenance is a likely requirement at the Nash Pool. Three basic constraints to producing the Nash Draw Brushy Canyon Reservoir are: (1) limited areal and interwell geologic knowledge, (2) lack of an engineering tool to evaluate the various producing strategies, and (3) limited surface access prohibiting development with conventional drilling. The limited surface access is caused by the proximity of underground potash mining and surface playa lakes. The objectives of this project are: (1) to demonstrate that a development drilling program and pressure maintenance program, based on advanced reservoir management methods, can significantly improve oil recovery compared with existing technology applications and (2) to transfer these advanced methodologies to oil and gas producers, especially in the Permian Basin.

Murphy, M.B.

1997-08-01T23:59:59.000Z

80

Contracts for field projects and supporting research on enhanced oil recovery and improved drilling technology. Progress review No. 21, quarter ending December 31, 1979  

SciTech Connect (OSTI)

Individual report are presented of contracts for field projects and supporting research on chemical flooding, CO/sub 2/ injection, thermal/heavy oil, resource assessment technology, improved drilling technology, residual oil, environment, and petroleum technology. (DLC)

Linville, B. (ed.)

1980-04-01T23:59:59.000Z

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


81

Caustic Recovery Technology  

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

366, REVISON 0 366, REVISON 0 Key Words: Waste Treatment Plant Sodium Recovery Electrochemical Retention: Permanent Review of Ceramatec's Caustic Recovery Technology W. R. Wilmarth D. T. Hobbs W. A. Averill E. B. Fox R. A. Peterson UNCLASSIFIED DOES NOT CONTAIN UNCLASSIFIED CONTROLLED NUCLEAR INFORMATION ADC & Reviewing Official:_______________________________________ (E. Stevens, Manager, Solid Waste and Special Programs) Date:______________________________________ JULY 20, 2007 Washington Savannah River Company Savannah River Site Aiken, SC 29808 Prepared for the U. S. Department of Energy Under Contract Number DE-AC09-96SR18500 Page 1 of 28 WSRC-STI-2007-00366, REVISON 0 DISCLAIMER This report was prepared for the United States Department of Energy under

82

Starting Up Microbial Enhanced Oil Recovery  

Science Journals Connector (OSTI)

This chapter gives the reader a practical introduction into microbial enhanced oil recovery (MEOR) including the microbial production of natural gas from oil. Decision makers who consider the use of one of the...

Michael Siegert; Jana Sitte; Alexander Galushko; Martin Krüger

2014-01-01T23:59:59.000Z

83

NETL: News Release - DOE Oil Recovery Project Extends Success through  

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

5 , 2007 5 , 2007 DOE Oil Recovery Project Extends Success through Technology Transfer New Technologies & Techniques Boost U.S. Proved Oil Reserves, Travel the Globe WASHINGTON, DC - A groundbreaking oil-recovery project funded by the U.S. Department of Energy (DOE) is coming to a close, but its success will continue to be felt throughout the United States and the world. MORE INFO Read 03.10.06 Techline: DOE-Funded Project Revives Aging California Oilfield The project, titled "Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterizations and Thermal Production Technologies," began in 1995 with the goal of increasing recoverable heavy oil reserves in those sections of the Wilmington oilfield operated by Long

84

Advanced Oil Recovery Technologies for Improved Recovery from Slope Basin Clastic Reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, New Mexico, Class III  

SciTech Connect (OSTI)

The Nash Draw Brushy Canyon Pool (NDP) is southeast New Mexico is one of the nine projects selected in 1995 by the U.S. Department of Energy (DOE) for participation in the Class III Reservoir Field Demonstration Program. The goals of the DOE cost-shared Class Program are to: (1) extend economic production, (2) increase ultimate recovery, and (3) broaden information exchange and technology application. Reservoirs in the Class III Program are focused on slope-basin and deep-basin clastic depositional types.

Murphy, Mark B.

2000-10-25T23:59:59.000Z

85

Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration...  

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

Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration. Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration. Abstract: A novel EOR method using...

86

Alabama Injection Project Aimed at Enhanced Oil Recovery, Testing...  

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

Alabama Injection Project Aimed at Enhanced Oil Recovery, Testing Important Geologic CO2 Storage Alabama Injection Project Aimed at Enhanced Oil Recovery, Testing Important...

87

Microbial enhanced oil recovery and compositions therefor  

DOE Patents [OSTI]

A method is provided for microbial enhanced oil recovery, wherein a combination of microorganisms is empirically formulated based on survivability under reservoir conditions and oil recovery efficiency, such that injection of the microbial combination may be made, in the presence of essentially only nutrient solution, directly into an injection well of an oil bearing reservoir having oil present at waterflood residual oil saturation concentration. The microbial combination is capable of displacing residual oil from reservoir rock, which oil may be recovered by waterflooding without causing plugging of the reservoir rock. Further, the microorganisms are capable of being transported through the pores of the reservoir rock between said injection well and associated production wells, during waterflooding, which results in a larger area of the reservoir being covered by the oil-mobilizing microorganisms.

Bryant, Rebecca S. (Bartlesville, OK)

1990-01-01T23:59:59.000Z

88

HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS  

SciTech Connect (OSTI)

This technical progress report describes work performed from April 1 through June 30, 2002, for the project ''Heavy and Thermal Oil Recovery Production Mechanisms.'' We investigate a broad spectrum of topics related to thermal and heavy-oil recovery. Significant results were obtained in the areas of multiphase flow and rock properties, hot-fluid injection, improved primary heavy oil recovery, and reservoir definition. The research tools and techniques used are varied and span from pore-level imaging of multiphase fluid flow to definition of reservoir-scale features through streamline-based history-matching techniques. Briefly, experiments were conducted to image at the pore level matrix-to-fracture production of oil from a fractured porous medium. This project is ongoing. A simulation studied was completed in the area of recovery processes during steam injection into fractured porous media. We continued to study experimentally heavy-oil production mechanisms from relatively low permeability rocks under conditions of high pressure and high temperature. High temperature significantly increased oil recovery rate and decreased residual oil saturation. Also in the area of imaging production processes in laboratory-scale cores, we use CT to study the process of gas-phase formation during solution gas drive in viscous oils. Results from recent experiments are reported here. Finally, a project was completed that uses the producing water-oil ratio to define reservoir heterogeneity and integrate production history into a reservoir model using streamline properties.

Anthony R. Kovscek

2002-07-01T23:59:59.000Z

89

Evolution of seismic velocities in heavy oil sand reservoirs during thermal recovery process  

E-Print Network [OSTI]

1 Evolution of seismic velocities in heavy oil sand reservoirs during thermal recovery process localiser la chambre Ă  vapeur. INTRODUCTION [1] Huge quantities of heavy oils (heavy oil, extra heavy oil. Larribau 64018 Pau Cedex, France Oil and Gas Science and Technology 2012, 67 (6), 1029-1039, doi:10

Paris-Sud XI, Université de

90

Oil shale technology  

SciTech Connect (OSTI)

Oil shale is undoubtedly an excellent energy source that has great abundance and world-wide distribution. Oil shale industries have seen ups and downs over more than 100 years, depending on the availability and price of conventional petroleum crudes. Market forces as well as environmental factors will greatly affect the interest in development of oil shale. Besides competing with conventional crude oil and natural gas, shale oil will have to compete favorably with coal-derived fuels for similar markets. Crude shale oil is obtained from oil shale by a relatively simple process called retorting. However, the process economics are greatly affected by the thermal efficiencies, the richness of shale, the mass transfer effectiveness, the conversion efficiency, the design of retort, the environmental post-treatment, etc. A great many process ideas and patents related to the oil shale pyrolysis have been developed; however, relatively few field and engineering data have been published. Due to the vast heterogeneity of oil shale and to the complexities of physicochemical process mechanisms, scientific or technological generalization of oil shale retorting is difficult to achieve. Dwindling supplied of worldwide petroleum reserves, as well as the unprecedented appetite of mankind for clean liquid fuel, has made the public concern for future energy market grow rapidly. the clean coal technology and the alternate fuel technology are currently of great significance not only to policy makers, but also to process and chemical researchers. In this book, efforts have been made to make a comprehensive text for the science and technology of oil shale utilization. Therefore, subjects dealing with the terminological definitions, geology and petrology, chemistry, characterization, process engineering, mathematical modeling, chemical reaction engineering, experimental methods, and statistical experimental design, etc. are covered in detail.

Lee, S. (Akron Univ., OH (United States). Dept. of Chemical Engineering)

1991-01-01T23:59:59.000Z

91

PREDICTIVE MODELS. Enhanced Oil Recovery Model  

SciTech Connect (OSTI)

PREDICTIVE MODELS is a collection of five models - CFPM, CO2PM, ICPM, PFPM, and SFPM - used in the 1982-1984 National Petroleum Council study of enhanced oil recovery (EOR) potential. Each pertains to a specific EOR process designed to squeeze additional oil from aging or spent oil fields. The processes are: 1 chemical flooding, where soap-like surfactants are injected into the reservoir to wash out the oil; 2 carbon dioxide miscible flooding, where carbon dioxide mixes with the lighter hydrocarbons making the oil easier to displace; 3 in-situ combustion, which uses the heat from burning some of the underground oil to thin the product; 4 polymer flooding, where thick, cohesive material is pumped into a reservoir to push the oil through the underground rock; and 5 steamflood, where pressurized steam is injected underground to thin the oil. CFPM, the Chemical Flood Predictive Model, models micellar (surfactant)-polymer floods in reservoirs, which have been previously waterflooded to residual oil saturation. Thus, only true tertiary floods are considered. An option allows a rough estimate of oil recovery by caustic or caustic-polymer processes. CO2PM, the Carbon Dioxide miscible flooding Predictive Model, is applicable to both secondary (mobile oil) and tertiary (residual oil) floods, and to either continuous CO2 injection or water-alternating gas processes. ICPM, the In-situ Combustion Predictive Model, computes the recovery and profitability of an in-situ combustion project from generalized performance predictive algorithms. PFPM, the Polymer Flood Predictive Model, is switch-selectable for either polymer or waterflooding, and an option allows the calculation of the incremental oil recovery and economics of polymer relative to waterflooding. SFPM, the Steamflood Predictive Model, is applicable to the steam drive process, but not to cyclic steam injection (steam soak) processes.

Ray, R.M. [DOE Bartlesville Energy Technology Technology Center, Bartlesville, OK (United States)

1992-02-26T23:59:59.000Z

92

Low Level Heat Recovery Technology  

E-Print Network [OSTI]

level heat recovery technology. This paper discusses heat distribution systems, latest developments in absorption refrigeration and organic Rankine cycles, and pressure, minimization possibilities. The relative merits and economics of the various...

O'Brien, W. J.

1982-01-01T23:59:59.000Z

93

PREDICTIVE MODELS. Enhanced Oil Recovery Model  

SciTech Connect (OSTI)

PREDICTIVE MODELS is a collection of five models - CFPM, CO2PM, ICPM, PFPM, and SFPM - used in the 1982-1984 National Petroleum Council study of enhanced oil recovery (EOR) potential. Each pertains to a specific EOR process designed to squeeze additional oil from aging or spent oil fields. The processes are: 1 chemical flooding; 2 carbon dioxide miscible flooding; 3 in-situ combustion; 4 polymer flooding; and 5 steamflood. CFPM, the Chemical Flood Predictive Model, models micellar (surfactant)-polymer floods in reservoirs, which have been previously waterflooded to residual oil saturation. Thus, only true tertiary floods are considered. An option allows a rough estimate of oil recovery by caustic or caustic-polymer processes. CO2PM, the Carbon Dioxide miscible flooding Predictive Model, is applicable to both secondary (mobile oil) and tertiary (residual oil) floods, and to either continuous CO2 injection or water-alternating gas processes. ICPM, the In-situ Combustion Predictive Model, computes the recovery and profitability of an in-situ combustion project from generalized performance predictive algorithms. PFPM, the Polymer Flood Predictive Model, is switch-selectable for either polymer or waterflooding, and an option allows the calculation of the incremental oil recovery and economics of polymer relative to waterflooding. SFPM, the Steamflood Predictive Model, is applicable to the steam drive process, but not to cyclic steam injection (steam soak) processes. The IBM PC/AT version includes a plotting capability to produces a graphic picture of the predictive model results.

Ray, R.M. [DOE Bartlesville Energy Technology Center, Bartlesville, OK (United States)

1992-02-26T23:59:59.000Z

94

Aqueous flooding methods for tertiary oil recovery  

DOE Patents [OSTI]

A method of aqueous flooding of subterranean oil bearing formation for tertiary oil recovery involves injecting through a well into the formation a low alkaline pH aqueous sodium bicarbonate flooding solution. The flooding solution's pH ranges from about 8.25 to 9.25 and comprises from 0.25 to 5 weight percent and preferably about 0.75 to 3.0 weight percent of sodium bicarbonate and includes a petroleum recovery surfactant of 0.05 to 1.0 weight percent and between 1 and 20 weight percent of sodium chloride. After flooding, an oil and water mixture is withdrawn from the well and the oil is separated from the oil and water mixture.

Peru, Deborah A. (Bartlesville, OK)

1989-01-01T23:59:59.000Z

95

Increasing CO2 Storage in Oil Recovery  

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

Increasing CO Increasing CO 2 Storage in Oil Recovery Kristian Jessen (krisj@pangea.stanford.edu, 650-723-6348) Linda C. Sam-Olibale (chizoba@pangea.stanford.edu, 650-725-0831) Anthony R. Kovscek (kovscek@pangea.stanford.edu, 650-723-1218) Franklin M. Orr, Jr. (fmorr@pangea.stanford.edu, 650-723-2750) Department of Petroleum Engineering, Stanford University 65 Green Earth Sciences Building 367 Panama Street Stanford, CA 94305-2220 Introduction Carbon dioxide (CO 2 ) injection has been used as a commercial process for enhanced oil recovery (EOR) since the 1970's. Because the cost of oil recovered is closely linked to the purchase cost of the CO 2 injected, considerable reservoir engineering design effort has gone into reducing the total amount of CO 2 required to recover each barrel of oil. If,

96

The recovery of oil from carbonate reservoirs by fluid injection  

E-Print Network [OSTI]

Hole 70 Neasured and Calculated Productivities Obtained on Wells Completed Through Perforations 39 Cumulative Oil Recovery Versus Total Water and Oil Throughf low for Stratified Reservoirs- lj. O Cumulative Oil Recovery Versus Total Water and Oil... for Field A 12, Cumulative Oil Recovery Versus Total Water and Oil Throughflow for Field B 13, -20, Permeability Distribution Plots $5-52 The object of this project was to study the extent of the variations of the permeability in carbonate reservoirs...

Coleman, Dwayne Marvin

2012-06-07T23:59:59.000Z

97

HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS  

SciTech Connect (OSTI)

This technical progress report describes work performed from January 1 through March 31, 2003 for the project ''Heavy and Thermal Oil Recovery Production Mechanisms,'' DE-FC26-00BC15311. In this project, a broad spectrum of research is undertaken related to thermal and heavy-oil recovery. The research tools and techniques span from pore-level imaging of multiphase fluid flow to definition of reservoir-scale features through streamline-based history matching techniques. During this period, previous analysis of experimental data regarding multidimensional imbibition to obtain shape factors appropriate for dual-porosity simulation was verified by comparison among analytic, dual-porosity simulation, and fine-grid simulation. We continued to study the mechanisms by which oil is produced from fractured porous media at high pressure and high temperature. Temperature has a beneficial effect on recovery and reduces residual oil saturation. A new experiment was conducted on diatomite core. Significantly, we show that elevated temperature induces fines release in sandstone cores and this behavior may be linked to wettability. Our work in the area of primary production of heavy oil continues with field cores and crude oil. On the topic of reservoir definition, work continued on developing techniques that integrate production history into reservoir models using streamline-based properties.

Anthony R. Kovscek

2003-04-01T23:59:59.000Z

98

HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS  

SciTech Connect (OSTI)

This technical progress report describes work performed from July 1 through September, 2003 for the project ''Heavy and Thermal Oil Recovery Production Mechanisms,'' DE-FC26-00BC15311. In this project, a broad spectrum of research is undertaken related to thermal and heavy-oil recovery. The research tools and techniques span from pore-level imaging of multiphase fluid flow to definition of reservoir-scale features through streamline-based history-matching techniques. During this period, work focused on completing project tasks in the area of multiphase flow and rock properties. The area of interest is the production mechanisms of oil from porous media at high temperature. Temperature has a beneficial effect on oil recovery and reduces residual oil saturation. Work continued to delineate how the wettability of reservoir rock shifts from mixed and intermediate wet conditions to more water-wet conditions as temperature increases. One mechanism for the shift toward water-wet conditions is the release of fines coated with oil-wet material from pore walls. New experiments and theory illustrate the role of temperature on fines release.

Anthony R. Kovscek; Louis M. Castanier

2004-03-01T23:59:59.000Z

99

RESEARCH OIL RECOVERY MECHANISMS IN HEAVY OIL RESERVOIRS  

SciTech Connect (OSTI)

The United States continues to rely heavily on petroleum fossil fuels as a primary energy source, while domestic reserves dwindle. However, so-called heavy oil (10 to 20{sup o}API) remains an underutilized resource of tremendous potential. Heavy oils are much more viscous than conventional oils. As a result, they are difficult to produce with conventional recovery methods such as pressure depletion and water injection. Thermal recovery is especially important for this class of reservoirs because adding heat, usually via steam injection, generally reduces oil viscosity dramatically. This improves displacement efficiency. The research described here was directed toward improved understanding of thermal and heavy-oil production mechanisms and is categorized into: (1) flow and rock properties; (2) in-situ combustion; (3) additives to improve mobility control; (4) reservoir definition; and (5) support services. The scope of activities extended over a three-year period. Significant work was accomplished in the area of flow properties of steam, water, and oil in consolidated and unconsolidated porous media, transport in fractured porous media, foam generation and flow in homogeneous and heterogeneous porous media, the effects of displacement pattern geometry and mobility ratio on oil recovery, and analytical representation of water influx. Significant results are described.

Anthony R. Kovscek; William E. Brigham

1999-06-01T23:59:59.000Z

100

Electromagnetic Assisted Carbonated Water Flooding in Heavy Oil Recovery:.  

E-Print Network [OSTI]

??Carbonated water flooding (CWF) is an enhanced oil recovery method where an oil reservoir is flooded with water containing dissolved CO2. The CO2 is then… (more)

Son Tran, T.

2009-01-01T23:59:59.000Z

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


101

Recativation 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 (OSTI)

This project reactivates ARCO`s idle Pru Fee lease in the Midway- Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modem reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Schamel, Steven

1997-03-24T23:59:59.000Z

102

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

SciTech Connect (OSTI)

This project reactivates ARCO's idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steam was used to reestablish baseline production within the reservoir characterization phase of the project completed in December 1996. During the demonstration phase begun in January 1997, a continuous steamflood enhanced oil recovery is testing the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objective of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Schamel, Steven

1999-07-08T23:59:59.000Z

103

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 (OSTI)

This project reactivates ARCO?s idle Pru Fee property in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming was used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase begun in January 1997, a continuous steamflood enhanced oil recovery was initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and the recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Steven Schamel

1997-07-29T23:59:59.000Z

104

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 (OSTI)

This project reactivates ARCO's idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming was used to reestablish baseline production within the reservoir characterization phase of the project completed in December 1996. During the demonstration phase begun in January 1997, a continuous steamflood enhanced oil recovery is testing the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having simular producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially t o other producers in California, through an aggressive technology transfer program.

Deo, M.; Forster, C.; Jenkins, C.; Schamel, S.; Sprinkel, D.; and Swain, R.

1999-02-01T23:59:59.000Z

105

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

SciTech Connect (OSTI)

This project reactivates ARCO?s idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Creties Jenkins; Doug Sprinkel; Milind Deo; Ray Wydrinski; Robert Swain

1997-10-21T23:59:59.000Z

106

Microbial enhancement of oil recovery: Recent advances. Proceedings  

SciTech Connect (OSTI)

During recent years, systematic, scientific, and engineering effort by researchers in the United States and abroad, has established the scientific basis for Microbial Enhanced Oil Recovery (MEOR) technology. The successful application of MEOR technology as an oil recovery process is a goal of the Department of Energy (DOE). Research efforts involving aspects of MEOR in the microbiological, biochemical, and engineering fields led DOE to sponsor an International Conference at Brookhaven National Laboratory in 1992, to facilitate the exchange of information and a discussion of ideas for the future research emphasis. At this, the Fourth International MEOR Conference, where international attendees from 12 countries presented a total of 35 papers, participants saw an equal distribution between ``research`` and ``field applications.`` In addition, several modeling and ``state-of-the-art`` presentations summed up the present status of MEOR science and engineering. Individual papers in this proceedings have been process separately for inclusion in the Energy Science and Technology Database.

Premuzic, E.T.; Woodhead, A.D.; Vivirito, K.J. [eds.

1992-12-31T23:59:59.000Z

107

Research on Oil Recovery Mechanisms in Heavy Oil Reservoirs  

SciTech Connect (OSTI)

The goal of this project is to increase recovery of heavy oils. Towards that goal studies are being conducted in how to assess the influence of temperature and pressure on the absolute and relative permeability to oil and water and on capillary pressure; to evaluate the effect of different reservoir parameters on the in site combustion process; to develop and understand mechanisms of surfactants on for the reduction of gravity override and channeling of steam; and to improve techniques of formation evaluation.

Louis M. Castanier; William E. Brigham

1998-03-31T23:59:59.000Z

108

Vehicle Technologies Office: Recovery Act Funding Opportunities  

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

Recovery Act Funding Recovery Act Funding Opportunities to someone by E-mail Share Vehicle Technologies Office: Recovery Act Funding Opportunities on Facebook Tweet about Vehicle Technologies Office: Recovery Act Funding Opportunities on Twitter Bookmark Vehicle Technologies Office: Recovery Act Funding Opportunities on Google Bookmark Vehicle Technologies Office: Recovery Act Funding Opportunities on Delicious Rank Vehicle Technologies Office: Recovery Act Funding Opportunities on Digg Find More places to share Vehicle Technologies Office: Recovery Act Funding Opportunities on AddThis.com... Recovery Act Funding Opportunities President Barack Obama announced on March 19 that the DOE is offering up to $2.4 billion in American Recovery and Reinvestment Act funds to support next-generation plug-in hybrid electric vehicles (PHEV) and their advanced

109

A field laboratory for improved oil recovery. Final report  

SciTech Connect (OSTI)

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.

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

1992-09-01T23:59:59.000Z

110

Research on oil recovery mechanisms in heavy oil reservoirs  

SciTech Connect (OSTI)

The research described here was directed toward improved understanding of thermal and heavy-oil production mechanisms and is categorized into: (1) flow and rock properties, (2) in-situ combustion, (3) additives to improve mobility control, (4) reservoir definition, and (5) support services. The scope of activities extended over a three-year period. Significant work was accomplished in the area of flow properties of steam, water, and oil in consolidated and unconsolidated porous media, transport in fractured porous media, foam generation and flow in homogeneous and heterogeneous porous media, the effects of displacement pattern geometry and mobility ratio on oil recovery, and analytical representation of water influx.

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

2000-03-16T23:59:59.000Z

111

Process for tertiary oil recovery using tall oil pitch  

DOE Patents [OSTI]

A process and compositions for enhancing the recovery of acid crudes are disclosed. The process involves injecting caustic solutions into the reservoir to maintain a pH of 11 to 13. The fluid contains an effective amount of multivalent cation for inhibiting alkaline silica dissolution with the reservoir. A tall oil pitch soap is added as a polymeric mobility control agent. (DMC)

Radke, C.J.

1983-07-25T23:59:59.000Z

112

Recovery of stranded heavy oil by electromagnetic heating.  

E-Print Network [OSTI]

??High oil-viscosity is a major concern for the recovery of oil from heavy-oil reservoirs. Introducing energy to the formation has proven to be an effective… (more)

Carrizales, Maylin Alejandra

2012-01-01T23:59:59.000Z

113

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 (OSTI)

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)

Tiedemann, H.A. (ed.) (USDOE Bartlesville Project Office, OK (USA))

1991-03-01T23:59:59.000Z

114

HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS  

SciTech Connect (OSTI)

This technical progress report describes work performed from October 1 through December 31, 2002 , for the project ''Heavy and Thermal Oil Recovery Production Mechanisms.'' In this project, a broad spectrum of research is undertaken related to thermal and heavy-oil recovery. The research tools and techniques used are varied and span from pore-level imaging of multiphase fluid flow to definition of reservoir-scale features through streamline-based history-matching techniques. During this period, experimental data regarding multidimensional imbibition was analyzed to obtain shape factors appropriate for dual-porosity simulation. It is shown that the usual assumption of constant, time-independent shape factors is incorrect. In other work, we continued to study the mechanisms by which oil is produced from fractured media at high pressure and high temperature. High temperature significantly increased the apparent wettability and affected water relative permeability of cores used in previous experiments. A phenomenological and mechanistic cause for this behavior is sought. Our work in the area of primary production of heavy oil continues with field cores and crude oil. On the topic of reservoir definition, work continued on developing techniques that integrate production history into reservoir models using streamline-based properties.

Anthony R. Kovscek

2003-01-01T23:59:59.000Z

115

DOE-Sponsored Project Tests Novel Method to Increase Oil Recovery  

Broader source: Energy.gov [DOE]

Successful laboratory tests at the Energy Department’s National Energy Technology Laboratory (NETL) have verified that the use of a brine-soluble ionic surfactant could improve the efficiency of carbon dioxide enhanced oil recovery (CO2-EOR).

116

Oil & Gas Technology Center | GE Global Research  

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

Global Research Oil & Gas Technology Center GE Global Research Oil & Gas Technology Center Mark Little, SVP and chief technology officer for GE, and Eric Gebhardt, vice president...

117

"Smart" Multifunctional Polymers for Enhanced Oil Recovery  

SciTech Connect (OSTI)

Recent recommendations made by the Department of Energy, in conjunction with ongoing research at the University of Southern Mississippi, have signified a need for the development of 'smart' multi-functional polymers (SMFPs) for Enhanced Oil Recovery (EOR) processes. Herein we summarize research from the period of September 2003 through March 2007 focusing on both Type I and Type II SMFPs. We have demonstrated the synthesis and behavior of materials that can respond in situ to stimuli (ionic strength, pH, temperature, and shear stress). In particular, Type I SMFPs reversibly form micelles in water and have the potential to be utilized in applications that serve to lower interfacial tension at the oil/water interface, resulting in emulsification of oil. Type II SMFPs, which consist of high molecular weight polymers, have been synthesized and have prospective applications related to the modification of fluid viscosity during the recovery process. Through the utilization of these advanced 'smart' polymers, the ability to recover more of the original oil in place and a larger portion of that by-passed or deemed 'unrecoverable' by conventional chemical flooding should be possible.

Charles McCormick; Andrew Lowe

2007-03-20T23:59:59.000Z

118

Chemical systems for improved oil recovery: Phase behavior, oil recovery, and mobility control studies  

SciTech Connect (OSTI)

Selected surfactant systems containing a series of ethoxylated nonionic surfactants in combination with an anionic surfactant system have been studied to evaluate phase behavior as well as oil recovery potential. These experiments were conducted to evaluate possible improved phase behavior and overall oil recovery potential of mixed surfactant systems over a broad range of conditions. Both polyacrylamide polymers and Xanthan biopolymers were evaluated. Studies were initiated to use a chemical flooding simulation program, UTCHEM, to simulate oil recovery for laboratory and field applications and evaluate its use to simulate oil saturation distributions obtained in CT-monitoring of oil recovery experiments. The phase behavior studies focused on evaluating the effect of anionic-nonionic surfactant proportion on overall phase behavior. Two distinct transition behaviors were observed, depending on the dominant surfactant in the overall system. The first type of transition corresponded to more conventional behavior attributed to nonionic-dominant surfactant systems. This behavior is manifested by an oil-water-surfactant system that inverts from a water-external (highly conducting) microemulsion to an oil-external (nonconducting) one, as a function of temperature. The latter type which inverts in an opposite manner can be attributed to the separation of the anionic-nonionic mixtures into water- and oil-soluble surfactants. Both types of transition behavior can still be used to identify relative proximity to optimal areas. Determining these transition ranges provided more insight on how the behavior of these surfactant mixtures was affected by altering component proportions. Efforts to optimize the chemical system for oil displacement experiments were also undertaken. Phase behavior studies with systems formulated with biopolymer in solution were conducted.

Llave, F.; Gall, B.; Gao, H., Scott, L., Cook, I.

1995-09-01T23:59:59.000Z

119

Develop Thermoelectric Technology for Automotive Waste Heat Recovery...  

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

Documents & Publications Development of Thermoelectric Technology for Automotive Waste Heat Recovery Development of Thermoelectric Technology for Automotive Waste Heat Recovery...

120

Successful Sequestration and Enhanced Oil Recovery Project Could Mean More  

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

Successful Sequestration and Enhanced Oil Recovery Project Could Successful Sequestration and Enhanced Oil Recovery Project Could Mean More Oil and Less CO2 Emissions Successful Sequestration and Enhanced Oil Recovery Project Could Mean More Oil and Less CO2 Emissions November 15, 2005 - 2:45pm Addthis "Weyburn Project" Breaks New Ground in Enhanced Oil Recovery Efforts WASHINGTON, DC - Secretary Samuel W. Bodman today announced that the Department of Energy (DOE)-funded "Weyburn Project" successfully sequestered five million tons of carbon dioxide (CO2) into the Weyburn Oilfield in Saskatchewan, Canada, while doubling the field's oil recovery rate. If the methodology used in the Weyburn Project was successfully applied on a worldwide scale, one-third to one-half of CO2 emissions could be eliminated in the next 100 years and billions of barrels of oil could be

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


121

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

SciTech Connect (OSTI)

The objective of this project is not just to produce oil from the Pru Fee property, but rather to test which operational strategies best optimize total oil recovery at economically acceptable rates of production and production costs.

Schamel, S.

2001-01-09T23:59:59.000Z

122

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

SciTech Connect (OSTI)

The objective of the project is not just to commercially produce oil from the Pru Fee property, but rather to test which operational strategies best optimize total oil recovery at economically acceptable rates of production volumes and costs.

Schamel, Steven; Deo, Milind; Deets, Mike

2002-02-21T23:59:59.000Z

123

Department of Energy Recovery Act Investment in Biomass Technologies...  

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

Department of Energy Recovery Act Investment in Biomass Technologies Department of Energy Recovery Act Investment in Biomass Technologies The American Recovery and Reinvestment Act...

124

NETL: E&P Technologies - Improved Recovery - Stripper Well Technology  

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

Exploration & Production Technologies Improved Recovery - Stripper Well Technology image of a well linking to Stripper Well Consortium “Stripper well" is a term used to describe wells that produce natural gas or oil at very low rates—less than 10 barrels per day of oil or less than 60 thousand cubic feet per day of gas. Despite their small output, stripper oil and gas wells make a significant contribution to the Nation’s energy supply—and they are the lifeblood of thousands of small, independent oil and gas operating companies. About 80 percent of the roughly 500,000 producing oil wells in the United States are classified as stripper wells. Despite their small volumes, they add up. The >400,000 stripper oil wells in the United States produce, in aggregate, nearly 1 million barrels per day of oil, which represents almost 19% of domestic oil production.

125

Enhanced oil recovery from heavy oil reservoirs utilizing a displacement agent  

Science Journals Connector (OSTI)

An oil displacement agent consisting of nonionic and anionic surfactants and emulsion stabilizers has been developed to enhance oil recovery from heavy oil reservoirs. The experimental results show that the pr...

Fusheng Zhang; Jian Ouyang; Xintong Ma…

2012-07-01T23:59:59.000Z

126

Successful Sequestration and Enhanced Oil Recovery Project Could...  

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

the energy industry, and the general public with reliable information about industrial carbon sequestration and enhanced oil recovery." In the first phase of the research...

127

Experimental study of mechanisms of improving oil recovery in Shale.  

E-Print Network [OSTI]

??ABSTRACT Extensive laboratory work was done to investigate some of the important mechanisms of improving oil recovery in Shale formations. The objective of this research… (more)

Onyenwere, Emmanuel

2012-01-01T23:59:59.000Z

128

Evaluation of Reservoir Wettability and its Effect on Oil Recovery,10/96,659,264  

Office of Scientific and Technical Information (OSTI)

EVALUATION OF RESERVOIR WETTABILITY AND ITS EFFECT ON OIL RECOVERY EVALUATION OF RESERVOIR WETTABILITY AND ITS EFFECT ON OIL RECOVERY First Annual Report by Jill S. Buckley Work Performed under Cooperative Agreement Number DE-FC22-96ID13421 Reporting Period: July 1, 1996 - June 30, 1997 Prepared for U.S. Department of Energy Assistant Secretary for Fossil Energy Jerry Casteel, Project Manager National Petroleum Technology Center P.O. Box 3628 Tulsa OK 74101 Prepared by Petroleum Recovery Research Center New Mexico Institute of Mining and Technology 801 Leroy Place Socorro, NM 87801 ii ABSTRACT We report on the first year of the project, "Evaluation of Reservoir Wettability and its Effect on Oil Recovery." The objectives of this five-year project are (1) to achieve improved understanding of the surface and interfacial properties of crude oils and their interactions with

129

NETL-RUA Scans for Improved Enhanced Oil Recovery Technique | Department of  

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

Scans for Improved Enhanced Oil Recovery Technique Scans for Improved Enhanced Oil Recovery Technique NETL-RUA Scans for Improved Enhanced Oil Recovery Technique April 4, 2012 - 1:00pm Addthis Washington, DC - Researchers participating in the National Energy Technology Laboratory Regional University Alliance (NETL-RUA) are using a familiar piece of medical equipment - a CT scanner - to evaluate cutting-edge improvements to enhanced oil recovery (EOR) techniques. Results from these studies could be used to help increase domestic oil supplies from EOR while helping to reduce the amount of carbon dioxide (CO2) emitted to the atmosphere. Scientists from the University of Pittsburgh, University of Bristol, Rutherford Appleton Laboratory, URS, and NETL are using the scanner and surfactants (fluids added to injected CO2 that change its flow properties)

130

Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 87  

SciTech Connect (OSTI)

Approximately 30 research projects are summarized in this report. Title of the project, contract number, company or university, award amount, principal investigators, objectives, and summary of technical progress are given for each project. Enhanced oil recovery projects include chemical flooding, gas displacement, and thermal recovery. Most of the research projects though are related to geoscience technology and reservoir characterization.

NONE

1997-10-01T23:59:59.000Z

131

Transformation of Resources to Reserves: Next Generation Heavy-Oil Recovery Techniques  

SciTech Connect (OSTI)

This final report and technical progress report describes work performed from October 1, 2004 through September 30, 2007 for the project 'Transformation of Resources to Reserves: Next Generation Heavy Oil Recovery Techniques', DE-FC26-04NT15526. Critical year 3 activities of this project were not undertaken because of reduced funding to the DOE Oil Program despite timely submission of a continuation package and progress on year 1 and 2 subtasks. A small amount of carried-over funds were used during June-August 2007 to complete some work in the area of foamed-gas mobility control. Completion of Year 3 activities and tasks would have led to a more thorough completion of the project and attainment of project goals. This progress report serves as a summary of activities and accomplishments for years 1 and 2. Experiments, theory development, and numerical modeling were employed to elucidate heavy-oil production mechanisms that provide the technical foundations for producing efficiently the abundant, discovered heavy-oil resources of the U.S. that are not accessible with current technology and recovery techniques. Work fell into two task areas: cold production of heavy oils and thermal recovery. Despite the emerging critical importance of the waterflooding of viscous oil in cold environments, work in this area was never sanctioned under this project. It is envisioned that heavy oil production is impacted by development of an understanding of the reservoir and reservoir fluid conditions leading to so-called foamy oil behavior, i.e, heavy-oil solution gas drive. This understanding should allow primary, cold production of heavy and viscous oils to be optimized. Accordingly, we evaluated the oil-phase chemistry of crude oil samples from Venezuela that give effective production by the heavy-oil solution gas drive mechanism. Laboratory-scale experiments show that recovery correlates with asphaltene contents as well as the so-called acid number (AN) and base number (BN) of the crude oil. A significant number of laboratory-scale tests were made to evaluate the solution gas drive potential of West Sak (AK) viscous oil. The West Sak sample has a low acid number, low asphaltene content, and does not appear foamy under laboratory conditions. Tests show primary recovery of about 22% of the original oil in place under a variety of conditions. The acid number of other Alaskan North Slope samples tests is greater, indicating a greater potential for recovery by heavy-oil solution gas drive. Effective cold production leads to reservoir pressure depletion that eases the implementation of thermal recovery processes. When viewed from a reservoir perspective, thermal recovery is the enhanced recovery method of choice for viscous and heavy oils because of the significant viscosity reduction that accompanies the heating of oil. One significant issue accompanying thermal recovery in cold environments is wellbore heat losses. Initial work on thermal recovery found that a technology base for delivering steam, other hot fluids, and electrical heat through cold subsurface environments, such as permafrost, was in place. No commercially available technologies are available, however. Nevertheless, the enabling technology of superinsulated wells appears to be realized. Thermal subtasks focused on a suite of enhanced recovery options tailored to various reservoir conditions. Generally, electrothermal, conventional steam-based, and thermal gravity drainage enhanced oil recovery techniques appear to be applicable to 'prime' Ugnu reservoir conditions to the extent that reservoir architecture and fluid conditions are modeled faithfully here. The extent of reservoir layering, vertical communication, and subsurface steam distribution are important factors affecting recovery. Distribution of steam throughout reservoir volume is a significant issue facing thermal recovery. Various activities addressed aspects of steam emplacement. Notably, hydraulic fracturing of horizontal steam injection wells and implementation of steam trap control that limits steam entry into hor

Stanford University; Department of Energy Resources Engineering Green Earth Sciences

2007-09-30T23:59:59.000Z

132

Enhanced oil recovery data base analysis by simplified predictive models  

SciTech Connect (OSTI)

The U.S. Department of Energy, Bartlesville Energy Technology Center (BETC), has been developing computerized data bases and simplified predictive models to be used to predict enhanced oil recovery (EOR) potential in the U.S. The development phase of this work is nearing completion whereupon the models and data bases will be made available to the public. This paper describes the overall development phase for the models and data bases with analyses of selected EOR projects using the predictive models. Examples of model outputs are discussed and brief descriptions of the predictive algorithms are given.

Ray, R.M.; Wesson, T.C.

1982-11-01T23:59:59.000Z

133

Recovery Act: Carbon Dioxide-Water Emulsion for Enhanced Oil Recovery and Permanent Sequestration of Carbon Dioxid  

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

Carbon Dioxide-Water Carbon Dioxide-Water Emulsion for Enhanced Oil Recovery and Permanent Sequestration of Carbon Dioxide Background The U.S. Department of Energy (DOE) distributed a portion of American Recovery and Reinvestment Act (ARRA) funds to advance technologies for chemical conversion of carbon dioxide (CO 2 ) captured from industrial sources. The focus of the research projects is permanent sequestration of CO 2 through mineralization or development

134

E-Print Network 3.0 - advanced oil recovery Sample Search Results  

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

oil recovery Search Powered by Explorit Topic List Advanced Search Sample search results for: advanced oil recovery Page: << < 1 2 3 4 5 > >> 1 Advanced Oil Spill Recovery in...

135

Innovative Technology Improves Upgrading Process for Unconventional Oil  

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

09, 2013 09, 2013 Innovative Technology Improves Upgrading Process for Unconventional Oil Resources Washington, D.C. - An innovative oil-upgrading technology that can increase the economics of unconventional petroleum resources has been developed under a U.S. Department of Energy -funded project. The promising technology, developed by Ceramatec of Salt Lake City, Utah, and managed by the Office of Fossil Energy's National Energy Technology Laboratory, has been licensed to Western Hydrogen of Calgary for upgrading bitumen or heavy oil from Canada. A new company, Field Upgrading (Calgary, Alberta), has been formed dedicated to developing and commercializing the technology. Heavy oil is crude oil that is viscous and requires thermally enhanced oil recovery methods, such as steam and hot water injection, to reduce its viscosity and enable it to flow. The largest U.S. deposits of heavy oil are in California and on Alaska's North Slope. Estimates for the U.S. heavy oil resource total about 104 billion barrels of oil in place - nearly five times the United States' proved reserves. In addition, although no commercial-scale development of U.S. oil sands or oil shale has yet occurred, both represent another potential future domestic unconventional oil resource.

136

Feasibility study of heavy oil recovery in the Midcontinent region (Kansas, Missouri, Oklahoma)  

SciTech Connect (OSTI)

This report is one of a series of publications assessing the feasibility/constraints of increasing domestic heavy oil production. Each report covers a select area of the United States. The Midcontinent (Kansas, Nssouri, Oklahoma) has produced significant oil, but contrary to early reports, the area does not contain the huge volumes of heavy oil that, along with the development of steam and in situ combustion as oil production technologies, sparked the area`s oil boom of the 1960s. Recovery of this heavy oil has proven economically unfeasible for most operators due to the geology of the formations rather than the technology applied to recover the oil. The geology of the southern Midcontinent, as well as results of field projects using thermal enhanced oil recovery (TEOR) methods to produce the heavy oil, was examined based on analysis of data from secondary sources. Analysis of the performance of these projects showed that the technology recovered additional heavy oil above what was produced from primary production from the consolidated, compartmentalized, fluvial dominated deltaic sandstone formations in the Cherokee and Forest City basins. The only projects producing significant economic and environmentally acceptable heavy oil in the Midcontinent are in higher permeability, unconsolidated or friable, thick sands such as those found in south-central Oklahoma. There are domestic heavy oil reservoirs in other sedimentary basins that are in younger formations, are less consolidated, have higher permeability and can be economically produced with current TEOR technology. Heavy oil production from the carbonates of central and wester Kansas has not been adequately tested, but oil production is anticipated to remain low. Significant expansion of Midcontinent heavy oil production is not anticipated because the economics of oil production and processing are not favorable.

Olsen, D.K.; Johnson, W.I.

1993-08-01T23:59:59.000Z

137

NETL: Oil and Natural Gas: Deepwater Technology  

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

Deepwater Technology Deepwater Technology Research Project Summaries Reference Shelf O&G Document Archive Deepwater (and Ultra-Deepwater, 5000 feet of water depth and beyond) is recognized as one of the last remaining areas of the world were oil and natural gas resources remain to be discovered and produced. The architecture of the systems employed to cost-effectively develop these resources in an environmentally safe manner, reflect some of industryÂ’s most advanced engineering accomplishments. NETL is funding research to catalyze further advances that can help Gulf of Mexico discoveries progress to production quickly and safely, and that can help maximize oil and gas recovery from fields that are currently at the edge of industry capabilities. Many of these efforts are focused on subsea production

138

Microbial Enhanced Oil Recovery in Fractional-Wet Systems: A Pore-Scale Investigation  

SciTech Connect (OSTI)

Microbial enhanced oil recovery (MEOR) is a technology that could potentially increase the tertiary recovery of oil from mature oil formations. However, the efficacy of this technology in fractional-wet systems is unknown, and the mechanisms involved in oil mobilization therefore need further investigation. Our MEOR strategy consists of the injection of ex situ produced metabolic byproducts produced by Bacillus mojavensis JF-2 (which lower interfacial tension (IFT) via biosurfactant production) into fractional-wet cores containing residual oil. Two different MEOR flooding solutions were tested; one solution contained both microbes and metabolic byproducts while the other contained only the metabolic byproducts. The columns were imaged with X-ray computed microtomography (CMT) after water flooding, and after MEOR, which allowed for the evaluation of the pore-scale processes taking place during MEOR. Results indicate that the larger residual oil blobs and residual oil held under relatively low capillary pressures were the main fractions recovered during MEOR. Residual oil saturation, interfacial curvatures, and oil blob sizes were measured from the CMT images and used to develop a conceptual model for MEOR in fractional-wet systems. Overall, results indicate that MEOR was effective at recovering oil from fractional-wet systems with reported additional oil recovered (AOR) values between 44 and 80%; the highest AOR values were observed in the most oil-wet system.

Armstrong, Ryan T.; Wildenschild, Dorthe (Oregon State U.)

2012-10-24T23:59:59.000Z

139

Oil recovery enhancement from fractured, low permeability reservoirs. Annual report 1990--1991, Part 1  

SciTech Connect (OSTI)

Joint funding by the Department of Energy and the State of Texas has Permitted a three year, multi-disciplinary investigation to enhance oil recovery from a dual porosity, fractured, low matrix permeability oil reservoir to be initiated. The Austin Chalk producing horizon trending thru the median of Texas has been identified as the candidate for analysis. Ultimate primary recovery of oil from the Austin Chalk is very low because of two major technological problems. The commercial oil producing rate is based on the wellbore encountering a significant number of natural fractures. The prediction of the location and frequency of natural fractures at any particular region in the subsurface is problematical at this time, unless extensive and expensive seismic work is conducted. A major portion of the oil remains in the low permeability matrix blocks after depletion because there are no methods currently available to the industry to mobilize this bypassed oil. The following multi-faceted study is aimed to develop new methods to increase oil and gas recovery from the Austin Chalk producing trend. These methods may involve new geological and geophysical interpretation methods, improved ways to study production decline curves or the application of a new enhanced oil recovery technique. The efforts for the second year may be summarized as one of coalescing the initial concepts developed during the initial phase to more in depth analyses. Accomplishments are predicting natural fractures; relating recovery to well-log signatures; development of the EOR imbibition process; mathematical modeling; and field test.

Poston, S.W.

1991-12-31T23:59:59.000Z

140

New EOR system being tested. [Enhanced oil recovery  

SciTech Connect (OSTI)

Oil and gas operators - and drilling contractors, if they own production - are watching with a great deal of interest an innovative enhanced oil recovery system now being tested in Missouri and Canada which, if present results prove to be the rule, will help gain recovery rates of double current oil production using conventional means. The new system, vapor therm, is being offered to oil and gas operators who either are now engaged in steam injection projects or plan to in the near future. The vapor therm system is designed for use in specific heavy oil reservoirs. What's more, existing steam generating equipment in field use need not be eliminated, since the system has been designed to be retrofitted to such steam generating facilities with little or no downtime involved. The system combines inert gases with injected steam to produced greatly enhanced recovery of oil for the same amount of steam injected in conventional steamflood operations.

Not Available

1982-04-01T23:59:59.000Z

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


141

Synchrophasor Technologies and their Deployment in the Recovery...  

Energy Savers [EERE]

Synchrophasor Technologies and their Deployment in the Recovery Act Smart Grid Programs (August 2013) Synchrophasor Technologies and their Deployment in the Recovery Act Smart Grid...

142

Recovery Act - Geothermal Technologies Program:Ground Source...  

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

Recovery Act - Geothermal Technologies Program:Ground Source Heat Pumps Recovery Act - Geothermal Technologies Program:Ground Source Heat Pumps A detailled description of the...

143

Horizontal oil well applications and oil recovery assessment. Technical progress report, April--June 1994  

SciTech Connect (OSTI)

Thousands of horizontal wells are being drilled each year in the U.S.A. and around the world. Horizontal wells have increased oil and gas production rates 3 to 8 times those of vertical wells in many areas and have converted non-economic oil reserves to economic reserves. However, the use of horizontal technology in various formation types and applications has not always yielded anticipated success. The primary objective of this project is to examine factors affecting technical and economic success of horizontal well applications. The project`s goals will be accomplished through six tasks designed to evaluate the technical and economic success of horizontal drilling, highlight current limitations, and outline technical needs to overcome these limitations. Data describing operators` experiences throughout the domestic oil and gas industry will be gathered and organized. Canadian horizontal technology will also be documented with an emphasis on lessons the US industry can learn from Canada`s experience. MEI databases containing detailed horizontal case histories will also be used. All these data will be categorized and analyzed to assess the status of horizontal well technology and estimate the impact of horizontal wells on present and future domestic oil recovery and reserves.

McDonald, W.J.

1993-06-03T23:59:59.000Z

144

Microbial enhanced oil recovery research. [Peptides  

SciTech Connect (OSTI)

The surface active lipopeptide produced by Bacillus licheniformis JF-2 was isolated to near apparent homogeneity. NMR experiments revealed that this compound consists of a heptapeptide with an amino acid sequence similar to surfactin and a heterogeneous fatty acid consisting of the normal-, anteiso-, and iso- branched isomers. The surface activity of the B. licheniformis JF-2 surfactant was shown to depend on the presence of fermentation products and is strongly affected by the pH. Under conditions of optimal salinity and pH the interfacial tension against decane was 6 [times] 10[sup 3] mN/m which is one of the lowest values ever obtained with a microbial surfactant. Microbial compounds which exhibit particularly high surface activity are classified as biosurfactants. Microbial biosurfactants include a wide variety of surface and interfacially active compounds, such as glycolipids, lipopeptides polysaccharideprotein complexes, phospholipids, fatty acids and neutral lipids. Biosurfactants are easily biodegradable and thus are particularly suited for environmental applications such as bioremediation and the dispersion of oil spills. Bacillus licheniformis strain JF-2 has been shown to be able to grow and produce a very effective biosurfactant under both aerobic and anaerobic conditions and in the presence of high salt concentrations. The production of biosurfactants in anaerobic, high salt environments is potentially important for a variety of in situ applications such as microbial enhanced oil recovery. As a first step towards evaluating the commercial utility of the B. licheniformis JF-2 surfactant, we isolated t-he active. compound from the culture supernatant, characterized its chemical structure and investigated its phase behavior. We found that the surface activity of the surfactant is strongly dependent on the pH of the aqueous. phase. This may be important for the biological function of the surfactant and is of interest for several applications in surfactancy.

Sharma, M.M.; Georgiou, G. (Texas Univ., Austin, TX (United States))

1992-01-01T23:59:59.000Z

145

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 (OSTI)

This project reactivates ARCO`s idle Pru Fee lease in the Midway- Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program. One of the main objectives of Budget Period I was to return the Pru Fee property to economic production and establish a baseline productivity with cyclic steaming. By the end of the second quarter 1996, all Pru producers except well 101 had been cyclic steamed two times. Each steam cycle was around 10,000 barrels of steam (BS) per well. No mechanical problems were found in the existing old wellbores. Conclusion is after several years of being shut-in, the existing producers on the Pru lease are in reasonable mechanical condition, and can therefore be utilized as viable producers in whatever development plan we determine is optimum. Production response to cyclic steam is very encouraging in the new producer, however productivity in the old producers appears to be limited in comparison.

Schamel, S.

1996-11-01T23:59:59.000Z

146

Enhanced Oil Recovery Affects the Future Energy Mix | GE Global...  

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

Affects the Future Energy Mix Enhanced Oil Recovery Affects the Future Energy Mix Trevor Kirsten 2012.11.19 One of the fascinating things about my job is contemplating questions...

147

Enhanced Oil Recovery Using the Alkaline-Surfactant-Polymer (ASP)  

E-Print Network [OSTI]

Alkaline Surfactant Polymer (ASP) process is a tertiary method of oil recovery that has promising results for future development. It has already been implemented in different areas of the United States such as Wyoming, west Texas, also in Canada...

Musharova, Darya

2010-07-14T23:59:59.000Z

148

Recovery of oil from fractured reservoirs by gas displacement  

E-Print Network [OSTI]

RECOVERY OF OIL FROM FRACTURED RESERVOIRS BY GAS DISPLACEMENT A Thesis by ARILD UNNE BE RG Submitted to the Graduate College of Texas AlkM University in partial fulfillment of the requirement for the degree of MASTER OF SCIENCE August 1974... Major Subject: Petroleum Engineering RECOVERY OF OIL FROM FRACTURED RESERVOIRS BY GAS DISPLACEMENT A Thesis by ARILD UNNEBERG Approved as, to style and content by: . ( y (Chairman of Cornrnittee) (Head of Depar nt) / (Membe r) (Member) M b...

Unneberg, Arild

2012-06-07T23:59:59.000Z

149

Uncertainty quantification for CO2 sequestration and enhanced oil recovery  

E-Print Network [OSTI]

This study develops a statistical method to perform uncertainty quantification for understanding CO2 storage potential within an enhanced oil recovery (EOR) environment at the Farnsworth Unit of the Anadarko Basin in northern Texas. A set of geostatistical-based Monte Carlo simulations of CO2-oil-water flow and reactive transport in the Morrow formation are conducted for global sensitivity and statistical analysis of the major uncertainty metrics: net CO2 injection, cumulative oil production, cumulative gas (CH4) production, and net water injection. A global sensitivity and response surface analysis indicates that reservoir permeability, porosity, and thickness are the major intrinsic reservoir parameters that control net CO2 injection/storage and oil/gas recovery rates. The well spacing and the initial water saturation also have large impact on the oil/gas recovery rates. Further, this study has revealed key insights into the potential behavior and the operational parameters of CO2 sequestration at CO2-EOR s...

Dai, Zhenxue; Fessenden-Rahn, Julianna; Middleton, Richard; Pan, Feng; Jia, Wei; Lee, Si-Yong; McPherson, Brian; Ampomah, William; Grigg, Reid

2014-01-01T23:59:59.000Z

150

Successful Oil and Gas Technology Transfer Program Extended to 2015 |  

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

Successful Oil and Gas Technology Transfer Program Extended to 2015 Successful Oil and Gas Technology Transfer Program Extended to 2015 Successful Oil and Gas Technology Transfer Program Extended to 2015 June 23, 2010 - 1:00pm Addthis Washington, D.C. - The Stripper Well Consortium (SWC) - a program that has successfully provided and transferred technological advances to small, independent oil and gas operators over the past nine years - has been extended to 2015 by the U.S. Department of Energy (DOE). An industry-driven consortium initiated in 2000, SWC's goal is to keep "stripper wells" productive in an environmentally safe manner, maximizing the recovery of domestic hydrocarbon resources. The consortium is managed and administered by The Pennsylvania State University on behalf of DOE; the Office of Fossil Energy's (FE) National Energy Technology Laboratory (NETL)

151

Microbial enhanced oil recovery and wettability research program  

SciTech Connect (OSTI)

This report covers research results for the microbial enhanced oil recovery (MEOR) and wettability research program conducted by EG G Idaho, Inc. at the Idaho National Engineering Laboratory (INEL). The isolation and characterization of microbial species collected from various locations including target oil field environments is underway to develop more effective oil recovery systems for specific applications. The wettability research is a multi-year collaborative effort with the New Mexico Petroleum Recovery Research Center (NMPRRC), to evaluate reservoir wettability and its effects on oil recovery. Results from the wettability research will be applied to determine if alteration of wettability is a significant contributing mechanism for MEOR systems. Eight facultatively anaerobic surfactant producing isolates able to function in the reservoir conditions of the Minnelusa A Sands of the Powder River Basin in Wyoming were isolated from naturally occurring oil-laden environments. Isolates were characterized according to morphology, thermostability, halotolerance, growth substrates, affinity to crude oil/brine interfaces, degradative effects on crude oils, and biochemical profiles. Research at the INEL has focused on the elucidation of microbial mechanisms by which crude oil may be recovered from a reservoir and the chemical and physical properties of the reservoir that may impact the effectiveness of MEOR. Bacillus licheniformis JF-2 (ATCC 39307) has been used as a benchmark organism to quantify MEOR of medium weight crude oils (17.5 to 38.1{degrees}API) the capacity for oil recovery of Bacillus licheniformis JF-2 utilizing a sucrose-based nutrient has been elucidated using Berea sandstone cores. Spacial distribution of cells after microbial flooding has been analyzed with scanning electron microscopy. Also the effect of microbial surfactants on the interfacial tensions (IFT) of aqueous/crude oil systems has been measured. 87 refs., 60 figs., 15 tabs.

Thomas, C.P.; Bala, G.A.; Duvall, M.L.

1991-07-01T23:59:59.000Z

152

Horizontal oil well applications and oil recovery assessment. Technical progress report, January--March 1994  

SciTech Connect (OSTI)

The primary objective of this project is to examine factors affecting technical and economic success of horizontal well applications. The project`s goals will be accomplished through five tasks designed to evaluate the technical and economic success of horizontal drilling, highlight current limitations, and outline technical needs to overcome these limitations. Data describing operators` experiences throughout the domestic oil and gas industry will be gathered and organized. MEI databases containing detailed horizontal case histories will also be used. All these data will be categorized and analyzed to assess the status of horizontal well technology and estimate the impact of horizontal wells on present and future domestic oil recovery and reserves. Accomplishments for this quarter are presented.

McDonald, W.J.

1994-06-01T23:59:59.000Z

153

Develop Thermoelectric Technology for Automotive Waste Heat Recovery  

Broader source: Energy.gov [DOE]

Develop thermoelectric technology for waste heat recovery with a 10% fuel economy improvement without increasing emissions.

154

Method for maximizing shale oil recovery from an underground formation  

DOE Patents [OSTI]

A method for maximizing shale oil recovery from an underground oil shale formation which has previously been processed by in situ retorting such that there is provided in the formation a column of substantially intact oil shale intervening between adjacent spent retorts, which method includes the steps of back filling the spent retorts with an aqueous slurry of spent shale. The slurry is permitted to harden into a cement-like substance which stabilizes the spent retorts. Shale oil is then recovered from the intervening column of intact oil shale by retorting the column in situ, the stabilized spent retorts providing support for the newly developed retorts.

Sisemore, Clyde J. (Livermore, CA)

1980-01-01T23:59:59.000Z

155

RMOTC to Test Oil Viscosity Reduction Technology  

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

to Test Oil Viscosity Reduction Technology to Test Oil Viscosity Reduction Technology The Rocky Mountain Oilfield Testing Center (RMOTC) announces that the "Teapot Dome" oil field in Wyoming is hosting a series of tests funded by STWA, Inc. ("STWA") to determine the performance of its Applied Oil Technology (AOT(tm)) in reducing crude oil's viscosity to lower transportation costs for pipeline operators. The testing is managed by RMOTC, and conducted at Naval Petroleum Reserve No. 3, also known as the Teapot Dome oil field. RMOTC is providing the infrastructure and technical expertise to support companies such as STWA in their efforts to validate new technologies and bring those products and

156

Exhaust Gas Energy Recovery Technology Applications  

SciTech Connect (OSTI)

Exhaust waste heat recovery systems have the potential to significantly improve vehicle fuel economy for conventional and hybrid electric powertrains spanning passenger to heavy truck applications. This chapter discusses thermodynamic considerations and three classes of energy recovery technologies which are under development for vehicle applications. More specifically, this chapter describes the state-of-the-art in exhaust WHR as well as challenges and opportunities for thermodynamic power cycles, thermoelectric devices, and turbo-compounding systems.

Wagner, Robert M [ORNL] [ORNL; Szybist, James P [ORNL] [ORNL

2014-01-01T23:59:59.000Z

157

Role of Enhanced Oil Recovery in Carbon Sequestration, The Weyburn Monitoring Project, a case study  

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

Enhanced Oil Recovery in Carbon Sequestration Enhanced Oil Recovery in Carbon Sequestration The Weyburn Monitoring Project, a case study K. Brown (ken_brown@pcp.ca), PanCanadian Petroleum Limited) 150 - 9 th Avenue S.W., P.O. Box 2850, Calgary, Alberta T2P 2S5 W. Jazrawi (Waleed_Jazrawi@pancanadian.ca) Petroleum Technology Research Centre 6 Research Drive, Regina, Saskatchewan S4S 7J7 R. Moberg (Moberg@src.sk.ca) Petroleum Technology Research Centre 6 Research Drive, Regina, Saskatchewan S4S 7J7 M. Wilson (Mwilson@sem.gov.sk.ca) Petroleum Technology Research Centre 6 Research Drive, Regina, Saskatchewan S4S 7J7 Abstract: Injection of CO 2 into a carbonate oil reservoir in southeastern Saskatchewan, Canada, began on September 22, 2000. Prior to the start of injection, substantial baseline data were obtained from the field. This baseline data include extensive seismic work

158

An evaluation of known remaining oil resources in the state of California. Volume 2, Project on Advanced Oil Recovery and the States  

SciTech Connect (OSTI)

The Interstate Oil and Gas Compact Commission (IOGCC) has conducted a series of studies to evaluate the known, remaining oil resource in twenty-three (23) states. The primary objective of the IOGCC`s effort is to examine the potential impact of an aggressive and focused program of research, development, and demonstration (RD&D) and technology transfer on future oil recovery in the United States. As a part of this larger effort by the IOGCC, this report focuses on the potential economic benefits of improved oil recovery in the state of California. Individual reports for seven other oil producing states and a national report have been separately published by the IOGCC. The analysis presented in this report is based on the databases and models available in the Tertiary Oil Recovery Information System (TORIS). Overall, well abandonments and more stringent environmental regulations could limit economic access to California`s known, remaining oil resource. The high risk of near-term abandonment and the significant benefits of future application of improved oil recovery technology, clearly point to a need for more aggressive transfer of currently available technologies to oil producers. Development and application of advanced oil recovery technologies could have even greater benefits to the state and the nation. A collaborative, focused RD&D effort, integrating the resources and expertise of industry, state and local governments, and the Federal government, is clearly warranted. With effective RD&D and a program of aggressive technology transfer to widely disseminate its results, California oil production could be maximized. The resulting increase in production rates, employment, operator profits, state and Federal tax revenues, and energy security will benefit both the state of California and the nation as a whole.

Not Available

1994-10-01T23:59:59.000Z

159

An evaluation of known remaining oil resources in the state of New Mexico and Wyoming. Volume 4, Project on Advanced Oil Recovery and the States  

SciTech Connect (OSTI)

The Interstate Oil and Gas Compact Commission (IOGCC) has conducted a series of studies to evaluate the known, remaining oil resource in twenty-three (23) states. The primary objective of the IOGCC`s effort is to examine the potential impact of an aggressive and focused program of research, development, and demonstration (RD&D) and technology transfer on future oil recovery in the United States. As part of a larger effort by the IOGCC, this report focuses on the potential economic benefits of improved oil recovery in the states of New Mexico and Wyoming. Individual reports for six other oil producing states and a national report have been separately published by the IOGCC. The analysis presented in this report is based on the databases and models available in the Tertiary Oil Recovery Information System (TORIS). Overall, well abandonments and more stringent environmental regulations could limit economic access to New Mexico`s known, remaining oil resource. The high risk of near-term abandonment and the significant benefits of future application of improved oil recovery technology, clearly point to a need for more aggressive transfer of currently available technologies to domestic oil producers. Development and application of advanced oil recovery technologies could have even greater benefits to the state and the nation. A collaborative, focused RD&D effort, integrating the resources and expertise of industry, state and local governments, and the Federal government, is clearly warranted. With effective RD&D and a program of aggressive technology transfer to widely disseminate its results, oil production could be maximized. The resulting increase in production rates, employment, operator profits, state and Federal tax revenues, and energy security will benefit both the states of New Mexico and Wyoming and the nation as a whole.

Not Available

1994-11-01T23:59:59.000Z

160

Oil recovery process employing cyclic wettability alteration  

SciTech Connect (OSTI)

This patent describes a process for recovering oil from an oil-wet fractured subterranean oil-bearing formation penetrated by at least two wells from the surface which are in fluid communication with the formation and with one another comprising: (a)injecting a first slug of a surfactant solution into the fractured formation via a first of the at least two wells, the surfactant solution capable of becoming the preferred wetting phase of an oil-wet matrix block in the fractured formation; (b) contacting a face of the oil-well matrix block the surfactant solution for a time sufficient for the surfactant solution to penetrate and become the preferred wetting phase of at least a portion of the matrix block thereby displacing oil from the portion of the matrix block toward the face of the matrix block; (c) injecting a second slug of water into the formation via a second of at least two wells; (d) contacting the face of the matrix block with the water for a time sufficient for the water to penetrate and restore the portion of the matrix block to an oil-wet condition; (e) displacing the oil away from the face of the matrix block the water toward the first well; (f) recovering the oil from the formation via the first well; and (g) repeating steps (a), (b), (c), (d), (e), and (f).

McClure, D.C.

1989-06-27T23:59:59.000Z

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


161

Oil recovery from condensed corn distillers solubles.  

E-Print Network [OSTI]

??Condensed corn distillers solubles (CCDS) contains more oil than dried distillers grains with solubles (DDGS), 20 vs. 12% (dry weight basis). Therefore, significant amount of… (more)

Majoni, Sandra

2009-01-01T23:59:59.000Z

162

Kuwaiti oil sector shows more signs of recovery  

SciTech Connect (OSTI)

This paper reports that Kuwait's oil sector continues to show signs of recovery from the Persian Gulf war. On Mar. 23 Kuwait Petroleum Co. (KPC) loaded the country's first shipment of liquefied petroleum gas for export since the Iraqi invasion in August 1990. In addition, the first shipment of Kuwaiti crude recovered from giant oil lakes formed by hundreds of wild wells sabotaged in the war was to arrive by tanker in Naples, Italy, late last month. The tanker is carrying 210,000 bbl of crude. However, the project to clean up the lakes and recover more oil, undertaken by Bechtel Corp. with Kuwait Oil Co. (KOC), has reached a stand still.

Not Available

1992-04-06T23:59:59.000Z

163

Diesel Engine Oil Technology Insights and Opportunities | Department...  

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

Oil Technology Insights and Opportunities Diesel Engine Oil Technology Insights and Opportunities Perrformance of API CJ-4 diesel engine lubricating oil and emerging lubricant...

164

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

SciTech Connect (OSTI)

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 (Figure 1), but to test which production parameters optimize total oil recovery at economically acceptable rates of production and production costs.

Schamel, Steven

1999-11-09T23:59:59.000Z

165

Numerical simulation of preformed particle gel flooding for enhancing oil recovery  

Science Journals Connector (OSTI)

Abstract As a new type of oil recovery enhancing technology, preformed particle gel (PPG) flooding has been gradually used for high water-cut reservoir development. However, the current commercial software cannot simulate the processes of PPG flooding. In this paper, a novel mathematical model considering the behaviors of pore-throat plugging and particles restarting, the matching relations of particle size, throat size and pressure gradient is established based on the mass conservation equation and solved by IMPES and typical four-order Runge–Kutta methods. Also, the codes are written by Visual Basic, and the verification is proved by experimental data. Then, the influences of injection rate, suspension concentration, mean particle diameter, critical threshold pressure gradient and permeability ratio in ultimate oil recovery factor and water-cut are studied. The results show that, with the injection rate, mean particle diameter and critical restarting pressure gradient coefficient increasing, the ultimate oil recovery factor will increase first, and then decrease. As the concentration of injection suspension increases, the ultimate oil recovery factor will increase first, but at the later stage it tends to be smooth. As the permeability ratio increases, the enhanced recovery factor will also increase first, and then tend to be smooth.

Jing Wang; Huiqing Liu; Zenglin Wang; Jie Xu; Dengyu Yuan

2013-01-01T23:59:59.000Z

166

Numerical Simulation of Low Salinity Water Flooding Assisted with Chemical Flooding for Enhanced Oil Recovery.  

E-Print Network [OSTI]

?? World proved oil reserve gradually decreases due to the increase production but decrease new field discovery. The focus on enhance oil recovery from the… (more)

Atthawutthisin, Natthaporn

2012-01-01T23:59:59.000Z

167

Development and Optimization of Gas-Assisted Gravity Drainage (GAGD) Process for Improved Light Oil Recovery  

SciTech Connect (OSTI)

This is the final report describing the evolution of the project ''Development and Optimization of Gas-Assisted Gravity Drainage (GAGD) Process for Improved Light Oil Recovery'' from its conceptual stage in 2002 to the field implementation of the developed technology in 2006. This comprehensive report includes all the experimental research, models developments, analyses of results, salient conclusions and the technology transfer efforts. As planned in the original proposal, the project has been conducted in three separate and concurrent tasks: Task 1 involved a physical model study of the new GAGD process, Task 2 was aimed at further developing the vanishing interfacial tension (VIT) technique for gas-oil miscibility determination, and Task 3 was directed at determining multiphase gas-oil drainage and displacement characteristics in reservoir rocks at realistic pressures and temperatures. The project started with the task of recruiting well-qualified graduate research assistants. After collecting and reviewing the literature on different aspects of the project such gas injection EOR, gravity drainage, miscibility characterization, and gas-oil displacement characteristics in porous media, research plans were developed for the experimental work to be conducted under each of the three tasks. Based on the literature review and dimensional analysis, preliminary criteria were developed for the design of the partially-scaled physical model. Additionally, the need for a separate transparent model for visual observation and verification of the displacement and drainage behavior under gas-assisted gravity drainage was identified. Various materials and methods (ceramic porous material, Stucco, Portland cement, sintered glass beads) were attempted in order to fabricate a satisfactory visual model. In addition to proving the effectiveness of the GAGD process (through measured oil recoveries in the range of 65 to 87% IOIP), the visual models demonstrated three possible multiphase mechanisms at work, namely, Darcy-type displacement until gas breakthrough, gravity drainage after breakthrough and film-drainage in gas-invaded zones throughout the duration of the process. The partially-scaled physical model was used in a series of experiments to study the effects of wettability, gas-oil miscibility, secondary versus tertiary mode gas injection, and the presence of fractures on GAGD oil recovery. In addition to yielding recoveries of up to 80% IOIP, even in the immiscible gas injection mode, the partially-scaled physical model confirmed the positive influence of fractures and oil-wet characteristics in enhancing oil recoveries over those measured in the homogeneous (unfractured) water-wet models. An interesting observation was that a single logarithmic relationship between the oil recovery and the gravity number was obeyed by the physical model, the high-pressure corefloods and the field data.

Dandina N. Rao; Subhash C. Ayirala; Madhav M. Kulkarni; Wagirin Ruiz Paidin; Thaer N. N. Mahmoud; Daryl S. Sequeira; Amit P. Sharma

2006-09-30T23:59:59.000Z

168

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. Annual report, June 13, 1995--June 13, 1996  

SciTech Connect (OSTI)

This project reactivates ARCO`s idle Pru Fee lease in the Midway-Sunset field, California and conducts a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming is being used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase scheduled to begin in January 1997, a continuous steamflood enhanced oil recovery will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to optimal commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program.

Deo, M.; Jenkins, C.; Sprinkel, D.; Swain, R.; Wydrinski, R.; Schamel, S.

1998-09-01T23:59:59.000Z

169

Fuel Cell Technologies Office: Recovery Act  

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

Act Act Pie chart diagram shows the breakdown of how cost-sharing funds related to the American Recovery and Reinvestment Act from industry participants, totaling $54 million (for a grand total of $96 million), are allocated within the Fuel Cell Technologies Office, updated September 2010. The diagram shows that $18.5 million is allocated to backup power, $9.7 million is allocated to lift truck, $7.6 million is allocated to portable power, $3.4 million is allocated to residential and commercial CHP, and $2.4 million is allocated to auxiliary power research. The American Recovery and Reinvestment Act of 2009 (Recovery Act) presents opportunities with potential for hydrogen and fuel cell technologies. Signed into law by President Obama on February 17, 2009, the Recovery Act is an unprecedented effort to jumpstart our economy, create or save millions of jobs, and put a down payment on addressing long-neglected challenges so our country can thrive in the twenty-first century.

170

Environmental factors affecting heavy oil recovery in the midcontinent (Kansas, Missouri and Oklahoma) USA  

Science Journals Connector (OSTI)

Thermal enhanced oil recovery (TEOR) of shallow heavy oil by cyclic steam injection or steamflooding is a commercial technology that has evolved over the past 30 years. Although TEOR may have adverse effects on the environment, these can be mitigated by careful management of standard oil field practices during TEOR process implementation. Poorly plugged old wells, natural fracturing, vertical communication between oil reservoirs and underground aquifers, and impact on air quality are a few of the environmental factors under consideration that may limit production of the midcontinent heavy oil resources. Air quality conditions and legislation are compared to those in California, which has air quality standards that are more stringent than those of the US Environmental Protection Agency (EPA). Early in the life of determining the feasibility of TEOR for a specific site, the combined resources of engineering, geological and economic feasibility, process design, and environmental assessment must be coordinated to determine the environmental impact of process implementation.

W.I. Johnson; D.K. Olsen; P.S. Sarathi

1992-01-01T23:59:59.000Z

171

Modeling of surfactant and surfactant–polymer flooding for enhanced oil recovery using STARS (CMG) software  

Science Journals Connector (OSTI)

Chemical flooding methods are now getting importance in enhanced oil recovery to recover the trapped oil after conventional recovery. Investigation has been made to characterize the surfactant solution in ter...

Sumit Kumar Rai; Achinta Bera; Ajay Mandal

2014-03-01T23:59:59.000Z

172

Oil and Gas Recovery Data from the Riser Insertion Tub - ODS...  

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

ODS Oil and Gas Recovery Data from the Riser Insertion Tub - ODS Oil and Gas Recovery Data from the Riser Insertion Tube from May 17 until the Riser Insertion Tube was disconnected...

173

Oil and Gas Recovery Data from the Riser Insertion Tub - XLS...  

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

XLS Oil and Gas Recovery Data from the Riser Insertion Tub - XLS Oil and Gas Recovery Data from the Riser Insertion Tube from May 17 until the Riser Insertion Tube was disconnected...

174

SOVENT BASED ENHANCED OIL RECOVERY FOR IN-SITU UPGRADING OF HEAVY OIL SANDS  

SciTech Connect (OSTI)

With the depletion of conventional crude oil reserves in the world, heavy oil and bitumen resources have great potential to meet the future demand for petroleum products. However, oil recovery from heavy oil and bitumen reservoirs is much more difficult than that from conventional oil reservoirs. This is mainly because heavy oil or bitumen is partially or completely immobile under reservoir conditions due to its extremely high viscosity, which creates special production challenges. In order to overcome these challenges significant efforts were devoted by Applied Research Center (ARC) at Florida International University and The Center for Energy Economics (CEE) at the University of Texas. A simplified model was developed to assess the density of the upgraded crude depending on the ratio of solvent mass to crude oil mass, temperature, pressure and the properties of the crude oil. The simplified model incorporated the interaction dynamics into a homogeneous, porous heavy oil reservoir to simulate the dispersion and concentration of injected CO2. The model also incorporated the characteristic of a highly varying CO2 density near the critical point. Since the major challenge in heavy oil recovery is its high viscosity, most researchers have focused their investigations on this parameter in the laboratory as well as in the field resulting in disparaging results. This was attributed to oil being a complex poly-disperse blend of light and heavy paraffins, aromatics, resins and asphaltenes, which have diverse behaviors at reservoir temperature and pressures. The situation is exacerbated by a dearth of experimental data on gas diffusion coefficients in heavy oils due to the tedious nature of diffusivity measurements. Ultimately, the viscosity and thus oil recovery is regulated by pressure and its effect on the diffusion coefficient and oil swelling factors. The generation of a new phase within the crude and the differences in mobility between the new crude matrix and the precipitate readily enables removal of asphaltenes. Thus, an upgraded crude low in heavy metal, sulfur and nitrogen is more conducive for further purification.

Munroe, Norman

2009-01-30T23:59:59.000Z

175

A Decade of Increased Oil Recovery in Virtual Reality  

Science Journals Connector (OSTI)

In the early '90s, VR was still in its infancy, but the Norwegian oil company Norsk Hydro saw the technology's potential. Still, there was no framework for developing VR for exploration and production. Working with the Norwegian research institute Christian ... Keywords: virtual reality, petroleum industry, oil exploration and production

Endre M. Lidal; Tor Langeland; Christopher Giertsen; Jens Grimsgaard; Rolf Helland

2007-11-01T23:59:59.000Z

176

Shallow oil production using horizontal wells with enhanced oil recovery techniques  

SciTech Connect (OSTI)

Millions of barrels of oil exist in the Bartlesville formation throughout Oklahoma, Kansas, and Missouri. In an attempt to demonstrate that these shallow heavy oil deposits can be recovered, a field project was undertaken to determine the effectiveness of enhanced oil recovery techniques (EOR) employing horizontal wells. Process screening results suggested that thermal EOR processes were best suited for the recovery of this heavy oil. Screening criteria suggested that in situ combustion was a viable technique for the production of these reserves. Laboratory combustion tube tests confirmed that sufficient amounts of fuel could be deposited. The results of the in situ combustion field pilot were disappointing. A total overall recovery efficiency of only 16.0 percent was achieved. Results suggest that the combustion front might have moved past the horizontal well, however elevated temperatures or crude upgrading were not observed. Factors contributing to the lack of production are also discussed.

Satchwell, R.M.; Johnson, L.A. Jr. [Western Research Institute, Laramie, WY (United States); Trent, R. [Univ. of Alaska, Fairbanks, AK (United States)

1995-02-01T23:59:59.000Z

177

The future of oil: Geology versus technology  

Science Journals Connector (OSTI)

Abstract We discuss and reconcile the geological and economic/technological views concerning the future of world oil production and prices, and present a nonlinear econometric model of the world oil market that encompasses both views. The model performs far better than existing empirical models in forecasting oil prices and oil output out-of-sample. Its point forecast is for a near doubling of the real price of oil over the coming decade, though the error bands are wide, reflecting sharply differing judgments on the ultimately recoverable reserves, and on future price elasticities of oil demand and supply.

Jaromir Benes; Marcelle Chauvet; Ondra Kamenik; Michael Kumhof; Douglas Laxton; Susanna Mursula; Jack Selody

2015-01-01T23:59:59.000Z

178

Int. J. Oil, Gas and Coal Technology, Vol. 7, No. 2, 2014 115 Copyright 2014 Inderscience Enterprises Ltd.  

E-Print Network [OSTI]

Int. J. Oil, Gas and Coal Technology, Vol. 7, No. 2, 2014 115 Copyright © 2014 Inderscience fields in Saudi Arabia', Int. J. Oil, Gas and Coal Technology, Vol. 7, No. 2, pp.115­131. Biographical economic recovery of oil and gas from a reservoir. The purpose of reservoir management is to control

Mohaghegh, Shahab

179

An evaluation of known remaining oil resources in the state of California: Project on advanced oil recovery and the states. Volume 2  

SciTech Connect (OSTI)

The Interstate Oil and Gas Compact Commission (IOGCC) has conducted a series of studies to evaluate the known, remaining oil resource in twenty-three (23) states. The primary objective of die IOGCC`s effort is to examine the potential impact of an aggressive and focused program of research, development, and demonstration (RD&D) and technology transfer on future oil recovery in the United States. As part of a larger effort by the IOGCC, this report focuses on the potential economic benefits of improved oil recovery in the state of California. Individual reports for seven other oil producing states and a national report have been separately published by the IOGCC. Several major technical insights for state and Federal policymakers and regulators can be reached from this analysis. Overall, well abandonments and more stringent environmental regulations could limit economic access to the nation`s known, remaining oil resource. The high risk of near-term abandonment and the significant benefits of future application of improved oil recovery technoloy, clearly point to a need for more aggressive transfer of currently available technologies to domestic oil producers. Development and application of advanced oil recovery technologies could leave even greater benefits to the nation. A collaborative, focused RD&D effort, integrating the resources and expertise of industry, state and local governments, and the Federal government, is clearly warranted. With effective RD&D and a program of aggressive technology transfer to widely disseminate its results, California oil production could be maximized. The resulting increase and improvement in production rates, employment, operator profits, state and Federal tax revenues, energy security will benefit both the state of California and the nation as a whole.

NONE

1993-11-01T23:59:59.000Z

180

An evaluation of known remaining oil resources in the United States: Project on advanced oil recovery and the states. Volume 1  

SciTech Connect (OSTI)

The Interstate Oil and Gas Compact Commission (IOGCC) has conducted a series of studies to evaluate the known, remaining oil resource in twenty-three (23) states. The primary objective of die IOGCC`s effort is to examine the potential impact of an aggressive and focused program of research, development, and demonstration (RD&D) and technology transfer on future oil recovery in the United States. As part of a larger effort by the IOGCC, this report focuses on the potential economic, social, and political benefits of improved oil recovery to the nation as a whole. Individual reports for major oil producing states have been separately published. The individual state reports include California, Illinois, Kansas, Louisiana, New Mexico, Oklahoma, Texas, and Wyoming. Overall, well abandonments and more stringent environmental regulations could limit economic access to the nation`s known, remaining oil resource. The high risk of near-term abandonment and the significant benefits of future application of improved oil recovery technoloy, clearly point to a need for more aggressive transfer of currently available technologies to domestic oil producers. Development and application of advanced oil recovery technologies could leave even greater benefits to the nation. A collaborative, focused RD&D effort, integrating the resources and expertise of industry, state and local governments, and the Federal government, is clearly warranted. With effective RD&D and a program of aggressive technology transfer to widely disseminate its results, domestic oil production could be maximized. The resulting increase and improvement in production rates, employment, operator profits, state and Federal tax revenues, energy security will benefit the nation as a whole.

NONE

1993-11-01T23:59:59.000Z

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


181

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 (OSTI)

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.

Steven Schamel

1998-02-27T23:59:59.000Z

182

Increasing Oil Productivity Through Electromagnetic Induction Heat Generation of Salt Water as a Stimulant for Heavy Oil Recovery  

Science Journals Connector (OSTI)

Brine is usually exist in the oil reservoir. Varying salinity brine are used as stimulants for heavy oil recovery processes using electromagnetic induction heating. The heated heavy oil is floating on top of the brine since it becomes less viscous and lighter. As the temperature increased more heavy oil is “produced/recovered”. An increasing salinity of brine will result in more recovery of heavy oil.

2010-01-01T23:59:59.000Z

183

Heavy oil reservoirs recoverable by thermal technology. Annual report  

SciTech Connect (OSTI)

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

Kujawa, P.

1981-02-01T23:59:59.000Z

184

High-Temperature Nuclear Reactors for In-Situ Recovery of Oil from Oil Shale  

SciTech Connect (OSTI)

The world is exhausting its supply of crude oil for the production of liquid fuels (gasoline, jet fuel, and diesel). However, the United States has sufficient oil shale deposits to meet our current oil demands for {approx}100 years. Shell Oil Corporation is developing a new potentially cost-effective in-situ process for oil recovery that involves drilling wells into oil shale, using electric heaters to raise the bulk temperature of the oil shale deposit to {approx}370 deg C to initiate chemical reactions that produce light crude oil, and then pumping the oil to the surface. The primary production cost is the cost of high-temperature electrical heating. Because of the low thermal conductivity of oil shale, high-temperature heat is required at the heater wells to obtain the required medium temperatures in the bulk oil shale within an economically practical two to three years. It is proposed to use high-temperature nuclear reactors to provide high-temperature heat to replace the electricity and avoid the factor-of-2 loss in converting high-temperature heat to electricity that is then used to heat oil shale. Nuclear heat is potentially viable because many oil shale deposits are thick (200 to 700 m) and can yield up to 2.5 million barrels of oil per acre, or about 125 million dollars/acre of oil at $50/barrel. The concentrated characteristics of oil-shale deposits make it practical to transfer high-temperature heat over limited distances from a reactor to the oil shale deposits. (author)

Forsberg, Charles W. [Oak Ridge National Laboratory, P.O. Box 2008, Oak Ridge, TN 37831-6165 (United States)

2006-07-01T23:59:59.000Z

185

NETL: News Release - Four New Projects Seek to Improve Oil Recovery on  

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

August 12, 2002 August 12, 2002 Four New Projects Seek to Improve Oil Recovery on Native American Lands Goal is Return Economic Dividends to Tribes, Strengthen Oil Security for America TULSA, OK - An estimated 890 million barrels of oil and natural gas liquids and six trillion cubic feet of natural gas are thought to exist beneath Native American lands in the lower 48 States and Alaska. Since 1999, the Department of Energy has sponsored a program to help Tribes develop and manage these resources in an environmentally sound manner. Now, following the 3rd and latest round of competition, four new projects have been added to the department's Native American Initiative. The projects were judged the best of 14 proposals by the National Energy Technology Laboratory's petroleum office in Tulsa, Oklahoma. Each teams Native American tribes with oil producers and service companies to apply the latest technological innovations to increase recovery of oil from tribal lands. Negotiations are now underway to finalize terms of the projects.

186

Oil shale: Technology status report  

SciTech Connect (OSTI)

This report documents the status of the US Department of Energy's (DOE) Oil Shale Program as of the end of FY 86. The report consists of (1) a status of oil shale development, (2) a description of the DOE Oil Shale Program, (3) an FY 86 oil shale research summary, and (4) a summary of FY 86 accomplishments. Discoveries were made in FY 86 about the physical and chemical properties and behavior of oil shales, process chemistry and kinetics, in situ retorting, advanced processes, and the environmental behavior and fate of wastes. The DOE Oil Shale Program shows an increasing emphasis on eastern US oil shales and in the development of advanced oil shale processing concepts. With the award to Foster Wheeler for the design of oil shale conceptual plants, the first step in the development of a systems analysis capability for the complete oil shale process has been taken. Unocal's Parachute Creek project, the only commercial oil shale plant operating in the United States, is operating at about 4000 bbl/day. The shale oil is upgraded at Parachute Creek for input to a conventional refinery. 67 refs., 21 figs., 3 tabs.

Not Available

1986-10-01T23:59:59.000Z

187

Chapter 7 Microbial Plugging in Enhanced Oil Recovery  

Science Journals Connector (OSTI)

Publisher Summary This chapter explores the microbial plugging problems associated with conventional water-flooding operations and evaluates the mechanisms responsible. The characteristics required of bacterial microbiologically enhanced oil recovery (MEOR) cultures for their successful injection are described and the microbial problems anticipated during other enhanced oil recovery (EOR) operations such as polymer flooding is discussed. There are two general mechanisms of microbial plugging likely to occur in the wellbore region. Two mechanisms of plugging can be distinguished: (1) particulate plugging by the microbial cells themselves and (2) viable bacterial plugging through biofilm formation. The mechanisms of microbial plugging is independently demonstrated in a model core system in which the average pore throat size is sufficiently large (33 pm) to ensure that particulate type plugging will be relatively insignificant for suspensions of singly dispersed bacteria. The importance of extracellular polymer production in microbial plugging has also been demonstrated using a culture not noted for biofilm formation.

T.R. Jack; J. Shaw; N. Wardlaw; J.W. Costerton

1989-01-01T23:59:59.000Z

188

Demonstrated Petroleum Reduction Using Oil Bypass Filter Technology...  

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

Demonstrated Petroleum Reduction Using Oil Bypass Filter Technology on Heavy and Light Vehicles Demonstrated Petroleum Reduction Using Oil Bypass Filter Technology on Heavy and...

189

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

SciTech Connect (OSTI)

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.

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

2005-12-01T23:59:59.000Z

190

Geomechanical Study of Bakken Formation for Improved Oil Recovery  

SciTech Connect (OSTI)

On October 1, 2008 US DOE-sponsored research project entitled “Geomechanical Study of Bakken Formation for Improved Oil Recovery” under agreement DE-FC26-08NT0005643 officially started at The University of North Dakota (UND). This is the final report of the project; it covers the work performed during the project period of October 1, 2008 to December 31, 2013. The objectives of this project are to outline the methodology proposed to determine the in-situ stress field and geomechanical properties of the Bakken Formation in Williston Basin, North Dakota, USA to increase the success rate of horizontal drilling and hydraulic fracturing so as to improve the recovery factor of this unconventional crude oil resource from the current 3% to a higher level. The success of horizontal drilling and hydraulic fracturing depends on knowing local in-situ stress and geomechanical properties of the rocks. We propose a proactive approach to determine the in-situ stress and related geomechanical properties of the Bakken Formation in representative areas through integrated analysis of field and well data, core sample and lab experiments. Geomechanical properties are measured by AutoLab 1500 geomechanics testing system. By integrating lab testing, core observation, numerical simulation, well log and seismic image, drilling, completion, stimulation, and production data, in-situ stresses of Bakken formation are generated. These in-situ stress maps can be used as a guideline for future horizontal drilling and multi-stage fracturing design to improve the recovery of Bakken unconventional oil.

Ling, Kegang; Zeng, Zhengwen; He, Jun; Pei, Peng; Zhou, Xuejun; Liu, Hong; Huang, Luke; Ostadhassan, Mehdi; Jabbari, Hadi; Blanksma, Derrick; Feilen, Harry; Ahmed, Salowah; Benson, Steve; Mann, Michael; LeFever, Richard; Gosnold, Will

2013-12-31T23:59:59.000Z

191

Conditions for a Low-Salinity Enhanced Oil Recovery (EOR) Effect in Carbonate Oil Reservoirs  

Science Journals Connector (OSTI)

Tertiary low-salinity effects, 2–5% of original oil in place (OOIP), were observed by first flooding the cores with high-saline formation water (208?940 ppm) and then with 100× diluted formation water or 10× diluted Gulf seawater at 110 °C. ... Evaluation of Low-Salinity Enhanced Oil Recovery Effects in Sandstone: Effects of the Temperature and pH Gradient ...

T. Austad; S. F. Shariatpanahi; S. Strand; C. J. J. Black; K. J. Webb

2011-12-13T23:59:59.000Z

192

(Passamaquoddy Technology Recovery Scrubber trademark , March 1992)  

SciTech Connect (OSTI)

The Passamaquoddy Technology Recovery Scrubber{trademark} has been built and is being demonstrated on-line at the Dragon Products Plant in Thomaston, Maine. This Innovative Clean Coal Technology is using waste cement kiln dust (CKD) to scrub sulfur dioxide, some NO{sub x}, as well as a small amount of carbon dioxide from a coal burning kiln exhaust flue gas. The process also enables the cement plant to reuse the treated CKD, eliminating the need to landfill this material. Potassium, the offending contaminant in the CKD, is extracted in a useful form, potassium sulfate, which is used as a fertilizer. These useful products generate income from operation of this Recovery Scrubber. System start-up was begun in late December of 1990. At that time, several mechanical problems were encountered. These relatively minor problems were resolved enabling Phase III to begin on August 20, 1991. While inefficiencies are still being worked out, major program objectives are being met. Resolution of remaining operability problems is well in hand and should not hamper attainment of all project goals.

Not Available

1992-03-03T23:59:59.000Z

193

SOLVENT-BASED ENHANCED OIL RECOVERY PROCESSES TO DEVELOP WEST SAK ALASKA NORTH SLOPE HEAVY OIL RESOURCES  

SciTech Connect (OSTI)

A one-year research program is conducted to evaluate the feasibility of applying solvent-based enhanced oil recovery processes to develop West Sak and Ugnu heavy oil resources found on the Alaska North Slope (ANS). The project objective is to conduct research to develop technology to produce and market the 300-3000 cp oil in the West Sak and Ugnu sands. During the first phase of the research, background information was collected, and experimental and numerical studies of vapor extraction process (VAPEX) in West Sak and Ugnu are conducted. The experimental study is designed to foster understanding of the processes governing vapor chamber formation and growth, and to optimize oil recovery. A specially designed core-holder and a computed tomography (CT) scanner was used to measure the in-situ distribution of phases. Numerical simulation study of VAPEX was initiated during the first year. The numerical work completed during this period includes setting up a numerical model and using the analog data to simulate lab experiments of the VAPEX process. The goal was to understand the mechanisms governing the VAPEX process. Additional work is recommended to expand the VAPEX numerical study using actual field data obtained from Alaska North Slope.

David O. Ogbe; Tao Zhu

2004-01-01T23:59:59.000Z

194

Enhanced Oil Recovery by Horizontal Waterflooding  

SciTech Connect (OSTI)

Solar energy has become a major alternative for supplying a substantial fraction of the nation's future energy needs. The U.S. Department of Energy (DOE) supports activities ranging from the demonstration of existing technology to research on future possibilities. At Lawrence Berkeley Laboratory (LBL), projects are in progress that span a wide range of activities, with the emphasis on research to extend the scientific basis for solar energy applications, and on preliminary development of new approaches to solar energy conversion. To assess various solar applications, it is important to quantify the solar resource. Special instruments have been developed and are now in use to measure both direct solar radiation and circum-solar radiation, i.e., the radiation from near the sun resulting from the scattering of sunlight by small particles in the atmosphere. These measurements serve to predict the performance of solar designs that use focusing collectors employing mirrors or lenses to concentrate the sunlight. Efforts have continued at a low level to assist DOE in demonstrating existing solar technology by providing the San Francisco Operations Office (SAN) with technical support for its management of commercial-building solar demonstration projects. Also, a hot water and space-heating system has been installed on an LBL building as part of the DOE facilities Solar Demonstration Program. LBL continues to provide support for the DOE Appropriate Energy Technology grants program. Evaluations are made of the program's effectiveness by, for example, estimating the resulting potential energy savings. LBL also documents innovative features and improvements in economic feasibility as compared to existing conventional systems or applications. In the near future, we expect that LBL research will have a substantial impact in the areas of solar heating and cooling. Conventional and new types of high-performance absorption air conditioners are being developed that are air-cooled and suitable for use with flat plate or higher-temperature collectors. Operation of the controls test facility and computer modeling of collector loop and building load dynamics are yielding quantitative evaluations of the performance of different control strategies for active solar-heating systems. Research is continuing on ''passive'' approaches to solar heating and cooling, where careful considerations of architectural design, construction materials, and the environment are used to moderate a building's interior climate. Computer models of passive concepts are being developed and incorporated into building energy analysis computer programs which are in the public domain. The resulting passive analysis capabilities are used in systems studies leading to design tools and in the design of commercial buildings on a case study basis. The investigation of specific passive cooling methods is an ongoing project; for example, a process is being studied in which heat-storage material would be cooled by radiation to the night sky, and would then provide ''coolness'' to the building. Laboratory personnel involved in the solar cooling, controls, and passive projects are also providing technical support to the Active Heating and Cooling Division and the Passive and Hybrid Division of DOE in developing program plans, evaluating proposals, and making technical reviews of projects at other institutions and in industry. Low-grade heat is a widespread energy resource that could make a significant contribution to energy needs if economical methods can be developed for converting it to useful work. Investigations continued this year on the feasibility of using the ''shape-memory'' alloy, Nitinol, as a basis for constructing heat engines that could operate from energy sources, such as solar-heated water, industrial waste heat, geothermal brines, and ocean thermal gradients. Several projects are investigating longer-term possibilities for utilizing solar energy. One project involves the development of a new type of solar thermal receiver that would be placed at the focus of a central

Scott Robinowitz; Dwight Dauben; June Schmeling

2005-09-05T23:59:59.000Z

195

Building Technologies Office: Recovery Act-Funded HVAC Research Projects  

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

HVAC Research Projects to someone by E-mail HVAC Research Projects to someone by E-mail Share Building Technologies Office: Recovery Act-Funded HVAC Research Projects on Facebook Tweet about Building Technologies Office: Recovery Act-Funded HVAC Research Projects on Twitter Bookmark Building Technologies Office: Recovery Act-Funded HVAC Research Projects on Google Bookmark Building Technologies Office: Recovery Act-Funded HVAC Research Projects on Delicious Rank Building Technologies Office: Recovery Act-Funded HVAC Research Projects on Digg Find More places to share Building Technologies Office: Recovery Act-Funded HVAC Research Projects on AddThis.com... About Take Action to Save Energy Partner with DOE Activities Appliances Research Building Envelope Research Windows, Skylights, & Doors Research Space Heating & Cooling Research

196

Building Technologies Office: Recovery Act-Funded Working Fluid Projects  

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

Working Fluid Projects to someone by E-mail Working Fluid Projects to someone by E-mail Share Building Technologies Office: Recovery Act-Funded Working Fluid Projects on Facebook Tweet about Building Technologies Office: Recovery Act-Funded Working Fluid Projects on Twitter Bookmark Building Technologies Office: Recovery Act-Funded Working Fluid Projects on Google Bookmark Building Technologies Office: Recovery Act-Funded Working Fluid Projects on Delicious Rank Building Technologies Office: Recovery Act-Funded Working Fluid Projects on Digg Find More places to share Building Technologies Office: Recovery Act-Funded Working Fluid Projects on AddThis.com... About Take Action to Save Energy Partner with DOE Activities Appliances Research Building Envelope Research Windows, Skylights, & Doors Research Space Heating & Cooling Research

197

Sovent Based Enhanced Oil Recovery for In-Situ Upgrading of Heavy Oil Sands  

SciTech Connect (OSTI)

With the depletion of conventional crude oil reserves in the world, heavy oil and bitumen resources have great potential to meet the future demand for petroleum products. However, oil recovery from heavy oil and bitumen reservoirs is much more difficult than that from conventional oil reservoirs. This is mainly because heavy oil or bitumen is partially or completely immobile under reservoir conditions due to its extremely high viscosity, which creates special production challenges. In order to overcome these challenges significant efforts were devoted by Applied Research Center (ARC) at Florida International University and The Center for Energy Economics (CEE) at the University of Texas. A simplified model was developed to assess the density of the upgraded crude depending on the ratio of solvent mass to crude oil mass, temperature, pressure and the properties of the crude oil. The simplified model incorporated the interaction dynamics into a homogeneous, porous heavy oil reservoir to simulate the dispersion and concentration of injected CO{sub 2}. The model also incorporated the characteristic of a highly varying CO{sub 2} density near the critical point. Since the major challenge in heavy oil recovery is its high viscosity, most researchers have focused their investigations on this parameter in the laboratory as well as in the field resulting in disparaging results. This was attributed to oil being a complex poly-disperse blend of light and heavy paraffins, aromatics, resins and asphaltenes, which have diverse behaviors at reservoir temperature and pressures. The situation is exacerbated by a dearth of experimental data on gas diffusion coefficients in heavy oils due to the tedious nature of diffusivity measurements. Ultimately, the viscosity and thus oil recovery is regulated by pressure and its effect on the diffusion coefficient and oil swelling factors. The generation of a new phase within the crude and the differences in mobility between the new crude matrix and the precipitate readily enables removal of asphaltenes. Thus, an upgraded crude low in heavy metal, sulfur and nitrogen is more conducive for further purification.

Norman Munroe

2009-01-30T23:59:59.000Z

198

Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 86, quarter ending March 31, 1996  

SciTech Connect (OSTI)

Summaries are presented for 37 enhanced oil recovery contracts being supported by the Department of Energy. The projects are grouped into gas displacement methods, thermal recovery methods, geoscience technology, reservoir characterization, and field demonstrations in high-priority reservoir classes. Each summary includes the objectives of the project and a summary of the technical progress, as well as information on contract dates, size of award, principal investigator, and company or facility doing the research.

NONE

1997-05-01T23:59:59.000Z

199

IMPROVED OIL RECOVERY IN MISSISSIPPIAN CARBONATE RESERVOIRS OF KANSAS--NEAR TERM--CLASS 2  

SciTech Connect (OSTI)

This annual report describes progress during the third year of the project entitled ''Improved Oil Recovery in Mississippian Carbonate Reservoirs in Kansas''. This project funded under the Department of Energy's Class 2 program targets improving the reservoir performance of mature oil fields located in shallow shelf carbonate reservoirs. The focus of this project is development and demonstration of cost-effective reservoir description and management technologies to extend the economic life of mature reservoirs in Kansas and the mid-continent. The project introduced a number of potentially useful technologies, and demonstrated these technologies in actual oil field operations. Advanced technology was tailored specifically to the scale appropriate to the operations of Kansas producers. An extensive technology transfer effort is ongoing. Traditional technology transfer methods (e.g., publications and workshops) are supplemented with a public domain relational database and an online package of project results that is available through the Internet. The goal is to provide the independent complete access to project data, project results and project technology on their desktop. Included in this report is a summary of significant project results at the demonstration site (Schaben Field, Ness County, Kansas). The value of cost-effective techniques for reservoir characterization and simulation at Schaben Field were demonstrated to independent operators. All major operators at Schaben have used results of the reservoir management strategy to locate and drill additional infill locations. At the Schaben Demonstration Site, the additional locations resulted in incremental production increases of 200 BOPD from a smaller number of wells.

Timothy R. Carr; Don W. Green; G. Paul Willhite

1999-06-01T23:59:59.000Z

200

SolarOil Project, Phase I preliminary design report. [Solar Thermal Enhanced Oil Recovery project  

SciTech Connect (OSTI)

The preliminary design of the Solar Thermal Enhanced Oil Recovery (SolarOil) Plant is described in this document. This plant is designed to demonstrate that using solar thermal energy is technically feasible and economically viable in enhanced oil recovery (EOR). The SolarOil Plant uses the fixed mirror solar concentrator (FMSC) to heat high thermal capacity oil (MCS-2046) to 322/sup 0/C (611/sup 0/F). The hot fluid is pumped from a hot oil storage tank (20 min capacity) through a once-through steam generator which produces 4.8 MPa (700 psi) steam at 80% quality. The plant net output, averaged over 24 hr/day for 365 days/yr, is equivalent to that of a 2.4 MW (8.33 x 10/sup 6/ Btu/hr) oil-fired steam generator having an 86% availability. The net plant efficiency is 57.3% at equinox noon, a 30%/yr average. The plant will be demonstrated at an oilfield site near Oildale, California.

Baccaglini, G.; Bass, J.; Neill, J.; Nicolayeff, V.; Openshaw, F.

1980-03-01T23:59:59.000Z

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


201

Analysis of Heavy Oil Recovery by Thermal EOR in a Meander Belt: From Geological  

E-Print Network [OSTI]

Analysis of Heavy Oil Recovery by Thermal EOR in a Meander Belt: From Geological to Reservoir Energies nouvelles2 INTRODUCTION SAGD will become increasingly important for heavy oil recovery because assessment, well placement and production performance prediction. One of the most famous heavy oil provinces

Paris-Sud XI, Université de

202

Advanced Oil Spill Recovery in Marine Environments Victoria Broje and Arturo A. Keller  

E-Print Network [OSTI]

Advanced Oil Spill Recovery in Marine Environments Victoria Broje and Arturo A. Keller Bren School of Environmental Science and Management, University of California, Santa Barbara Almost 14,000 oil spills research will help identifying parameters having major effect on oil adhesion to the recovery surface

Keller, Arturo A.

203

Enhanced Oil Recovery through Steam Assisted Gravity Drainage January 22, 2014  

E-Print Network [OSTI]

Enhanced Oil Recovery through Steam Assisted Gravity Drainage January 22, 2014 A Comparative Study Of Continuous And Cyclic Steam Injection With Trapping Of Oil Phase Muhammad Adil Javed Summary of Thesis Enhanced oil recovery (EOR) through steam-assisted gravity drainage (SAGD) has become an important in

Cirpka, Olaf Arie

204

Effect of Gas Diffusion on Mobility of Foam for Enhanced Oil Recovery Lars E. Nonnekes1  

E-Print Network [OSTI]

Effect of Gas Diffusion on Mobility of Foam for Enhanced Oil Recovery Lars E. Nonnekes1 Foam can improve the sweep efficiency of gas injected into oil reservoirs for enhanced oil recovery University William Richard Rossen Email: W.R.Rossen@tudelft.nl Abstract Transport of gas across

Cox, Simon

205

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

SciTech Connect (OSTI)

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 alkaline-surfactant-polymer injected solution were observed. Aluminum citrate-polyacrylamide, resorcinol-formaldehyde, and the silicate-polyacrylamide gel systems did not produce significant incremental oil in linear corefloods. Both flowing and rigid flowing chromium acetate-polyacrylamide gels and the xanthan gum-chromium acetate gel system 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 appeared to alter alkaline-surfactant-polymer solution oil recovery. Total waterflood plus chemical flood oil recovery sequence recoveries were all similar. Chromium acetate-polyacrylamide gel used to seal fractured core maintain fracture closure if followed by an alkaline-surfactant-polymer solution. Chromium acetate gels that were stable to injection of alkaline-surfactant-polymer solutions at 72 F were stable to injection of alkaline-surfactant-polymer solutions at 125 F and 175 F in linear corefloods. Chromium acetate-polyacrylamide gels maintained diversion capability after injection of an alkaline-surfactant-polymer solution in stacked; radial coreflood with a common well bore. Xanthan gum-chromium acetate gels maintained gel integrity in linear corefloods after injection of an alkaline-surfactant-polymer solution at 125 F. At 175 F, Xanthan gum-chromium acetate gels were not stable either with or without subsequent alkaline-surfactant-polymer solution injection. 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 when a gel was placed in the B sand. A sand and B sand alkaline-surfactant-polymer flood oil recovery was improved by 596,000 bbls when a gel was placed in the B sand. Alkaline-surfactant-pol

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

2005-10-01T23:59:59.000Z

206

Microbial enhanced oil recovery research. Final report, Annex 5  

SciTech Connect (OSTI)

The objective of this project was to develop an engineering framework for the exploitation of microorganisms to enhance oil recovery. An order of magnitude analysis indicated that selective plugging and the production of biosurfactants are the two most likely mechanisms for the mobilization of oil in microbial enhanced oil recovery (MEOR). The latter, biosurfactant production, is easier to control within a reservoir environment and was investigated in some detail. An extensive literature survey indicated that the bacterium Bacillus licheniformis JF-2 produces a very effective surface active agent capable of increasing the capillary number to values sufficiently low for oil mobilization. In addition, earlier studies had shown that growth of this bacterium and biosurfactant production occur under conditions that are typically encountered in MEOR, namely temperatures up to 55{degrees}C, lack of oxygen and salinities of up to 10% w/v. The chemical structure of the surfactant, its interfacial properties and its production by fermentation were characterized in some detail. In parallel, a set of experiments as conducted to measure the transport of Bacillus licheniformis JF-2 in sandpacks. It was shown that the determining parameters for cell transport in porous media are: cell size and degree of coagulation, presence of dispersants, injection velocity and cell concentration. The mechanisms of bacteria retention within the pores of the reservoir were analyzed based on heuristic arguments. A mathematical simulator of MEOR was developed using conservation equations in which the mechanisms of bacteria retention and the growth kinetics of the cells were incorporated. The predictions of the model agreed reasonably well with experimental results.

Sharma, M.M.; Gerogiou, G.

1993-07-01T23:59:59.000Z

207

Multi-level analysis of field synergy in the displacement mechanisms of heavy oil thermal recovery  

Science Journals Connector (OSTI)

One of the major problems of heavy oil thermal recovery is the inadequacy of understanding the multi-field coupling displacement mechanisms to improve the oil production and extraction ratio. From the perspect...

Yang Liu; Qinglin Cheng; Xuxu Wang; Xinyao Xiang

2014-02-01T23:59:59.000Z

208

Enhanced oil recovery through water imbibition in fractured reservoirs using Nuclear Magnetic Resonance  

E-Print Network [OSTI]

Conventional waterflooding methods of oil recovery are difficult to apply when reservoirs show evidence of natural fractures, because injected water advances through paths of high permeability, and oil trapped in the rock matrix system...

Hervas Ordonez, Rafael Alejandro

2012-06-07T23:59:59.000Z

209

Optimal Control of Vapor Extraction of Heavy Oil.  

E-Print Network [OSTI]

??Vapor extraction (Vapex) process is an emerging technology for viscous oil recovery that has gained much attention in the oil industry. However, the oil production… (more)

Muhamad, Hameed (Author)

2012-01-01T23:59:59.000Z

210

Enhanced oil recovery through water imbibition in fractured reservoirs using Nuclear Magnetic Resonance.  

E-Print Network [OSTI]

??Conventional waterflooding methods of oil recovery are difficult to apply when reservoirs show evidence of natural fractures, because injected water advances through paths of high… (more)

Hervas Ordonez, Rafael Alejandro

2012-01-01T23:59:59.000Z

211

A parametric study on reservoir cooling for enhanced oil recovery from CO2 injection.  

E-Print Network [OSTI]

??Whorton et al. (1952) received a patent for their development of an oil recovery method by CO2 injection. Since then, CO2 flooding for secondary and… (more)

Wang, Zhenzhen

2013-01-01T23:59:59.000Z

212

Improved Oil Recovery in Fluvial Dominated Deltaic Reservoirs of Kansas Near Term  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Morrow sandstone reservoirs in southwestern Kansas and Cherokee Group reservoirs in southeastern Kansas. Two demonstration sites operated by different independent oil operators are involved in this project. The Stewart Field is located in Finney County, Kansas and is operated by North American Resources Company. The Nelson Lease is located in Allen County, Kansas, in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. General topics to be addressed are (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. In the Stewart Project, the reservoir management portion of the project conducted during Budget Period I involved performance evaluation. This included (1) reservoir characterization and the development of a reservoir database, (2) volumetric analysis to evaluate production performance, (3) reservoir modeling, (4) laboratory work, (5) identification of operational problems, (6) identification of unrecovered mobile oil and estimation of recovery factors, and (7) identification of the most efficient and economical recovery process. To accomplish these objectives the initial budget period was subdivided into three major tasks. The tasks were (1) geological and engineering analysis, (2) laboratory testing, and (3) unitization. Due to the presence of different operators within the field, it was necessary to unitize the field in order to demonstrate a field-wide improved recovery process. This work was completed and the project moved into Budget Period 2. Budget Period 2 objectives consisted of the design, construction, and operation of a field-wide waterflood utilizing state-of-the-art, off-the-shelf technologies in an attempt to optimize secondary oil recovery. To accomplish these objectives the second budget period was subdivided into five major tasks. The tasks were (1) design and construction of a waterflood plant, (2) design and construction of a water injection system, (3) design and construction of tank battery consolidation and gathering system, (4) initiation of waterflood operations and reservoir management, and (5) technology transfer. In the Savonburg Project, the reservoir management portion involves performance evaluation. This work included (1) reservoir characterization and the development of a reservoir database, (2) identification of operational problems, (3) identification of near wellbore problems such as plugging caused from poor water quality, (4) identification of unrecovered mobile oil and estimation of recovery factors, and (5) preliminary identification of the most efficient and economical recovery process i.e., polymer augmented waterflooding or infill drilling (vertical or horizontal wells). To accomplish this work the initial budget period was subdivided into four major tasks. The tasks included (1) geological and engineering analysis, (2) waterplant optimization, (3) wellbore cleanup and pattern changes, and (4) field operations. This work was completed and the project has moved into Budget Period 2. The Budget Period 2 objectives consisted of continual optimization of this mature waterflood in an attempt to optimize secondary and tertiary oil recovery. To accomplish these objectives the second budget period was subdivided into six major tasks. The tasks were (1) waterplant development, (2) profile modification treatments, (3) pattern changes, new wells and wellbore cleanups, (4) reservoir development (polymer flooding), (5) field operations, and (6) technology transfer.

Green, D.W.; Willhlte, C.P.; Walton, A.; Schoeling, L.; Reynolds, R.; Michnick, M.; Watney, L.

1997-04-15T23:59:59.000Z

213

Improved Oil Recovery in Fluvial Dominated Deltaic Reservoirs of Kansas - Near-Term  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Morrow sandstone reservoirs in southwestern Kansas and in Cherokee Group reservoirs in southeastern Kansas. Two demonstration sites operated by different independent oil operators are involved in this project. The Stewart Field is located in Finney County, Kansas and is operated by North American Resources Company. The Nelson Lease is located in Allen County, Kansas, in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. General topics to be addressed are 1) reservoir management and performance evaluation, 2) waterflood optimization, and 3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. In the Stewart Project, the reservoir management portion of the project conducted during Budget Period 1 involved performance evaluation. This included 1) reservoir characterization and the development of a reservoir database, 2) volumetric analysis to evaluate production performance, 3) reservoir modeling, 4) laboratory work, 5) identification of operational problems, 6) identification of unrecovered mobile oil and estimation of recovery factors, and 7) identification of the most efficient and economical recovery process. To accomplish these objectives the initial budget period was subdivided into three major tasks. The tasks were 1) geological and engineering analysis, 2) laboratory testing, and 3) unitization. Due to the presence of different operators within the field, it was necessary to unitize the field in order to demonstrate a field-wide improved recovery process. This work was completed and the project moved into Budget Period 2. Budget Period 2 objectives consisted of the design, construction, and operation of a field-wide waterflood utilizing state-of-the-art, off-the-shelf technologies in an attempt to optimize secondary oil recovery. To accomplish these objectives the second budget period was subdivided into five major tasks. The tasks were 1) design and construction of a waterflood plant, 2) design and construction of a water injection system, 3) design and construction of tank battery consolidation and gathering system, 4) initiation of waterflood operations and reservoir management, and 5) technology transfer. Tasks 1-3 have been completed and water injection began in October 1995. In the Savonburg Project, the reservoir management portion involves performance evaluation. This work included 1) reservoir characterization and the development of a reservoir database, 2) identification of operational problems, 3) identification of near wellbore problems such as plugging caused from poor water quality, 4) identification of unrecovered mobile oil and estimation of recovery factors, and 5) preliminary identification of the most efficient and economical recovery process i.e., polymer augmented waterflooding or infill drilling (vertical or horizontal wells). To accomplish this work the initial budget period was subdivided into four major tasks. The tasks included 1) geological and engineering analysis, 2) waterplant optimization, 3) wellbore cleanup and pattern changes, and 4) field operations. This work was completed and the project has moved into Budget Period 2. The Budget Period 2 objectives consisted of continual optimization of this mature waterflood in an attempt to optimize secondary and tertiary oil recovery. To accomplish these objectives the second budget period is subdivided into six major tasks. The tasks were 1) waterplant development, 2) profile modification treatments, 3) pattern changes, new wells and wellbore cleanups, 4) reservoir development (polymer flooding), 5) field operations, and 6) technology transfer.

A. Walton; Don W. Green; G. Paul Whillhite; L. Schoeling; L. Watney; M. Michnick; R. Reynolds

1997-07-15T23:59:59.000Z

214

Oil shale technology. Final report  

SciTech Connect (OSTI)

This collaborative project with industrial participants studied oil shale retorting through an integrated program of fundamental research, mathematical model development and operation of a 4-tonne-per-day solid recirculation oil shale test unit. Quarterly, project personnel presented progress and findings to a Project Guidance Committee consisting of company representatives and DOE program management. We successfully operated the test unit, developed the oil shale process (OSP) mathematical model, evaluated technical plans for process scale up and determined economics for a successful small scale commercial deployment, producing premium motor fuel, specility chemicals along with electricity co-production. In budget negotiations, DOE funding for this three year CRADA was terminated, 17 months prematurely, as of October 1993. Funds to restore the project and continue the partnership have not been secured.

NONE

1995-03-01T23:59:59.000Z

215

An investigation of oil recovery by injection of CO? and LPG mixtures  

E-Print Network [OSTI]

in light hydrocarbons, due to a selective extraction by the CO2 was believed to be responsible for the attractively high oil recoveries. Holm ' further re- ported additional oil recoveries of 6 to 15 per cent of the original oil in place by blowing down... the pressure in the reservoir. The blow down recovery was found to be a function of the oil left after flooding. Further work on CO2 flooding revealed that carbon 16 dioxide is not completely miscible with most reservoir oils at reservoir pressures...

Kumar, Naresh

1972-01-01T23:59:59.000Z

216

Evaluating technologies of oil spill surveillance  

SciTech Connect (OSTI)

Surveillance and monitoring of oil in the marine environment imposes a broad spectrum of remote sensing requirements. At the US Coast Guard Research Development Center, the environmental safety branch is sponsoring oil spill remote sensing research in four areas of technology: Synthetic aperture radar (SAR), Frequency-scanning microwave radiometry (FSR), Laser fluorosensing (LFS), and Forward-looking infrared (FLIR) imagers. SAR technology uses sophisticated signal processing to overcome prior limitations, providing images of higher and more uniform spatial acuity which may enable interpreters to more-readily distinguish petroleum slicks from others. The ability to determine the distribution of oil thickness within a slick is necessary when an estimate of oil volume is desired. Scientists at MIT have formulated a new approach to radiometric oil thickness measurement that takes advantage of recent advances in electronic component technology. The initial data collected with a prototype FSR instrument have validated the FSR concept and more work is ongoing. The Coast Guard is co-funding a program to demonstrate and evaluate the capabilities of an airborne laser fluorosensor to support oil spill response operations. During a controlled test, the instrument successfully demonstrated an ability to detect oil on water, ice, and various beach surfaces. Additional testing included different oil types and allowed for weathering. Data analysis is ongoing. Recent developments in infrared imager technology have produced a wide variety of off-the-shelf, portable cameras that could potentially provide a rapid-response spill assessment capability. The R D Center has been involved in the testing of many of these sensors.

Hover, G.L.

1993-07-01T23:59:59.000Z

217

Interaction of Escherichia coli B and B/4 and Bacteriophage T4D with Berea Sandstone Rock in Relation to Enhanced Oil Recovery  

Science Journals Connector (OSTI)

...mated two-thirds of the world's oil, or some 1012 barrels of petroleum reserves, are not recoverable by...by U.S. Department of Energy Contract DE-AS19-81BC10508...Oil Recovery. Bartlesville Energy Technology Center, Bartlesville...

Philip L. Chang; Teh Fu Yen

1984-03-01T23:59:59.000Z

218

Oil Bypass filter technology evaluation final report  

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

6-01355 6-01355 U.S. Department of Energy FreedomCAR & Vehicle Technologies Program Oil Bypass Filter Technology Evaluation Final Report TECHNICAL REPORT Larry Zirker James Francfort Jordan Fielding March 2006 Idaho National Laboratory Operated by Battelle Energy Alliance INL/EXT-06-01355 U.S. Department of Energy FreedomCAR & Vehicle Technologies Program Oil Bypass Filter Technology Evaluation Final Report Larry Zirker James Francfort Jordan Fielding March 2006 Idaho National Laboratory Transportation Technology Department Idaho Falls, Idaho 83415 Prepared for the U.S. Department of Energy Assistant Secretary for Energy Efficiency and Renewable Energy Under DOE Idaho Operations Office Contract DE-AC07-05ID14517

219

Thermally-enhanced oil recovery method and apparatus  

DOE Patents [OSTI]

A thermally-enhanced oil recovery method and apparatus for exploiting deep well reservoirs utilizes electric downhole steam generators to provide supplemental heat to generate high quality steam from hot pressurized water which is heated at the surface. A downhole electric heater placed within a well bore for local heating of the pressurized liquid water into steam is powered by electricity from the above-ground gas turbine-driven electric generators fueled by any clean fuel such as natural gas, distillate or some crude oils, or may come from the field being stimulated. Heat recovered from the turbine exhaust is used to provide the hot pressurized water. Electrical power may be cogenerated and sold to an electric utility to provide immediate cash flow and improved economics. During the cogeneration period (no electrical power to some or all of the downhole units), the oil field can continue to be stimulated by injecting hot pressurized water, which will flash into lower quality steam at reservoir conditions. The heater includes electrical heating elements supplied with three-phase alternating current or direct current. The injection fluid flows through the heater elements to generate high quality steam to exit at the bottom of the heater assembly into the reservoir. The injection tube is closed at the bottom and has radial orifices for expanding the injection fluid to reservoir pressure.

Stahl, Charles R. (Scotia, NY); Gibson, Michael A. (Houston, TX); Knudsen, Christian W. (Houston, TX)

1987-01-01T23:59:59.000Z

220

Vehicle Technologies Office: Waste Heat Recovery | Department...  

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

Batteries Fuel Efficiency & Emissions Combustion Engines Fuel Effects on Combustion Idle Reduction Emissions Waste Heat Recovery Lightweighting Parasitic Loss Reduction Lubricants...

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


221

An evaluation of known remaining oil resources in the United States: Project on advanced oil recovery and the states. Volume 1  

SciTech Connect (OSTI)

The Interstate Oil and Gas Compact Commission (IOGCC) has conducted a series of studies to evaluate the known, remaining oil resource in twenty-three (23) states. The primary objective of the IOGCC`s effort is to examine the potential impact of an aggressive and focused program of research, development, and demonstration (RD&D) and technology transfer on future oil recovery in the United States. As part of a larger effort by the IOGCC, this report focuses on the potential economic, social, and political benefits of improved oil recovery to the nation as a whole. Individual reports for major oil producing states have been separately published. The individual state reports include California, Illinois, Kansas, Louisiana, New Mexico, Oklahoma, Texas, and Wyoming. The analysis presented in this report is based on the databases and models available in the Tertiary Oil Recovery Information System (TORIS). TORIS is a tested and verified system maintained and operated by the Department of Energy`s Bartlesville Project Office. The TORTS system was used to evaluate over 2,300 major reservoirs in a consistent manner and on an individual basis, the results of which have been aggregated to arrive at the national total.

Not Available

1994-10-01T23:59:59.000Z

222

DOE-Sponsored Technology Enhances Recovery of Natural Gas in Wyoming |  

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

Sponsored Technology Enhances Recovery of Natural Gas in Sponsored Technology Enhances Recovery of Natural Gas in Wyoming DOE-Sponsored Technology Enhances Recovery of Natural Gas in Wyoming March 26, 2009 - 1:00pm Addthis Washington, DC --Research sponsored by the U.S. Department of Energy (DOE) Oil and Natural Gas Program has found a way to distinguish between groundwater and the water co-produced with coalbed natural gas, thereby boosting opportunities to tap into the vast supply of natural gas in Wyoming as well as Montana. In a recently completed project, researchers at the University of Wyoming used the isotopic carbon-13 to carbon-12 ratio to address environmental issues associated with water co-produced with coalbed natural gas. The research resulted in a patent application for this unique use of the ratio.

223

DOE-Sponsored Technology Enhances Recovery of Natural Gas in Wyoming |  

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

Technology Enhances Recovery of Natural Gas in Technology Enhances Recovery of Natural Gas in Wyoming DOE-Sponsored Technology Enhances Recovery of Natural Gas in Wyoming March 26, 2009 - 1:00pm Addthis Washington, DC --Research sponsored by the U.S. Department of Energy (DOE) Oil and Natural Gas Program has found a way to distinguish between groundwater and the water co-produced with coalbed natural gas, thereby boosting opportunities to tap into the vast supply of natural gas in Wyoming as well as Montana. In a recently completed project, researchers at the University of Wyoming used the isotopic carbon-13 to carbon-12 ratio to address environmental issues associated with water co-produced with coalbed natural gas. The research resulted in a patent application for this unique use of the ratio. An added benefit of the project, which was managed by the National Energy

224

Upgrading and enhanced recovery of Jobo heavy oil using hydrogen donor under in-situ combustion  

E-Print Network [OSTI]

UPGRADING AND ENHANCED RECOVERY OF JOBO HEAVY OIL USING HYDROGEN DONOR UNDER IN-SITU COMBUSTION A... UPGRADING AND ENHANCED RECOVERY OF JOBO HEAVY OIL USING HYDROGEN DONOR UNDER IN-SITU COMBUSTION A Thesis by SAMIR HUSEYNZADE Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements...

Huseynzade, Samir

2008-10-10T23:59:59.000Z

225

Heavy oil reservoirs recoverable by thermal technology. Annual report  

SciTech Connect (OSTI)

This volume contains reservoir, production, and project data for target reservoirs which contain heavy oil in the 8 to 25/sup 0/ API gravity range and are susceptible to recovery by in situ combustion and steam drive. The reservoirs for steam recovery are less than 2500 feet deep to comply with state-of-the-art technology. In cases where one reservoir would be a target for in situ combustion or steam drive, that reservoir is reported in both sections. Data were collectd from three source types: hands-on (A), once-removed (B), and twice-removed (C). In all cases, data were sought depicting and characterizing individual reservoirs as opposed to data covering an entire field with more than one producing interval or reservoir. The data sources are listed at the end of each case. This volume also contains a complete listing of operators and projects, as well as a bibliography of source material.

Kujawa, P.

1981-02-01T23:59:59.000Z

226

Synchrophasor Technologies and their Deployment in the Recovery Act Smart  

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

Synchrophasor Technologies and their Deployment in the Recovery Act Synchrophasor Technologies and their Deployment in the Recovery Act Smart Grid Programs (August 2013) Synchrophasor Technologies and their Deployment in the Recovery Act Smart Grid Programs (August 2013) The American Recovery and Reinvestment Act of 2009 provided $4.5 billion for the Smart Grid Investment Grant (SGIG), Smart Grid Demonstration Program (SGDP), and other DOE smart grid programs. These programs provided grants to the electric utility industry to deploy smart grid technologies to modernize the nation's electric grid. As a part of these programs, independent system operators, regional transmission organizations, and electric utilities installed synchrophasor and supporting technologies and systems in their electric power transmission systems.

227

Improved Oil Recovery in Fluvial Dominated Deltaic Reservoirs of Kansas - Near-Term  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Morrow sandstone reservoirs in southwestern Kansas and in Cherokee Group reservoirs in southeastern Kansas. Two demonstration sites operated by different independent oil operators are involved in this project. The Stewart Field is located in Finney County, Kansas and is operated by PetroSantander, Inc. Te Nelson Lease is located in Allen County, Kansas, in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. General topics to be addressed are (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. In the Stewart Project, the reservoir management portion of the project conducted during Budget Period 1 involved performance evaluation. This included (1) reservoir characterization and the development of a reservoir database, (2) volumetric analysis to evaluate production performance, (3) reservoir modeling, (4) laboratory work, (5) identification of operational problems, (6) identification of unrecovered mobile oil and estimation of recovery factors, and (7) identification of the most efficient and economical recovery process. To accomplish these objectives the initial budget period was subdivided into three major tasks. The tasks were (1) geological and engineering analysis, (2) laboratory testing, and (3) unitization. Due to the presence of different operators within the field, it was necessary to unitize the field in order to demonstrate a field-wide improved recovery process. This work was completed and the project moved into Budget Period 2.

Green, D.W.; McCune, D.; Michnick, M.; Reynolds, R.; Walton, A.; Watney, L.; Willhite G.P.

1999-10-29T23:59:59.000Z

228

Improved Oil Recovery in Fluvial Dominated Deltaic Reservoirs of Kansas - Near-Term  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Morrow sandstone reservoirs in southwestern Kansas and in Cherokee Group reservoirs in southeastern Kansas. Two demonstration sites operated by different independent oil operators are involved in this project. The Stewart Field is located in Finney County, Kansas and is operated by PetroSantander, Inc. Te Nelson Lease is located in Allen County, Kansas, in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. General topics to be addressed are (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. In the Stewart Project, the reservoir management portion of the project conducted during Budget Period 1 involved performance evaluation. This included (1) reservoir characterization and the development of a reservoir database, (2) volumetric analysis to evaluate production performance, (3) reservoir modeling, (4) laboratory work, (5) identification of operational problems, (6) identification of unrecovered mobile oil and estimation of recovery factors, and (7) Identification of the most efficient and economical recovery process. To accomplish these objectives the initial budget period was subdivided into three major tasks. The tasks were (1) geological and engineering analysis, (2) laboratory testing, and (3) unitization. Due to the presence of different operators within the field, it was necessary to unitize the field in order to demonstrate a field-wide improved recovery process. This work was completed and the project moved into Budget Period 2.

Green, Don W.; McCune, A.D.; Michnick, M.; Reynolds, R.; Walton, A.; Watney, L.; Willhite, G. Paul

1999-11-03T23:59:59.000Z

229

Waterflood control system for maximizing total oil recovery  

DOE Patents [OSTI]

A control system and method for determining optimal fluid injection pressure is based upon a model of a growing hydrofracture due to waterflood injection pressure. This model is used to develop a control system optimizing the injection pressure by using a prescribed injection goal coupled with the historical times, pressures, and volume of injected fluid at a single well. In this control method, the historical data is used to derive two major flow components: the transitional component, where cumulative injection volume is scaled as the square root of time, and a steady-state breakthrough component, which scales linearly with respect to time. These components provide diagnostic information and allow for the prevention of rapid fracture growth and associated massive water break through that is an important part of a successful waterflood, thereby extending the life of both injection and associated production wells in waterflood secondary oil recovery operations.

Patzek, Tadeusz Wiktor (Oakland, CA); Silin, Dimitriy Borisovich (Pleasant Hill, CA); De, Asoke Kumar (San Jose, CA)

2007-07-24T23:59:59.000Z

230

Biosurfactant Activity for Enhanced Oil Recovery Final Report  

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

Development of Microorganisms with Improved Transport and Development of Microorganisms with Improved Transport and Biosurfactant Activity for Enhanced Oil Recovery Final Report Report Start Date: June 1, 2002 Report End Date: August 31, 2005 M. J. McInerney, K.E. Duncan, N. Youssef, T. Fincher, S. K. Maudgalya, M. J. Folmsbee, R. Knapp, Randy R. Simpson, N. Ravi, and D. Nagle Date of Report: August 15, 2005 DE-FC-02NT15321 R 02 Department of Botany and Microbiology and Department of Petroleum Engineering University of Oklahoma 770 Van Vleet Oval Norman, OK 73019-0245 2 Disclaimer This report was prepared as an account of work sponsored by an agency of the United States Government. Neither the United States Government not any agency thereof, nor any of their employees, makes any warranty, expressed or implied, or

231

Department of Energy Recovery Act Investment in Biomass Technologies  

Broader source: Energy.gov [DOE]

The American Recovery and Reinvestment Act of 2009 (Recovery Act) provided more than $36 billion to the Department of Energy (DOE) to accelerate work on existing projects, undertake new and transformative research, and deploy clean energy technologies across the nation. Of this funding, $1029 million is supporting innovative work to advance biomass research, development, demonstration, and deployment.

232

Post-Shred Materials Recovery Technology Development and Demonstration...  

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

Annual Merit Review and Peer Evaluation Meeting, May 18-22, 2009 -- Washington D.C. lm29jody.pdf More Documents & Publications Post-Shred Materials Recovery Technology...

233

Horizontal well improves oil recovery from polymer flood--  

SciTech Connect (OSTI)

Horizontal drilling associated with an injection scheme appears to be highly promising for obtaining additional oil recovery. Horizontal well CR 163H, in the Chateaurenard field is discussed. It demonstrated that a thin unconsolidated sand can be successfully drilled and cased. The productivity index (PI) of the well was much greater than vertical wells, and an unproduced oil bank was successfully intersected. On the negative side, it was necessary to pump low in a very deviated part of the well, and the drilling cost was high compared to an onshore vertical well. CR 163H was the fifth and probably most difficult horizontal well drilled by Elf Aquitaine. Located within a polymer-flood project, the target was a 7-m thick sand reservoir at a vertical depth of 590:0080 m. In this inverted seven-spot configuration with one injector in the center and six producers at a distance of 400 m, a polymer solution was injected from 1977 to 1983, followed by water injection.

Bruckert, L. (Elf Aquitaine, Boussens, (FR))

1989-12-18T23:59:59.000Z

234

Conversion Technologies for Advanced Biofuels – Bio-Oil Production  

Broader source: Energy.gov [DOE]

RTI International report-out at the CTAB webinar on Conversion Technologies for Advanced Biofuels – Bio-Oil Production.

235

Effect of the Particle Surface on Oil Recovery from Petroleum Sludge  

Science Journals Connector (OSTI)

The effective disposal of oily sludge generated from the petroleum industry has received increasing concerns, and oil recovery from such waste was considered as one feasible option. ... A no. of crude oils and petroleum products were tested with the surface materials that are used or may potentially be used to recover oil spills. ...

Qunxing Huang; Xu Han; Feiyan Mao; Yong Chi; Jianhua Yan

2014-06-20T23:59:59.000Z

236

Disturbance and Recovery of Salt Marsh Arthropod Communities following BP Deepwater Horizon Oil Spill  

E-Print Network [OSTI]

Disturbance and Recovery of Salt Marsh Arthropod Communities following BP Deepwater Horizon Oil of Houston, Houston, Texas, United States of America Abstract Oil spills represent a major environmental.S. Gulf of Mexico is a hub of oil and gas exploration activities that historically have impacted

Pennings, Steven C.

237

Efficient screening of enhanced oil recovery methods and predictive economic analysis  

Science Journals Connector (OSTI)

Oil demand for economic development around the world is rapidly increasing. Moreover, oil production rates are getting a peak in mature reservoirs and tending to decline in the near future, which has led to considerable researches on enhanced oil recovery ... Keywords: Artificial neural network, EOR data, Economical study, Fluid characteristics, Rock, Screening

Arash Kamari, Mohammad Nikookar, Leili Sahranavard, Amir H. Mohammadi

2014-09-01T23:59:59.000Z

238

Surfactant Based Enhanced Oil Recovery and Foam Mobility Control  

SciTech Connect (OSTI)

Surfactant flooding has the potential to significantly increase recovery over that of conventional waterflooding. The availability of a large number of surfactant structures makes it possible to conduct a systematic study of the relation between surfactant structure and its efficacy for oil recovery. A mixture of two surfactants was found to be particularly effective for application in carbonate formations at low temperature. The mixture is single phase for higher salinity or calcium concentrations than that for either surfactant used alone. This makes it possible to inject the surfactant slug with polymer close to optimal conditions and yet be single phase. A formulation has been designed for a particular field application. It uses partially hydrolyzed polyacrylamide for mobility control. The addition of an alkali such as sodium carbonate makes possible in situ generation of naphthenic soap and significant reduction of synthetic surfactant adsorption. The design of the process to maximize the region of ultra-low IFT takes advantage of the observation that the ratio of soap to synthetic surfactant is a parameter in the conditions for optimal salinity. Even for a fixed ratio of soap to surfactant, the range of salinity for low IFT was wider than that reported for surfactant systems in the literature. Low temperature, forced displacement experiments in dolomite and silica sandpacks demonstrate that greater than 95% recovery of the waterflood remaining oil is possible with 0.2% surfactant concentration, 0.5 PV surfactant slug, with no alcohol. Compositional simulation of the displacement process demonstrates the role of soap/surfactant ratio on passage of the profile through the ultralow IFT region, the importance of a wide salinity range of low IFT, and the importance of the viscosity of the surfactant slug. Mobility control is essential for surfactant EOR. Foam is evaluated to improve the sweep efficiency of surfactant injected into fractured reservoirs as well as a drive fluid for ASP flooding. UTCHEM is a reservoir simulator specially designed for surfactant EOR. It has been modified to represent the effects of a change in wettability produced by surfactant injection.

George J. Hirasaki; Clarence A. Miller

2006-09-09T23:59:59.000Z

239

European Conference on the Mathematics of Oil Recovery --Amsterdam, The Netherlands 4 -7 September 2006  

E-Print Network [OSTI]

in Oil Reservoirs F.J. Vermolen* (Delft University of Technology), P.L.J. Zitha (Delft University of Technology) & C. Vuik (Delft University of Technology) SUMMARY Oil reservoirs generally contain several to model single- and multi-phase flow pro- cesses in oil and gas reservoirs, see for instance the work

Vuik, Kees

240

Report on Synchrophasor Technologies and Their Deployment in Recovery Act  

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

Report on Synchrophasor Technologies and Their Deployment in Report on Synchrophasor Technologies and Their Deployment in Recovery Act Projects Now Available Report on Synchrophasor Technologies and Their Deployment in Recovery Act Projects Now Available August 15, 2013 - 10:48am Addthis The Office of Electricity Delivery and Energy Reliability has released a new report that explains synchrophasor technologies and how they can be used to improve the efficiency, reliability, and resiliency of grid operations. The report also includes an analysis of the costs and benefits of synchrophasors, based on data and initial results from Recovery Act-funded projects that are deploying the technologies. The report is available now for downloading. Addthis Related Articles Reports on the Impact of the Smart Grid Investment Grant Program Now

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


241

Faces of the Recovery Act: 1366 Technologies | Department of Energy  

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

1366 Technologies 1366 Technologies Faces of the Recovery Act: 1366 Technologies Addthis Description LEXINGTON, MA - At 1366 Technologies, Ely Sachs and Frank van Mierlo are using ARPA-E Recovery Act funding to dramatically reduce the costs of solar panel production. Speakers President Obama, Ely Sachs, Frank van Mierlo Duration 4:00 Topic Energy Economy Recovery Act Solar ARPA-E Summit Emerging Technologies Credit Energy Department Video PRESIDENT OBAMA: Next we need to encourage American innovation. Last year we made the largest investment in basic research funding in history - (applause) - an investment - an investment that could lead to the world's cheapest solar cells or treatment that kills cancer cells but leaves healthy ones untouched. And no area is more ripe for such

242

Report on Synchrophasor Technologies and Their Deployment in Recovery Act  

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

on Synchrophasor Technologies and Their Deployment in on Synchrophasor Technologies and Their Deployment in Recovery Act Projects Now Available Report on Synchrophasor Technologies and Their Deployment in Recovery Act Projects Now Available August 15, 2013 - 10:48am Addthis The Office of Electricity Delivery and Energy Reliability has released a new report that explains synchrophasor technologies and how they can be used to improve the efficiency, reliability, and resiliency of grid operations. The report also includes an analysis of the costs and benefits of synchrophasors, based on data and initial results from Recovery Act-funded projects that are deploying the technologies. The report is available now for downloading. Addthis Related Articles Reports on the Impact of the Smart Grid Investment Grant Program Now

243

Oil & Natural Gas Technology  

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

May -October, 2009 May -October, 2009 Submitted by: Rice University, University of Texas, and Oklahoma State University George J. Hirasaki and Walter Chapman, Chemical and Biomolecular Engineering Gerald R. Dickens, Colin A. Zelt, and Brandon E. Dugan, Earth Science Kishore K. Mohanty, University of Texas Priyank Jaiswal, Oklahoma State University November, 2009 DOE Award No.: DE-FC26-06NT42960 John Terneus, Program Officer Rice University - MS 362 6100 Main St. Houston, TX 77251-1892 Phone: 713-348-5416; FAX: 713-348-5478; Email: gjh@rice.edu Prepared for: United States Department of Energy National Energy Technology Laboratory Office of Fossil Energy 2 Table of Contents Disclaimer .......................................................................................................... 3

244

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 Joaquin Basin, California. Quarterly report, June 14--September 30, 1995  

SciTech Connect (OSTI)

This project will reactivate ARCO`s idle Pru Fee lease in the Midway-Sunset field, California and conduct a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming will be used to reestablish baseline production within the reservoir characterization phase of the project. During the demonstration phase, a continuous steamflood enhanced oil recover will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class 3 reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program. A summary of technical progress discusses the literature compilation, assembly of digitized log suites, development of a stratigraphic framework, installation of lease production facilities, return wells to production, drill producer and observation wells, and reservoir characterization.

Schamel, S.

1995-12-19T23:59:59.000Z

245

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 Joaquin Basin, California. [Quarterly report], June 14, 1995--September 30, 1995  

SciTech Connect (OSTI)

This project will reactivate ARCO`s idle Pru Fee lease in the Midway-Sunset field, California and conduct a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. Cyclic steaming will be used to re-establish baseline production within the reservoir characterization phase of the project. During the demonstration phase, a continuous steamflood enhanced oil recover will be initiated to test the incremental value of this method as an alternative to cyclic steaming. Other economically marginal Class III reservoirs having similar producibility problems will benefit from insight gained in this project. The objectives of the project are: (1) to return the shut-in portion of the reservoir to commercial production; (2) to accurately describe the reservoir and recovery process; and (3) to convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program. A summary of technical progress covers: geological and reservoir characterization, and reservoir simulation.

Schamel, S.

1996-01-19T23:59:59.000Z

246

Horizontal oil well applications and oil recovery assessment. Volume 2: Applications overview, Final report  

SciTech Connect (OSTI)

Horizontal technology has been applied in over 110 formations in the USA. Volume 1 of this study addresses the overall success of horizontal technology, especially in less-publicized formations, i.e., other than the Austin Chalk, Bakken, and Niobrara. Operators in the USA and Canada were surveyed on a formation-by-formation basis by means of a questionnaire. Response data were received describing horizontal well projects in 58 formations in the USA and 88 in Canada. Operators` responses were analyzed for trends in technical and economic success based on lithology (clastics and carbonates) and resource type (light oil, heavy oil, and gas). The potential impact of horizontal technology on reserves was also estimated. A forecast of horizontal drilling activity over the next decade was developed.

Deskins, W.G.; McDonald, W.J.; Knoll, R.G.; Springer, S.J.

1995-03-01T23:59:59.000Z

247

The effect of asphalt deposition on recovery of oil by a pentane slug  

E-Print Network [OSTI]

THE EFFECT OF ASPHALT DEPOSITION ON RECOVERY OF OIL BY A PENTANE SLUG NANIK S. BHAGIA THE EFFECT OF ASPHALT DEPOSITION ON RECOVERY OF OIL BY A PENTANE SLUG A Thesis By NANIK S. BHAGIA Submitted to the Graduate College of the Texas Ak...M University in partial fulfillment of the requirements for the degree of MASTER OF SCIENCE May, I 965 Major Subject: Petroleum Engineering THE EFFECT OF ASPHALT DEPOSITION ON RECOVERY OF OIL BY A PENTANE SLUG A Thesis By NANIK S. BHAGIA Approved...

Bhagia, Nanik S

1965-01-01T23:59:59.000Z

248

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

SciTech Connect (OSTI)

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.

Scott Hara

2001-06-27T23:59:59.000Z

249

Oil & Natural Gas Projects Exploration and Production Technologies | Open  

Open Energy Info (EERE)

Oil & Natural Gas Projects Exploration and Production Technologies Oil & Natural Gas Projects Exploration and Production Technologies Jump to: navigation, search OpenEI Reference LibraryAdd to library Web Site: Oil & Natural Gas Projects Exploration and Production Technologies Author U.S. Department of Energy Published Publisher Not Provided, Date Not Provided DOI Not Provided Check for DOI availability: http://crossref.org Online Internet link for Oil & Natural Gas Projects Exploration and Production Technologies Citation U.S. Department of Energy. Oil & Natural Gas Projects Exploration and Production Technologies [Internet]. [cited 2013/10/15]. Available from: http://www.netl.doe.gov/technologies/oil-gas/Petroleum/projects/EP/Explor_Tech/P225.htm Retrieved from "http://en.openei.org/w/index.php?title=Oil_%26_Natural_Gas_Projects_Exploration_and_Production_Technologies&oldid=688583

250

Innovative Technology Improves Upgrading Process for Unconventional Oil  

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

Technology Improves Upgrading Process for Unconventional Technology Improves Upgrading Process for Unconventional Oil Resources Innovative Technology Improves Upgrading Process for Unconventional Oil Resources April 9, 2013 - 1:57pm Addthis Washington, DC - An innovative oil-upgrading technology that can increase the economics of unconventional petroleum resources has been developed under a U.S. Department of Energy -funded project. The promising technology, developed by Ceramatec of Salt Lake City, Utah, and managed by the Office of Fossil Energy's National Energy Technology Laboratory, has been licensed to Western Hydrogen of Calgary for upgrading bitumen or heavy oil from Canada. A new company, Field Upgrading (Calgary, Alberta), has been formed dedicated to developing and commercializing the technology. Heavy oil is crude oil that is viscous and requires thermally enhanced oil

251

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 Joaquin basin, California. Quarterly report, January 1--March 31, 1996  

SciTech Connect (OSTI)

This project will reactivate ARCO`s idle Pru Fee lease in the Midway-Sunset field, California and conduct a continuous steamflood enhanced oil recovery demonstration aided by an integration of modern reservoir characterization and simulation methods. The objectives of the project are: (1) to return the shut-in portion of the reservoir to commercial production; (2) to accurately describe the reservoir and recovery process; and (3) convey the details of this activity to the domestic petroleum industry, especially to other producers in California, through an aggressive technology transfer program. The producibility problems initially thought to be responsible for the low recovery in the Pru Fee property are: (a) the shallow dip of the bedding; (b) complex reservoir structure, (c) thinning pay zone; and (d) the presence of bottom water. The project is using tight integration of reservoir characterization and simulation modeling to evaluate the magnitude of and alternative solutions to these problems. Two main activities were brought to completion during the first quarter of 1996: (1) lithologic and petrophysical description of the core taken form the new well Pru 101 near the center of the demonstration site and (2) development of a stratigraphic model for the Pru Fee project area. In addition, the first phase of baseline cyclic steaming of the Pru Fee demonstration site was continued with production tests and formation temperature monitoring.

Schamel, S.

1996-06-28T23:59:59.000Z

252

Mass Transfer Mechanisms during the Solvent Recovery of Heavy Oil.  

E-Print Network [OSTI]

??Canada has the second largest proven oil reserves next to Saudi Arabia which is mostly located in Alberta and Saskatchewan but is unconventional heavy oil… (more)

James, Lesley

2009-01-01T23:59:59.000Z

253

enhanced_oil_recovery | netl.doe.gov  

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

that have unconventional characteristics (such as oil in fractured shales, kerogen in oil shale, or bitumen in tar sands) constitute an enormous potential domestic supply of...

254

Co-optimization of CO? sequestration and enhanced oil recovery and co-optimization of CO? sequestration and methane recovery in geopressured aquifers.  

E-Print Network [OSTI]

??In this study, the co-optimization of carbon dioxide sequestration and enhanced oil recovery and the co-optimization of carbon dioxide sequestration and methane recovery studies were… (more)

Bender, Serdar

2011-01-01T23:59:59.000Z

255

Oil Recovery Enhancement from Fractured, Low Permeability Reservoirs. [Carbonated Water  

DOE R&D Accomplishments [OSTI]

The results of the investigative efforts for this jointly funded DOE-State of Texas research project achieved during the 1990-1991 year may be summarized as follows: Geological Characterization - Detailed maps of the development and hierarchical nature the fracture system exhibited by Austin Chalk outcrops were prepared. The results of these efforts were directly applied to the development of production decline type curves applicable to a dual-fracture-matrix flow system. Analysis of production records obtained from Austin Chalk operators illustrated the utility of these type curves to determine relative fracture/matrix contributions and extent. Well-log response in Austin Chalk wells has been shown to be a reliable indicator of organic maturity. Shear-wave splitting concepts were used to estimate fracture orientations from Vertical Seismic Profile, VSP data. Several programs were written to facilitate analysis of the data. The results of these efforts indicated fractures could be detected with VSP seismic methods. Development of the EOR Imbibition Process - Laboratory displacement as well as Magnetic Resonance Imaging, MRI and Computed Tomography, CT imaging studies have shown the carbonated water-imbibition displacement process significantly accelerates and increases recovery from oil saturated, low permeability rocks. Field Tests - Two operators amenable to conducting a carbonated water flood test on an Austin Chalk well have been identified. Feasibility studies are presently underway.

Poston, S. W.

1991-00-00T23:59:59.000Z

256

Research on oil recovery mechanisms in heavy oil reservoirs. Final report  

SciTech Connect (OSTI)

The Research on Heavy Oil Recovery Mechanisms at Stanford University has been ongoing for the past twenty years. During this span of time, 106 technical reports have been published by the Department of Energy, over 200 technical papers have been presented at meetings of professional societies, and most importantly, over 120 students have performed research as graduate research assistants and are now employed by the oil industry or research institutions. Funding was provided by the Department of Energy and also by a group of oil companies. The support of industry is very important to us, not only from the financial viewpoint, but also from the constant exchange of ideas with technical experts from the companies. Meetings are held yearly with industry representatives and informal exchange of information is constant. Support from industry has been steady since 1980. SUPRI personnel is also active in participating in technical meetings and seminars organized by technical societies and other research organizations. We strongly believe that information exchange is one of the most cost effective way to improve research.

NONE

1996-08-01T23:59:59.000Z

257

Carbon capture and sequestration versus carbon capture utilisation and storage for enhanced oil recovery  

Science Journals Connector (OSTI)

There are 74 integrated carbon capture projects worldwide currently listed by the Global ... oil recovery and those for permanent storage of carbon dioxide in saline aquifers or in depleted ... challenges related...

Bob Harrison; Gioia Falcone

2014-02-01T23:59:59.000Z

258

The evaluation of CO2-based vapour extraction (VAPEX) process for heavy-oil recovery  

Science Journals Connector (OSTI)

Vapor extraction (VAPEX) has been proposed as an alternative for heavy-oil recovery in reservoirs where thermal methods face technical and economic problems. In VAPEX, a pair of horizontal injector-producer we...

Farshid Torabi; Benyamin Yadali Jamaloei…

2012-07-01T23:59:59.000Z

259

Investigation of Multiscale and Multiphase Flow, Transport and Reaction in Heavy Oil Recovery Processes  

SciTech Connect (OSTI)

The emphasis of this work was on investigating the mechanisms and factors that control the recovery of heavy oil with the objective to improve recovery efficiencies. For this purpose the interaction of flow transport and reaction at various scales from the pore network to the field scales were studied. Particular mechanisms to be investigated included the onset of gas flow in foamy oil production and in in-situ steam drive, gravity drainage in steam processes, the development of sustained combustion fronts and the propagation of foams in porous media. Analytical, computational and experimental methods were utilized to advance the state of the art in heavy oil recovery. Successful completion of this research was expected to lead to improvements in the Recovery efficiency of various heavy oil processes.

Yorstos, Yanis C.

2002-03-11T23:59:59.000Z

260

Investigation of Multiscale and Multiphase Flow, Transport and Reaction in Heavy Oil Recovery Process  

SciTech Connect (OSTI)

The emphasis of this work was on investigating the mechanisms and factors that control the recovery of heavy oil, with the objective to improve recovery efficiencies. For this purpose, the interaction of flow, transport and reaction at various scales (from the pore-network to the field scales) were studied. Particular mechanisms investigated included the onset of gas flow in foamy oil production and in in-situ steam drive, gravity drainage in steam process, the development of sustained combustion fronts and the propagation of foams in porous media. Analytical, computational and experimental methods were utilized to advance the state of the art in heavy oil recovery. Successful completion of this research was expected to lead to improvements in the recovery efficiency of various heavy oil processes.

Yortsos, Yanis C.; Akkutlu, Yucel; Amilik, Pouya; Kechagia, Persefoni; Lu, Chuan; Shariati, Maryam; Tsimpanogiannis, Ioannis; Zhan, Lang

2000-01-19T23:59:59.000Z

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


261

Further experimental studies of steam-propane injection to enhance recovery of Morichal oil.  

E-Print Network [OSTI]

??In 1998-1999, experimental research was conducted by Goite at Texas A&M University into steam-propane injection to enhance oil recovery from the Morichal field, Venezuela. Goite's… (more)

Ferguson,Mark Anthony

2012-01-01T23:59:59.000Z

262

A Mechanism of Improved Oil Recovery by Low-Salinity Waterflooding in Sandstone Rock  

E-Print Network [OSTI]

Injection of low-salinity water showed high potentials in improving oil recovery when compared to high-salinity water. However, the optimum water salinity and conditions are uncertain, due to the lack of understanding the mechanisms of fluid...

Nasralla, Ramez

2013-05-02T23:59:59.000Z

263

Experimental studies of steam-propane injection to enhance recovery of an intermediate crude oil.  

E-Print Network [OSTI]

??In the past few years, research has been conducted at Texas A&M University on steam-propane injection to enhance oil recovery from the Morichal field, Venezuela,… (more)

Tinss, Judicael Christopher

2012-01-01T23:59:59.000Z

264

Advanced reservoir characterization for improved oil recovery in a New Mexico Delaware basin project  

SciTech Connect (OSTI)

The Nash Draw Brushy Canyon Pool in Eddy County, New Mexico is a field demonstration site in the Department of Energy Class III program. The basic problem at the Nash Draw Pool is the low recovery typically observed in similar Delaware fields. By comparing a control area using standard infill drilling techniques to a pilot area developed using advanced reservoir characterization methods, the goal of the project is to demonstrate that advanced technology can significantly improve oil recovery. During the first year of the project, four new producing wells were drilled, serving as data acquisition wells. Vertical seismic profiles and a 3-D seismic survey were acquired to assist in interwell correlations and facies prediction. Limited surface access at the Nash Draw Pool, caused by proximity of underground potash mining and surface playa lakes, limits development with conventional drilling. Combinations of vertical and horizontal wells combined with selective completions are being evaluated to optimize production performance. Based on the production response of similar Delaware fields, pressure maintenance is a likely requirement at the Nash Draw Pool. A detailed reservoir model of pilot area was developed, and enhanced recovery options, including waterflooding, lean gas, and carbon dioxide injection, are being evaluated.

Martin, F.D.; Kendall, R.P.; Whitney, E.M. [Dave Martin and Associates, Inc., Socorro, NM (United States)] [and others

1997-08-01T23:59:59.000Z

265

Additional Reserve Recovery Using New Polymer Treatment on High Water Oil Ratio Wells in Alameda Field, Kingman County, Kansas  

SciTech Connect (OSTI)

The Chemical Flooding process, like a polymer treatment, as a tertiary (enhanced) oil recovery process can be a very good solution based on the condition of this field and its low cost compared to the drilling of new wells. It is an improved water flooding method in which high molecular-weight (macro-size molecules) and water-soluble polymers are added to the injection water to improve the mobility ratio by enhancing the viscosity of the water and by reducing permeability in invaded zones during the process. In other words, it can improve the sweep efficiency by reducing the water mobility. This polymer treatment can be performed on the same active oil producer well rather than on an injector well in the existence of strong water drive in the formation. Some parameters must be considered before any polymer job is performed such as: formation temperature, permeability, oil gravity and viscosity, location and formation thickness of the well, amount of remaining recoverable oil, fluid levels, well productivity, water oil ratio (WOR) and existence of water drive. This improved oil recovery technique has been used widely and has significant potential to extend reservoir life by increasing the oil production and decreasing the water cut. This new technology has the greatest potential in reservoirs that are moderately heterogeneous, contain moderately viscous oils, and have adverse water-oil mobility ratios. For example, many wells in Kansas's Arbuckle formation had similar treatments and we have seen very effective results. In addition, there were previous polymer treatments conducted by Texaco in Alameda Field on a number of wells throughout the Viola-Simpson formation in the early 70's. Most of the treatments proved to be very successful.

James Spillane

2005-10-01T23:59:59.000Z

266

Application of computed tomography to enhanced oil recovery studies in naturally fractured reservoirs  

E-Print Network [OSTI]

formations of the Middle East (Dukhan field in Qatar, the Jasjid-I-Sulamain, Kirkuk field and Haft- Kel fields in Iran) was made by Birks . Oil recoveries were mathematically determined as a function of time and saturations, for different fracture lengths...APPLICATION OF COMPUTED TOMOGRAPHY TO ENHANCED OIL RECOVERY STUDIES IN NATURALLY FRACTURED RESERVOIRS A Thesis by JAMES MARK FINEOUT Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment...

Fineout, James Mark

2012-06-07T23:59:59.000Z

267

Simulation study of the effect of hydrodynamic forces on oil recovery  

E-Print Network [OSTI]

SIMULATION STUDY OF THE EFFECT OF HYDRODYNAMIC FORCES ON OIL RECOVERY A Thesis by EDUARDO ALE JANDRO IDROBO HURTADO Submitted to the Office of Graduate Studies of Texas A&M University in partial fulfillment of the requirements for the degree... of MASTER OF SCIENCE December 1992 Major Subject: Petroleum Engineering SIMULATION STUDY OF THE EFFECT OF HYDRODYNAMIC FORCES ON OIL RECOVERY A Thesis by EDUARDO ALE JANDRO IDROBO HURTADO Approved as to style and content by: S, W. Poston (Chair...

Idrobo Hurtado, Eduardo Alejandro

2012-06-07T23:59:59.000Z

268

Effects of fluid properties and initial gas saturation on oil recovery by water flooding  

E-Print Network [OSTI]

EFFECTS OF FLUID PROPERTIES AND INITIAL GAS SATURATION ON OIL RECOVERY BY WATER FLOODING A Thesis By MARION D. ARNOLD Submitted to the Graduate School of the Agricultural and Mechanical College of Texas in partial fulfillment... of the requirements for the degree of MASTER OF SCIENCE August, 1959 Major Subject: Petroleum Engineering EFFECTS OF FLUID PROPERTIES AND INITIAL GAS SATURATION ON OIL RECOVERY BY WATER FLOODING A Thesis By MARION D, ARNOLD Approved as to style and content by...

Arnold, Marion Denson

2012-06-07T23:59:59.000Z

269

Thermoelectric Technology for Automotive Waste Heat Recovery  

Broader source: Energy.gov [DOE]

Presentation given at the 2007 Diesel Engine-Efficiency & Emissions Research Conference (DEER 2007). 13-16 August, 2007, Detroit, Michigan. Sponsored by the U.S. Department of Energy's (DOE) Office of FreedomCAR and Vehicle Technologies (OFCVT).

270

Effect of varying polyacrylamide molecular weight on tertiary oil recovery from porous media of varying permeability  

SciTech Connect (OSTI)

Three different molecular weight emulsion polyacrylamides (PAA) have been tested for their ability to recover oil from a multi-permeability Berea core system. Injection of a 6.5 x 10/sup 6/, 17 x 10/sup 6/, and 36 x 10/sup 6/ molecular weight PAA resulted in oil recovery from the multiple permeability core systems of 53.4, 63.7, and 57.2 percent of the waterflood residual oil, respectively. In tests with 15 g/kg Na/sub 2/CO/sub 3/, injection of the polymer systems resulted in recoveries of 65.6, 75.3, and 68.0 percent of the waterflood residual oil, respectively. In the presence of alkali, the injection of high molecular weight PAA resulted in the reduction of fluid flow into the medium and low permeability cores with 70 to 75 percent of the tertiary oil being recovered from the high permeability core. Decreasing the PAA molecular weight to 17 x 10/sup 6/ and subsequently to 6.5 x 10/sup 6/ resulted in an increasing amount of fluid flowing through the low and medium permeability cores. While decreasing the molecular weight of the PAA resulted in increased fluid diversion, the 6.5 x 10/sup 6/ molecular weight PAA recovery efficiency was less than either of the other two polymers in the high permeability core. The data indicates selection of too large a polymer can result in less than maximum oil recovery from a heterogeneous permeability reservoir as a result of lower sweep efficiency. Selection of too small a polymer can result in less than maximum oil recovery from a heterogeneous permeability reservoir as a result of decreased oil recovery from the high permeability zones. Proper selection of polyacrylamide for a heterogeneous permeability reservoir either in the presence or in the absence of alkali will maximize oil recovery.

Ball, J.T.; Pitts, M.J.

1984-04-01T23:59:59.000Z

271

IMPROVED OIL RECOVERY IN MISSISSIPPIAN CARBONATE RESERVOIRS OF KANSAS - NEAR TERM - CLASS 2  

SciTech Connect (OSTI)

This annual report describes progress during the final year of the project entitled ''Improved Oil Recovery in Mississippian Carbonate Reservoirs in Kansas''. This project funded under the Department of Energy's Class 2 program targets improving the reservoir performance of mature oil fields located in shallow shelf carbonate reservoirs. The focus of the project was development and demonstration of cost-effective reservoir description and management technologies to extend the economic life of mature reservoirs in Kansas and the mid-continent. As part of the project, tools and techniques for reservoir description and management were developed, modified and demonstrated, including PfEFFER spreadsheet log analysis software. The world-wide-web was used to provide rapid and flexible dissemination of the project results through the Internet. A summary of demonstration phase at the Schaben and Ness City North sites demonstrates the effectiveness of the proposed reservoir management strategies and technologies. At the Schaben Field, a total of 22 additional locations were evaluated based on the reservoir characterization and simulation studies and resulted in a significant incremental production increase. At Ness City North Field, a horizontal infill well (Mull Ummel No.4H) was planned and drilled based on the results of reservoir characterization and simulation studies to optimize the location and length. The well produced excellent and predicted oil rates for the first two months. Unexpected presence of vertical shale intervals in the lateral resulted in loss of the hole. While the horizontal well was not economically successful, the technology was demonstrated to have potential to recover significant additional reserves in Kansas and the Midcontinent. Several low-cost approaches were developed to evaluate candidate reservoirs for potential horizontal well applications at the field scale, lease level, and well level, and enable the small independent producer to identify efficiently candidate reservoirs and also to predict the performance of horizontal well applications.

Timothy R. Carr; Don W. Green; G. Paul Willhite

2000-04-30T23:59:59.000Z

272

Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas -- Near term. Quarterly report, June 30--September 30, 1995  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Cherokee Group reservoirs in southeastern Kansas and in Morrow sandstone reservoirs in southwestern Kansas. Two demonstration sites operated by different independent oil operators are involved in the project. General topics to be addressed will be (1) reservoir management and performance evaluation; (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. The reservoir management portion of the project will involve performance evaluation and will include such work as (1) reservoir characterization and the development of a reservoir database, (2) identification of operational problems, (3) identification of near wellbore problems, (4) identification of unrecovered mobile oil and estimation of recovery factors, and (5) identification of the most efficient and economical recovery process. The waterflood optimization portion of the project involves only the Nelson Lease. It will be based on the performance evaluation and will involve (1) design and implementation of a water cleanup system for the waterflood, (2) application of well remedial work such as polymer gel treatments to improve vertical sweep efficiency, and (3) changes in waterflood patterns to increase sweep efficiency. Finally, it is planned to implement an improved recovery process on both field demonstration sites.

Green, D.W.; Willhite, G.P.; Walton, A.; Schoeling, L.; Reynolds, R.; Michnick, M.; Watney, L.

1995-10-15T23:59:59.000Z

273

Shell And Statoil Plan To Use CO For Enhanced Offshore Oil Recovery  

Science Journals Connector (OSTI)

Shell and the Norwegian oil company Statoil have announced the world's first project to use carbon dioxide sequestered from a power plant to boost oil recovery offshore. In the $1.4 billion project, Statoil will build an 860-MW gas-fired power plant and ...

BETTE HILEMAN

2006-03-20T23:59:59.000Z

274

Experimental Study of Steam Surfactant Flood for Enhancing Heavy Oil Recovery After Waterflooding  

E-Print Network [OSTI]

surfactant flow due to the reduced steam override effect as well as reduced interfacial tension between oil and water in the formation. To investigate the ability to improve recovery of 20.5oAPI California heavy oil with steam surfactant injection, several...

Sunnatov, Dinmukhamed

2010-07-14T23:59:59.000Z

275

Experimental studies of steam-propane injection to enhance recovery of an intermediate crude oil  

E-Print Network [OSTI]

In the past few years, research has been conducted at Texas A&M University on steam-propane injection to enhance oil recovery from the Morichal field, Venezuela, which contains 13.5 ?API gravity oil. Experimental results show that a 5:100 propane...

Tinss, Judicael Christopher

2001-01-01T23:59:59.000Z

276

Numerical Simulation of Displacement Mechanisms for Enhancing Heavy Oil Recovery during Alkaline Flooding  

Science Journals Connector (OSTI)

In this paper, a simulation technique has been developed and successfully applied to numerically simulate the experimentally determined displacement mechanisms governing alkaline flooding for enhancing oil recovery in heavy oil reservoirs. ... (8-13) The existing simulation techniques used for alkaline flooding in the conventional oil reservoirs result in significant discrepancy between the experimental and simulated pressure drop for alkaline flooding in heavy oil reservoirs. ... Both the scientific findings and the newly developed simulation technique will facilitate simulating and designing field-scale alkaline flooding for heavy oil reservoirs. ...

Mohamed Arhuoma; Daoyong Yang; Mingzhe Dong; Heng Li; Raphael Idem

2009-10-15T23:59:59.000Z

277

Western states enhanced oil shale recovery program: Shale oil production facilities conceptual design studies report  

SciTech Connect (OSTI)

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.

Not Available

1989-08-01T23:59:59.000Z

278

Vehicle Technologies Office: Fact #336: September 6, 2004 World Oil  

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

6: September 6, 6: September 6, 2004 World Oil Reserves, Production, and Consumption, 2003 to someone by E-mail Share Vehicle Technologies Office: Fact #336: September 6, 2004 World Oil Reserves, Production, and Consumption, 2003 on Facebook Tweet about Vehicle Technologies Office: Fact #336: September 6, 2004 World Oil Reserves, Production, and Consumption, 2003 on Twitter Bookmark Vehicle Technologies Office: Fact #336: September 6, 2004 World Oil Reserves, Production, and Consumption, 2003 on Google Bookmark Vehicle Technologies Office: Fact #336: September 6, 2004 World Oil Reserves, Production, and Consumption, 2003 on Delicious Rank Vehicle Technologies Office: Fact #336: September 6, 2004 World Oil Reserves, Production, and Consumption, 2003 on Digg Find More places to share Vehicle Technologies Office: Fact #336:

279

Vehicle Technologies Office: Fact #487: September 17, 2007 World Oil  

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

7: September 17, 7: September 17, 2007 World Oil Reserves, Production, and Consumption, 2006 to someone by E-mail Share Vehicle Technologies Office: Fact #487: September 17, 2007 World Oil Reserves, Production, and Consumption, 2006 on Facebook Tweet about Vehicle Technologies Office: Fact #487: September 17, 2007 World Oil Reserves, Production, and Consumption, 2006 on Twitter Bookmark Vehicle Technologies Office: Fact #487: September 17, 2007 World Oil Reserves, Production, and Consumption, 2006 on Google Bookmark Vehicle Technologies Office: Fact #487: September 17, 2007 World Oil Reserves, Production, and Consumption, 2006 on Delicious Rank Vehicle Technologies Office: Fact #487: September 17, 2007 World Oil Reserves, Production, and Consumption, 2006 on Digg Find More places to share Vehicle Technologies Office: Fact #487:

280

Electromagnetic Induction Heat Generation of Nano?ferrofluid and Other Stimulants for Heavy Oil Recovery  

Science Journals Connector (OSTI)

Nano?ferrofluid and graphite?fluid are proposed to be used as stimulants for heavy oil recovery processes using electromagnetic induction. The heat generation in the stimulants will be used for reducing the viscosity of heavy oil. The temperature increase of the stimulants are observed with the presence of electromagnetic induction. These increments are better compared to those of the varying concentration of salt water (brine) usually exist in the oil reservoir.

A. A. Pramana; D. Abdassah; S. Rachmat; A. Mikrajuddin

2010-01-01T23:59:59.000Z

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


281

Physica A 266 (1999) 107114 Predicting oil recovery using percolation  

E-Print Network [OSTI]

and the subsequent decay in the production rate of oil at another well. Because we only have a stochastic view) to displace the oil to other wells. Ultimately the injected uid will breakthrough into a production well where it has to be separated from the oil, which is a very costly process. Once the injected uid has broken

Stanley, H. Eugene

282

Modification of chemical and physical factors in steamflood to increase heavy oil recovery  

SciTech Connect (OSTI)

This report covers the work performed in the various physicochemical factors for the improvement of oil recovery efficiency. In this context the following general areas were studied: (1) The understanding of vapor-liquid flows in porous media, including processes in steam injection; (2) The effect of reservoir heterogeneity in a variety of foams, from pore scale to macroscopic scale; (3) The flow properties of additives for improvement of recovery efficiency, particularly foams and other non-Newtonian fluids; and (4) The development of optimization methods to maximize various measures of oil recovery.

Yortsos, Yanis C.

2000-01-19T23:59:59.000Z

283

Analysis of Microscopic Displacement Mechanisms of Alkaline Flooding for Enhanced Heavy-Oil Recovery  

Science Journals Connector (OSTI)

(8, 11, 12) Accordingly, some numerical simulations of alkaline flooding for heavy oil were conducted on the basis of the formation of W/O emulsion. ... The waterflood recovery of low-gravity, viscous crude oils was increased by caustic flooding at ?0.05-0.5 wt.% NaOH [1310-73-2], which increased recovery before water breakthrough and lowered the producing water-oil ratios during the flood. ... In this paper, a simulation technique has been developed and successfully applied to numerically simulate the exptl. ...

Haihua Pei; Guicai Zhang; Jijiang Ge; Luchao Jin; Xiaoling Liu

2011-09-04T23:59:59.000Z

284

Research on viscosity-reduction technology by electric heating and blending light oil in ultra-deep heavy oil wells  

Science Journals Connector (OSTI)

In the Tahe oilfield in China, heavy oil is commonly lifted using the light oil blending technology. However, due to the lack of light oil, the production of heavy oil has been seriously limited. Thus, a new c...

Mo Zhu; Haiquan Zhong; Yingchuan Li…

2014-07-01T23:59:59.000Z

285

Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell  

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

Financial Opportunities Financial Opportunities Printable Version Share this resource Send a link to Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell Market Transformation to someone by E-mail Share Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell Market Transformation on Facebook Tweet about Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell Market Transformation on Twitter Bookmark Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell Market Transformation on Google Bookmark Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell Market Transformation on Delicious Rank Fuel Cell Technologies Office: Recovery Act Projects Funded for Fuel Cell Market Transformation on Digg

286

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 (OSTI)

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.

Steven Schamel

1998-03-20T23:59:59.000Z

287

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 (OSTI)

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.

Steven Schamel

1998-08-31T23:59:59.000Z

288

Enhanced oil recovery. Progress review, October--December 1993  

SciTech Connect (OSTI)

This document details current research in the area of enhanced recovery of petroleum as sponsored by the DOE. Progress reports are provided for over thirty projects.

Not Available

1993-12-31T23:59:59.000Z

289

Comparison of Conventional and Catalytic in Situ Combustion Processes for Oil Recovery  

Science Journals Connector (OSTI)

Although combustion and oxidation processes for oil recovery have traditionally been associated with heavy oil, it has been demonstrated recently that air injection into light oil reservoirs can provide good recoveries,(10, 11) while Al -Saffar et al.(12) have shown that the separation of a light oil fractions into individual SARA fractions followed by combustion can provide useful information on this light oil oxidation process. ... The system consists of the following interrelated parts: combustion cell, flow metering and pressure regulation units, temperature measurement and control, fluid production unit, and gas analysis unit. ... The combustion processes were very similar because the sample beds in all experiments were identical and the same processing parameters were used. ...

Musa B. Abuhesa; R. Hughes

2008-12-08T23:59:59.000Z

290

Surfactant-Polymer Interaction for Improved Oil Recovery  

SciTech Connect (OSTI)

The goal of this research was to use the interaction between a surfactant and a polymer for efficient displacement of tertiary oil by improving slug integrity, oil solubility in the displacing fluid and mobility control. Surfactant-polymer flooding has been shown to be highly effective in laboratory-scale linear floods. The focus of this proposal is to design an inexpensive surfactant-polymer mixture that can efficiently recover tertiary oil by avoiding surfactant slug degradation and viscous/heterogeneity fingering.

Gabitto, Jorge; Mohanty, Kishore K.

2002-01-07T23:59:59.000Z

291

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

SciTech Connect (OSTI)

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 novel alkaline-steam well completion technique for the containment of the unconsolidated formation sands and control of fluid entry and injection profiles. (5) Installation of a 2100 ft, 14 inch insulated, steam line beneath a harbor channel to supply steam to an island location. (6) Testing and proposed application of thermal recovery technologies to increase oil production and reserves: (a) Performing pilot tests of cyclic steam injection and production on new horizontal wells. (b) Performing pilot tests of hot water-alternating-steam (WAS) drive in the existing steam drive area to improve thermal efficiency. (7) Perform a pilot steamflood with the four horizontal injectors and producers using a pseudo steam-assisted gravity-drainage (SAGD) process. (8) Advanced reservoir management, through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring and evaluation.

Unknown

2001-08-08T23:59:59.000Z

292

DEVELOPMENT AND OPTIMIZATION OF GAS-ASSISTED GRAVITY DRAINAGE (GAGD) PROCESS FOR IMPROVED LIGHT OIL RECOVERY  

SciTech Connect (OSTI)

This report describes the progress of the project ''Development and Optimization of Gas-Assisted Gravity Drainage (GAGD) Process for Improved Light Oil Recovery'' for the duration of the second project year (October 1, 2003--September 30, 2004). There are three main tasks in this research project. Task 1 is scaled physical model study of GAGD process. Task 2 is further development of vanishing interfacial tension (VIT) technique for miscibility determination. Task 3 is determination of multiphase displacement characteristics in reservoir rocks. In Section I, preliminary design of the scaled physical model using the dimensional similarity approach has been presented. Scaled experiments on the current physical model have been designed to investigate the effect of Bond and capillary numbers on GAGD oil recovery. Experimental plan to study the effect of spreading coefficient and reservoir heterogeneity has been presented. Results from the GAGD experiments to study the effect of operating mode, Bond number and capillary number on GAGD oil recovery have been reported. These experiments suggest that the type of the gas does not affect the performance of GAGD in immiscible mode. The cumulative oil recovery has been observed to vary exponentially with Bond and capillary numbers, for the experiments presented in this report. A predictive model using the bundle of capillary tube approach has been developed to predict the performance of free gravity drainage process. In Section II, a mechanistic Parachor model has been proposed for improved prediction of IFT as well as to characterize the mass transfer effects for miscibility development in reservoir crude oil-solvent systems. Sensitivity studies on model results indicate that provision of a single IFT measurement in the proposed model is sufficient for reasonable IFT predictions. An attempt has been made to correlate the exponent (n) in the mechanistic model with normalized solute compositions present in both fluid phases. IFT measurements were carried out in a standard ternary liquid system of benzene, ethanol and water using drop shape analysis and capillary rise techniques. The experimental results indicate strong correlation among the three thermodynamic properties solubility, miscibility and IFT. The miscibility determined from IFT measurements for this ternary liquid system is in good agreement with phase diagram and solubility data, which clearly indicates the sound conceptual basis of VIT technique to determine fluid-fluid miscibility. Model fluid systems have been identified for VIT experimentation at elevated pressures and temperatures. Section III comprises of the experimental study aimed at evaluating the multiphase displacement characteristics of the various gas injection EOR process performances using Berea sandstone cores. During this reporting period, extensive literature review was completed to: (1) study the gravity drainage concepts, (2) identify the various factors influencing gravity stable gas injection processes, (3) identify various multiphase mechanisms and fluid dynamics operative during the GAGD process, and (4) identify important dimensionless groups governing the GAGD process performance. Furthermore, the dimensional analysis of the GAGD process, using Buckingham-Pi theorem to isolate the various dimensionless groups, as well as experimental design based on these dimensionless quantities have been completed in this reporting period. On the experimental front, recommendations from previous WAG and CGI have been used to modify the experimental protocol. This report also includes results from scaled preliminary GAGD displacements as well as the details of the planned GAGD corefloods for the next quarter. The technology transfer activities have mainly consisted of preparing technical papers, progress reports and discussions with industry personnel for possible GAGD field tests.

Dandina N. Rao; Subhash C. Ayirala; Madhav M. Kulkarni; Amit P. Sharma

2004-10-01T23:59:59.000Z

293

Thermo economic evaluation of oxy fuel combustion cycle in Kazeroon power plant considering enhanced oil recovery revenues  

Science Journals Connector (OSTI)

Oxy fuel combustion and conventional cycle (currently working cycle ... for enhanced oil recovery in the various oil price indices is conducted and indices net present ... models reveal that gross efficiency of t...

Ehsan Torabnejad; Ramin Haghighi-Khoshkhoo…

2014-03-01T23:59:59.000Z

294

Economic evaluation of mine assisted oil recovery using a reservoir simulator  

E-Print Network [OSTI]

W1th the r1s ing costs of explorat1on and the declining domestic oil supply, the potential of the Mine Assisted Oil Recovery (MAOR) process is too great to ignore. With the add1t1onal supply of oil obtained from m1ning, the US could substantially... continues but the economics of the process is uncertain. The United States Department of Energy recently funded a study by Stone f Webster Eng1neering Corporation(4) entitled, "An Evaluation of Heavy Oil M1ning. " This study involved a site specific...

Fontaine, Russell Charles

2012-06-07T23:59:59.000Z

295

Gasflooding-assisted cyclic solvent injection (GA-CSI) for enhancing heavy oil recovery  

Science Journals Connector (OSTI)

Abstract Cyclic solvent injection (CSI) process has showed great potential to enhance heavy oil recovery because it takes advantages of solution-gas drive and foamy oil flow for oil production. However, CSI suffers from solvent release during the production period so that the viscosity of the solvent-diluted heavy oil is re-increased and its mobility is re-decreased. How to effectively recover the solvent-diluted heavy oil becomes a key technical challenge in a CSI process. This paper first experimentally analyzed a conventional CSI process that used a solvent injector as an oil producer alternately. It is found that foamy oil was induced and flowed to the producer during the production period of a cycle but some foamy oil was pushed back by solvent during the solvent injection period of the following cycle. Such “back-and-forth” movement of foamy oil seriously hindered the productivity of the CSI process. On the basis of this knowledge, this study proposed a new process, gasflooding-assisted cyclic solvent injection (GA-CSI), to enhance the performance of CSI. In a GA-CSI process, the solvent injector and the oil producer were placed horizontally apart. An additional solvent gasflooding process was applied immediately after the pressure drawdown process to produce the foamy oil that lost its mobility due to solvent release. The experimental results showed that the oil production rate of the newly proposed GA-CSI process is 3?4 times of that for a conventional CSI process.

Xinfeng Jia; Fanhua Zeng; Yongan Gu

2015-01-01T23:59:59.000Z

296

Innovative Technology Improves Upgrading Process for Unconventional Oil  

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

Innovative Technology Improves Upgrading Process for Unconventional Innovative Technology Improves Upgrading Process for Unconventional Oil Resources Innovative Technology Improves Upgrading Process for Unconventional Oil Resources April 9, 2013 - 1:57pm Addthis Washington, DC - An innovative oil-upgrading technology that can increase the economics of unconventional petroleum resources has been developed under a U.S. Department of Energy -funded project. The promising technology, developed by Ceramatec of Salt Lake City, Utah, and managed by the Office of Fossil Energy's National Energy Technology Laboratory, has been licensed to Western Hydrogen of Calgary for upgrading bitumen or heavy oil from Canada. A new company, Field Upgrading (Calgary, Alberta), has been formed dedicated to developing and commercializing the technology.

297

Performance evaluation of starch based polymer for enhanced oil recovery  

E-Print Network [OSTI]

for Elgin-56 sandstone before and after a 1. 0% polymer treatment. 27 3. 6 Fractional flow curve of water for Okesa-23 sandstone before and after a 1. 0% polymer treannent. 28 3. 7 Oil production rate vs. time for edge water influx grid systems with P... = 1. 5, 2. 0, and 3. 0. 34 Cumulative oil production vs. time for edge water influx grid systems with P = 1. 5, 2. 0, and 3. 0. 35 3. 9 Bottomhole pressure vs. time for edge water influx grid systems with P = 1. 5, 2. 0, and 3. 0. 35 3. 10 Oil...

Skurner, James Andrew

2012-06-07T23:59:59.000Z

298

Assessment of opportunities to increase the recovery and recycling rates of waste oils  

SciTech Connect (OSTI)

Waste oil represents an important energy resource that, if properly managed and reused, would reduce US dependence on imported fuels. Literature and current practice regarding waste oil generation, regulations, collection, and reuse were reviewed to identify research needs and approaches to increase the recovery and recycling of this resource. The review revealed the need for research to address the following three waste oil challenges: (1) recover and recycle waste oil that is currently disposed of or misused; (2) identify and implement lubricating oil source and loss reduction opportunities; and (3) develop and foster an effective waste oil recycling infrastructure that is based on energy savings, reduced environment at impacts, and competitive economics. The United States could save an estimated 140 {times} 1012 Btu/yr in energy by meeting these challenges.

Graziano, D.J.; Daniels, E.J.

1995-08-01T23:59:59.000Z

299

Gas-assisted gravity drainage (GAGD) process for improved oil recovery  

DOE Patents [OSTI]

A rapid and inexpensive process for increasing the amount of hydrocarbons (e.g., oil) produced and the rate of production from subterranean hydrocarbon-bearing reservoirs by displacing oil downwards within the oil reservoir and into an oil recovery apparatus is disclosed. The process is referred to as "gas-assisted gravity drainage" and comprises the steps of placing one or more horizontal producer wells near the bottom of a payzone (i.e., rock in which oil and gas are found in exploitable quantities) of a subterranean hydrocarbon-bearing reservoir and injecting a fluid displacer (e.g., CO.sub.2) through one or more vertical wells or horizontal wells. Pre-existing vertical wells may be used to inject the fluid displacer into the reservoir. As the fluid displacer is injected into the top portion of the reservoir, it forms a gas zone, which displaces oil and water downward towards the horizontal producer well(s).

Rao, Dandina N. (Baton Rouge, LA)

2012-07-10T23:59:59.000Z

300

NETL: Oil & Natural Gas Technologies Reference Shelf  

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

NETL Oil & Natural Gas Technologies Reference Shelf NETL Oil & Natural Gas Technologies Reference Shelf E&P Focus Newsletter Banner The oil and gas exploration and production R&D newsletter, E&P Focus, highlights the latest developments in R&D being carried out by NETL. E&P Focus promotes the widespread dissemination of research results among all types of oil and gas industry stakeholders: producers, researchers, educators, regulators, and policymakers. Each issue provides up-to-date information regarding extramural projects managed under the Strategic Center for Natural Gas and OilÂ’s traditional oil and gas program, the EPAct Section 999 Program administered by the Research Partnership to Secure Energy for America (RPSEA), and in-house oil and gas research carried out by NETLÂ’s Office of Research and Development.

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


301

The recovery of crude oil spilled on a ground water aquifer  

E-Print Network [OSTI]

had to be operated manually. After 9 months, the total volume of oil recovered was about 45, 000 gallons, at an average cost of $2. 50 per gallon. The success of the recovery operation was good, but an effort to establish an operation that could... had to be operated manually. After 9 months, the total volume of oil recovered was about 45, 000 gallons, at an average cost of $2. 50 per gallon. The success of the recovery operation was good, but an effort to establish an operation that could...

Malter, Paul Lawrence

2012-06-07T23:59:59.000Z

302

Reducing Carbon Dioxide Emissions with Enhanced Oil Recovery Projects:? A Life Cycle Assessment Approach  

Science Journals Connector (OSTI)

Reducing Carbon Dioxide Emissions with Enhanced Oil Recovery Projects:? A Life Cycle Assessment Approach ... This capacity corresponds approximately to storing the emissions of a 5 MW power plant emitting 65 tons of CO2 per day for almost 1800 years27 or 14 years from a 300 MW coal power plant where 8000 tons of CO2 is captured per day. ... To overcome this CO2 emission problem, there is great interest, esp. in Canada, to capture carbon dioxide and utilize it as a flooding agent for the enhanced oil recovery (EOR) process. ...

Anne-Christine Aycaguer; Miriam Lev-On; Arthur M. Winer

2001-03-01T23:59:59.000Z

303

DEVELOPMENT AND OPTIMIZATION OF GAS-ASSISTED GRAVITY DRAINAGE (GAGD) PROCESS FOR IMPROVED LIGHT OIL RECOVERY  

SciTech Connect (OSTI)

This report describes the progress of the project ''Development And Optimization of Gas-Assisted Gravity Drainage (GAGD) Process for Improved Light Oil Recovery'' for the duration of the thirteenth project quarter (Oct 1, 2005 to Dec 30, 2005). There are three main tasks in this research project. Task 1 is a scaled physical model study of the GAGD process. Task 2 is further development of a vanishing interfacial tension (VIT) technique for miscibility determination. Task 3 is determination of multiphase displacement characteristics in reservoir rocks. Section I reports experimental work designed to investigate wettability effects of porous medium, on secondary and tertiary mode GAGD performance. The experiments showed a significant improvement of oil recovery in the oil-wet experiments versus the water-wet runs, both in secondary as well as tertiary mode. When comparing experiments conducted in secondary mode to those run in tertiary mode an improvement in oil recovery was also evident. Additionally, this section summarizes progress made with regard to the scaled physical model construction and experimentation. The purpose of building a scaled physical model, which attempts to include various multiphase mechanics and fluid dynamic parameters operational in the field scale, was to incorporate visual verification of the gas front for viscous instabilities, capillary fingering, and stable displacement. Preliminary experimentation suggested that construction of the 2-D model from sintered glass beads was a feasible alternative. During this reporting quarter, several sintered glass mini-models were prepared and some preliminary experiments designed to visualize gas bubble development were completed. In Section II, the gas-oil interfacial tensions measured in decane-CO{sub 2} system at 100 F and live decane consisting of 25 mole% methane, 30 mole% n-butane and 45 mole% n-decane against CO{sub 2} gas at 160 F have been modeled using the Parachor and newly proposed mechanistic Parachor models. In the decane-CO{sub 2} binary system, Parachor model was found to be sufficient for interfacial tension calculations. The predicted miscibility from the Parachor model deviated only by about 2.5% from the measured VIT miscibility. However, in multicomponent live decane-CO{sub 2} system, the performance of the Parachor model was poor, while good match of interfacial tension predictions has been obtained experimentally using the proposed mechanistic Parachor model. The predicted miscibility from the mechanistic Parachor model accurately matched with the measured VIT miscibility in live decane-CO2 system, which indicates the suitability of this model to predict miscibility in complex multicomponent hydrocarbon systems. In the previous reports to the DOE (15323R07, Oct 2004; 15323R08, Jan 2005; 15323R09, Apr 2005; 15323R10, July 2005 and 154323, Oct 2005), the 1-D experimental results from dimensionally scaled GAGD and WAG corefloods were reported for Section III. Additionally, since Section I reports the experimental results from 2-D physical model experiments; this section attempts to extend this 2-D GAGD study to 3-D (4-phase) flow through porous media and evaluate the performance of these processes using reservoir simulation. Section IV includes the technology transfer efforts undertaken during the quarter. This research work resulted in one international paper presentation in Tulsa, OK; one journal publication; three pending abstracts for SCA 2006 Annual Conference and an invitation to present at the Independents Day session at the IOR Symposium 2006.

Dandina N. Rao; Subhash C. Ayirala; Madhav M. Kulkarni; Thaer N.N. Mahmoud; Wagirin Ruiz Paidin

2006-01-01T23:59:59.000Z

304

Acoustic Energy: An Innovative Technology for Stimulating Oil Wells  

SciTech Connect (OSTI)

The objective of this investigation was to demonstrate the effectiveness of sonication in reducing the viscosity of heavy crude oils. Sonication is the use of acoustic or sound energy to produce physical and/or chemical changes in materials, usually fluids. The goal of the first project phase was to demonstrate a proof of concept for the project objective. Batch tests of three commercially available, single-weight oils (30-, 90-, and 120-wt) were performed in the laboratory. Several observations and conclusions were made from this series of experiments. These include the following: (1) In general, the lower the acoustic frequency, the greater the efficiency in reducing the viscosity of the oils; (2) Sonication treatment of the three oils resulted in reductions in viscosity that ranged from a low of 31% to a high of 75%; and (3) The results of the first phase of the project successfully demonstrated that sonication could reduce the viscosity of oils of differing viscosity. The goal of the second project phase was to demonstrate the ability of sonication to reduce the viscosity of three crude oils ranging from a light crude to a heavy crude. The experiments also were designed to examine the benefits of two proprietary chemical additives used in conjunction with sonication. Acoustic frequencies ranging from 800 Hz to 1.6 kHz were used in these tests, and a reactor chamber was designed for flow-through operation with a capacity of one gallon (3.8 liters). The three crude oils selected for use in the testing program were: (1) a heavy crude from California with a viscosity of approximately 65,000 cP (API gravity about 12{sup o}), (2) a crude from Alabama with a significant water content and a viscosity of approximately 6,000 cP (API gravity about 22 {sup o}), and (3) a light crude from the Middle East with a viscosity of approximately 700 cP (API gravity about 32{sup o}). The principal conclusions derived from the second project phase include the following: (1) The application of acoustic energy (sonication) significantly reduced the viscosity of crude oils, and the amount of viscosity reduction resulting is greater for more viscous, heavy crude oils than it is for less viscous, light crude oils. (2) Test results showed that after being heated, resulting viscosity reductions were not sustained following treatment to the extent that post-sonication reductions were sustained. (3) The maximum viscosity reductions in Oils 1, 2, and 3 due to sonication were 43%, 76%, and 6%, respectively. Samples of Oil 2 associated with larger viscosity reductions often exhibited a definite water separation layer follow the tests, whereas reductions of approximately 23% were measured when this separation was not observed. (4) It was observed that neither horn design nor the reduction of input power by 25% had very little effect on the ability of sonication to alter crude oil viscosity. (5) The chemical additives produced a range of viscosity reduction from 37% to a maximum of 94% with the largest reductions being facilitated by the abundant water present Oil 2. If the Oil 2 results are not considered, the maximum reduction was 73%. The effects of the additives and sonication are enhanced by each other. (6) In only one test did the viscosity return to as much as 50% of the pre-treatment value during a period of 30 days following treatment; recovery was much less in all other cases. Therefore, more than half of the viscosity reduction was maintained for a month without additional treatment. (7) Possible applications, market potential, and economic value of the implementation of a mature sonication technology within the petroleum industry were identified, and it was estimated that the potential exists that more than a billion barrels of oil could be upgraded or produced annually as a result. The project results successfully demonstrated that sonication alone and in combination with chemical additives can effectively reduce the viscosity of crude oils having a broad range of viscosity/API gravity values. Several recommendations are made for follow-on

Edgar, Dorland E.; Peters, Robert W.; Johnson, Donald O.; Paulsen, P. David; Roberts, Wayne

2006-04-30T23:59:59.000Z

305

Nuclear Technology & Canadian Oil Sands: Integration of Nuclear Power with In-Situ Oil Extraction  

E-Print Network [OSTI]

Nuclear Technology & Canadian Oil Sands: Integration of Nuclear Power with In-Situ Oil Extraction A.E. FINAN, K. MIU, A.C. KADAK Massachusetts Institute of Technology Department of Nuclear Science the technical aspects and the economics of utilizing nuclear reactors to provide the energy needed

306

Annex III-evaluation of past and ongoing enhanced oil recovery projects  

SciTech Connect (OSTI)

The Infill Drilling Predictive Model (IDPM) was developed by Scientific Software-Intercomp (SSI) for the Bartlesville Project Office (BPO) of the United States Department of Energy (DOE). The model and certain adaptations thereof were used in conjunction with other models to support the Interstate Oil and Gas Compact Commission`s (IOGCC) 1993 state-by-state assessment of the potential domestic reserves achievable through the application of Advanced Secondary Recovery (ASR) and Enhanced Oil Recovery (EOR) techniques. Funding for this study was provided by the DOE/BPO, which additionally provided technical support. The IDPM is a three-dimensional (stratified, five-spot), two-phase (oil and water) model which uses a minimal amount of reservoir and geologic data to generate production and recovery forecasts for ongoing waterflood and infill drilling projects. The model computes water-oil displacement and oil recovery using finite difference solutions within streamtubes. It calculates the streamtube geometries and uses a two-dimensional reservoir simulation to track fluid movement in each streamtube slice. Thus the model represents a hybrid of streamtube and numerical simulators.

Not Available

1995-02-01T23:59:59.000Z

307

Assessment of Long-Term Research Needs for Shale-Oil Recovery (FERWG-III)  

SciTech Connect (OSTI)

The Fossil Energy Research Working Group (FERWG), at the request of E. Frieman (Director, Office of Energy Research) and G. Fumich, Jr. (Assistant Secretary for Fossil Fuels), has reviewed and evaluated the U.S. programs on shale-oil recovery. These studies were performed in order to provide an independent assessment of critical research areas that affect the long-term prospects for shale-oil availability. This report summarizes the findings and research recommendations of FERWG.

Penner, S.S.

1981-03-01T23:59:59.000Z

308

Modification of reservoir chemical and physical factors in steamfloods to increase heavy oil recovery  

SciTech Connect (OSTI)

Thermal methods, and particularly steam injection, are currently recognized as the most promising for the efficient recovery of heavy oil. Despite significant progress, however, important technical issues remain open. Specifically, still inadequate is our knowledge of the complex interaction between porous media and the various fluids of thermal recovery (steam, water, heavy oil, gases, and chemicals). While, the interplay of heat transfer and fluid flow with pore- and macro-scale heterogeneity is largely unexplored. The objectives of this contract are to continue previous work and to carry out new fundamental studies in the following areas of interest to thermal recovery: displacement and flow properties of fluids involving phase change (condensation-evaporation) in porous media; flow properties of mobility control fluids (such as foam); and the effect of reservoir heterogeneity on thermal recovery. The specific projects are motivated by and address the need to improve heavy oil recovery from typical reservoirs as well as less conventional fractured reservoirs producing from vertical or horizontal wells. During this past quarter, work continued on: the development of relative permeabilities during steam displacement; the optimization of recovery processes in heterogeneous reservoirs by using optical control methods; and in the area of chemical additives, work continued on the behavior of non-Newtonian fluid flow and on foam displacements in porous media.

Yortsos, Y.C.

1996-12-31T23:59:59.000Z

309

Modification of reservoir chemical and physical factors in steamfloods to increase heavy oil recovery  

SciTech Connect (OSTI)

Thermal methods, and particularly steam injection, are currently recognized as the most promising for the efficient recovery of heavy oil. Despite significant progress, however, important technical issues remain open. Specifically, still inadequate is our knowledge of the complex interaction between porous media and the various fluids of thermal recovery (steam, water, heavy oil, gases, and chemicals). While, the interplay of heat transfer and fluid flow with pore- and macro-scale heterogeneity is largely unexplored. The objectives of this contract are to continue previous work and to carry out new fundamental studies in the following areas of interest to thermal recovery: displacement and flow properties of fluids involving phase change (condensation-evaporation) in porous media; flow properties of mobility control fluids (such as foam); and the effect of reservoir heterogeneity on thermal recovery. The specific projects are motivated by and address the need to improve heavy oil recovery from typical reservoirs as well as less conventional fractured reservoirs producing from vertical or horizontal wells. During this quarter work continued on: development of relative permeabilities during steam injection; optimization of recovery processes in heterogeneous reservoirs by using optimal control methods; and behavior of non-Newtonian fluid flow and on foam displacements in porous media.

NONE

1996-12-31T23:59:59.000Z

310

Oil shale, tar sand, coal research, advanced exploratory process technology, jointly sponsored research  

SciTech Connect (OSTI)

Progress made in five research programs is described. The subtasks in oil shale study include oil shale process studies and unconventional applications and markets for western oil shale.The tar sand study is on recycle oil pyrolysis and extraction (ROPE) process. Four tasks are described in coal research: underground coal gasification; coal combustion; integrated coal processing concepts; and sold waste management. Advanced exploratory process technology includes: advanced process concepts; advanced mitigation concepts; and oil and gas technology. Jointly sponsored research covers: organic and inorganic hazardous waste stabilization; CROW field demonstration with Bell Lumber and Pole; development and validation of a standard test method for sequential batch extraction fluid; PGI demonstration project; operation and evaluation of the CO[sub 2] HUFF-N-PUFF process; fly ash binder for unsurfaced road aggregates; solid state NMR analysis of Mesaverde group, Greater Green River Basin, tight gas sands; flow-loop testing of double-wall pipe for thermal applications; shallow oil production using horizontal wells with enhanced oil recovery techniques; NMR analysis of sample from the ocean drilling program; and menu driven access to the WDEQ hydrologic data management system.

Not Available

1992-01-01T23:59:59.000Z

311

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

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; (7) Mobility control agents.

Unknown

2003-01-15T23:59:59.000Z

312

Visual display of reservoir parameters affecting enhanced oil recovery. Final report, September 29, 1993--September 28, 1996  

SciTech Connect (OSTI)

The Pioneer Anticline, 25 miles southwest of Bakersfield, California, which has yielded oil since 1926, was the subject of a three-year study aimed at recovering more oil. A team from Michigan Technological University of Houghton, Michigan (MTU), and Digital Petrophysics, Inc. of Bakersfield, California (DPI), undertook the study as part of the Department of Energy`s Advanced Extraction and Process Technology Program. The program provides support for projects which cross-cut geoscience and engineering research in order to develop innovative technologies for increasing the recovery of some of the estimated 340 billion barrels of in-place oil remaining in U.S. reservoirs. In recent years, low prices and declining production have increased the likelihood that oil fields will be prematurely abandoned, locking away large volumes of unrecovered oil. The major companies have sold many of their fields to smaller operators in an attempt to concentrate their efforts on fewer {open_quotes}core{close_quotes} properties and on overseas exploration. As a result, small companies with fewer resources at their disposal are becoming responsible for an ever-increasing share of U.S. production. The goal of the MTU-DPI project was to make small independent producers who are inheriting old fields from the majors aware that high technology computer software is now available at relatively low cost. In this project, a suite of relatively inexpensive, PC-based software packages, including a commercial database, a multimedia presentation manager, several well-log analysis program, a mapping and cross-section program, and 2-D and 3-D visualization programs, were tested and evaluated on Pioneer Anticline in the southern San Joaquin Valley of California. These relatively inexpensive, commercially available PC-based programs can be assembled into a compatible package for a fraction of the cost of a workstation program with similar capabilities.

Wood, J.R.

1997-05-01T23:59:59.000Z

313

Oil shale technology and evironmental aspects  

SciTech Connect (OSTI)

Oil shale processes are a combination of mining, retorting, and upgrading facilities. This work outlines the processing steps and some design considerations required in an oil shale facility. A brief overview of above ground and in situ retorts is presented; 6 retorts are described. The development aspects which the oil shale industry is addressing to protect the environment are presented.

Scinta, J.

1982-01-01T23:59:59.000Z

314

CHAPTER 45 - STIMULATING RECOVERY FROM HEAVY OIL RESOURCES--MID-CONTINENT AREA  

Science Journals Connector (OSTI)

Publisher Summary This chapter discusses stimulating recovery from heavy oil resources, mid-continent area. In western Missouri, eastern Kansas, and northeastern Oklahoma, heavy-oil deposits occur over an area of roughly 8,000 mi2 and extend for about 250 mi along the Kansas-Missouri border reaching a width of about 80 miles. Heavy-oil deposits are found throughout the region, although lighter oil deposits do occur. Oil saturation and viscosity vary from one reservoir to another and from one depth to another in the same well. The formations of prime interest are the Wayside, Bartlesville, and the Burgess. A research project at the Bartlesville Energy Research Center of ERDA combines modern chemical explosive fracturing techniques with heat and solvent treatment to extract the crude oil. It is found that of primary concern are the heavy-oil reservoirs, which contain low gravity crude oil that cannot be produced by conventional means and reservoirs that have no reservoir energy and consequently have produced no oil. The oil neither flows into the wellbore at an economic rate nor can it simply be pushed to the production well by the injection of water, as in waterflooding.

Larman J. Heath

1977-01-01T23:59:59.000Z

315

Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas - near-term. Quarterly report, April 1 - June 30, 1996  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Morrow sandstone reservoirs in southwestern Kansas and Cherokee Group reservoirs in southeastern Kansas. Two demonstration sites, Stewart Field, and Savonburg Field, operated by different independent oil operators are involved in this project. General topics to be addressed are: (1) reservoir management and performance evaluation; (2) waterflood optimization; and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. For the Stewart Field project, work is summarized for the last quarter on waterflood operations and reservoir management. For the Savonburg Field project, work on water plant development, and pattern changes and wellbore cleanup are briefly described.

Green, D.W.; Willhite, G.P.; Walton, A.; Schoeling, L.; Reynolds, R.; Michnick, M.; Watney, L.

1996-07-01T23:59:59.000Z

316

Feasibility of heavy oil recovery in the U.S. midcontinent (Kansas, Missouri, Oklahoma)  

SciTech Connect (OSTI)

The Midcontinent of the United States (Kansas, Missouri, Oklahoma) has three heavy oil resource areas: the carbonates of central and western Kansas, the Pennsylvanian Age consolidated sandstone reservoirs of the Tristate Heavy Oil Belt (southeastern Kansas, western Missouri, and northeast Oklahoma), and the unconsolidated or easily friable sand- stone reservoirs of south-central Oklahoma. The heavy oil resource volume of the carbonates is unknown and relatively untested because of the difficulty in producing viscous oil from low-permeability carbonates. Since the 1960s, the Tristate Heavy Oil Belt has been the site of numerous pilots and operations that tested many different techniques for oil production. The region was a proving ground for many thermal enhanced oil recovery projects (steam, cyclic steam, in situ combustion, hot solvent injection, etc.). Most of the projects produced more oil than primary production, but the geology of the formations limited significant economic oil production. The best opportunity for significant, economic heavy oil production is from the steeply dipping, unconsolidated or easily friable sandstone reservoirs of south-central Oklahoma. Several of these reservoirs are thicker, more continuous, have high permeability and can be exploited by using gravity drainage and steam to reduce oil viscosity. The Midcontinent is not anticipated to become a significant heavy oil producer even if oil prices were significantly higher than $151 barrel because of the nature of the resource and the limited refining capability in the area. Local refineries were designed to process light sweet crude and have little heavy ends processing capability to accommodate additional heavy oil.

Olsen, D.K.; Johnson, W.I. [BDM-Oklahoma, Inc., Bartlesville, OK (United States)

1995-12-31T23:59:59.000Z

317

A study of the effects of enhanced oil recovery agents on the quality of Strategic Petroleum Reserves crude oil. [Physical and chemical interactions of Enhanced Oil Recovery reagents with hydrocarbons present in petroleum  

SciTech Connect (OSTI)

The project was initiated on September 1, 1990. The objective of the project was to carry out a literature search to estimate the types and extents of long time interactions of enhanced oil recovery (EOR) agents, such as surfactants, caustics and polymers, with crude oil. This information is necessary to make recommendations about mixing EOR crude oil with crude oils from primary and secondary recovery processes in the Strategic Petroleum Reserve (SPR). Data were sought on both adverse and beneficial effects of EOR agents that would impact handling, transportation and refining of crude oil. An extensive literature search has been completed, and the following informations has been compiled: (1) a listing of existing EOR test and field projects; (2) a listing of currently used EOR agents; and (3) evidence of short and long term physical and chemical interactions of these EOR-agents with hydrocarbons, and their effects on the quality of crude oil at long times. This information is presented in this report. Finally some conclusions are derived and recommendations are made. Although the conclusions are based mostly on extrapolations because of lack of specific data, it is recommended that the enhancement of the rates of biodegradation of oil catalyzed by the EOR agents needs to be further studied. There is no evidence of substantial long term effects on crude oil because of other interactions. Some recommendations are also made regarding the types of studies that would be necessary to determine the effect of certain EOR agents on the rates of biodegradation of crude oil.

Kabadi, V.N.

1992-10-01T23:59:59.000Z

318

IFP --Oil & Gas Science and Technology --(Script : 1er specimen) --1 --Oil & Gas Science and Technology --rev. IFP, Vol. xx (2009), No X, pp. 00-00  

E-Print Network [OSTI]

IFP -- Oil & Gas Science and Technology -- (Script : 1er specimen) -- 1 -- Oil & Gas Science2010 Author manuscript, published in "Oil & Gas Science and Technology - Rev. IFP, 65, 3 (2010) 435-444" DOI : 10.2516/ogst/2010007 #12;IFP -- Oil & Gas Science and Technology -- (Script : 1er specimen) -- 2

Boyer, Edmond

319

Wyoming chemical flood test for oil recovery shows promise  

SciTech Connect (OSTI)

This project was begun in 1978 to provide data to promote surfactant chemical flooding on a commercial scale in the low-permeability reservoirs of eastern Wyoming and Colorado. The Big Muddy Field in Wyoming was selected because of the large resource, potential net pay, and high oil saturation. Injection began on February 20, 1980 with a surfactant flooding process. Water mixed with salt (brine) was injected as a preflush which was completed on January 20, 1981. This produced 12,122 bbl of oil. The next step involves injecting a surfactant, co-surfactant (alcohol), and polymer. When the injection of the surfactant is completed in the summer of 1982, polymer alone will be injected. Polymer injection will be completed sometime in 1984. The final phase will be a followup water drive scheduled for 1984-1987. As of February 1, 1982, 36,683 bbl of oil had been produced. About 88 bbl of oil per day is being produced, compared to only about 41 bbl per day in February 1981. (ATT)

Not Available

1981-01-01T23:59:59.000Z

320

Water alternating enriched gas injection to enhance oil production and recovery from San Francisco Field, Colombia  

E-Print Network [OSTI]

The main objectives of this study are to determine the most suitable type of gas for a water-alternating-gas (WAG) injection scheme, the WAG cycle time, and gas injection rate to increase oil production rate and recovery from the San Francisco field...

Rueda Silva, Carlos Fernando

2012-06-07T23:59:59.000Z

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


321

FLUID DYNAMICAL AND MODELING ISSUES OF CHEMICAL FLOODING FOR ENHANCED OIL RECOVERY  

E-Print Network [OSTI]

FLUID DYNAMICAL AND MODELING ISSUES OF CHEMICAL FLOODING FOR ENHANCED OIL RECOVERY Prabir Daripa. Relevance of this HS model based result to EOR is established by performing direct numerical simulations of fully developed tertiary displacement in porous media. Results of direct numer- ical simulation

Daripa, Prabir

322

Further experimental studies of steam-propane injection to enhance recovery of Morichal oil  

E-Print Network [OSTI]

In 1998-1999, experimental research was conducted by Goite at Texas A&M University into steam-propane injection to enhance oil recovery from the Morichal field, Venezuela. Goite's results showed that, compared with steam injection alone, steam-propane...

Ferguson,Mark Anthony

2012-06-07T23:59:59.000Z

323

Teapot Dome: Characterization of a CO2-enhanced oil recovery and storage site in Eastern Wyoming  

Science Journals Connector (OSTI)

...storage, and underground coal gasification. Vicki Stamp has more than...unparalleled opportunity for industry and others to use the site...projects are intimately linked to industry-driven enhanced oil recovery...three-dimensional models United States waste disposal Wyoming GeoRef...

S. Julio Friedmann; Vicki W. Stamp

324

Methodology for Designing and Evaluating Chemical Systems for Improved Oil Recovery  

E-Print Network [OSTI]

oil recovery ranging between 86%-91% at reservoir temperature with both soft brine (NaCl only) and synthetic formation brine. Synthetic formation brine for Trembley contained a high concentration of divalent cations in addition to monovalent yet it had...

Ahmed, Muhammad Shahab

2012-08-31T23:59:59.000Z

325

NETL: News Release - DOE-Sponsored Technology Enhances Recovery of Natural  

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

March 26, 2009 March 26, 2009 DOE-Sponsored Technology Enhances Recovery of Natural Gas in Wyoming Researchers Seek Patent for Isotopic Ratio to Evaluate Water in Coalbeds Washington, DC -Research sponsored by the U.S. Department of Energy (DOE) Oil and Natural Gas Program has found a way to distinguish between groundwater and the water co-produced with coalbed natural gas, thereby boosting opportunities to tap into the vast supply of natural gas in Wyoming as well as Montana. In a recently completed project, researchers at the University of Wyoming used the isotopic carbon-13 to carbon-12 ratio to address environmental issues associated with water co-produced with coalbed natural gas. The research resulted in a patent application for this unique use of the ratio. An added benefit of the project, which was managed by the National Energy Technology Laboratory for the DOE Office of Fossil Energy, was the creation of 27 jobs over the project's 2+ years.

326

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

SciTech Connect (OSTI)

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.

Eric P. Robertson

2007-11-01T23:59:59.000Z

327

NETL: Oil & Natural Gas Technologies Reference Shelf  

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

Reference Shelf Reference Shelf NETL Oil & Natural Gas Technologies Reference Shelf Solicitations Project Summaries Publications News Releases Software/Databases CDs/DVDs EOR Illustrations Welcome to the NETL Oil & Natural Gas Technologies Reference Shelf. Recently released and in-demand reference materials are available directly from this page using the links below. Online Database of Oil and Natural Gas Research Results Now Available The Knowledge Management Database (KMD) provides easy access to the results of nearly four decades of research supported by the Office of Fossil EnergyÂ’s Oil and Natural Gas Program. The database portal provides access to content from dozens of CDs and DVDs related to oil and natural gas research that FE's National Energy Technology Laboratory has published over the years. It

328

Improvement in oil recovery using cosolvents with CO{sub 2} gas floods  

SciTech Connect (OSTI)

This report presents the results of investigations to improve oil recovery using cosolvents in CO{sub 2} gas floods. Laboratory experiments were conducted to evaluate the application and selection of cosolvents as additives to gas displacement processes. A cosolvent used as a miscible additive changed the properties of the supercritical gas phase. Addition of a cosolvent resulted in increased viscosity and density of the gas mixture, and enhanced extraction of oil compounds into the CO{sub 2} rich phase. Gas phase properties were measured in an equilibrium cell with a capillary viscometer and a high pressure densitometer. A number of requirements must be considered in the application of a cosolvent. Cosolvent miscibility with CO{sub 2}, brine solubility, cosolvent volatility and relative quantity of the cosolvent partitioning into the oil phase were factors that must be considered for the successful application of cosolvents. Coreflood experiments were conducted with selected cosolvents to measure oil recovery efficiency. The results indicate lower molecular weight additives, such as propane, are the most effective cosolvents to increase oil recovery.

Raible, C.

1992-01-01T23:59:59.000Z

329

Improvement in oil recovery using cosolvents with CO sub 2 gas floods  

SciTech Connect (OSTI)

This report presents the results of investigations to improve oil recovery using cosolvents in CO{sub 2} gas floods. Laboratory experiments were conducted to evaluate the application and selection of cosolvents as additives to gas displacement processes. A cosolvent used as a miscible additive changed the properties of the supercritical gas phase. Addition of a cosolvent resulted in increased viscosity and density of the gas mixture, and enhanced extraction of oil compounds into the CO{sub 2} rich phase. Gas phase properties were measured in an equilibrium cell with a capillary viscometer and a high pressure densitometer. A number of requirements must be considered in the application of a cosolvent. Cosolvent miscibility with CO{sub 2}, brine solubility, cosolvent volatility and relative quantity of the cosolvent partitioning into the oil phase were factors that must be considered for the successful application of cosolvents. Coreflood experiments were conducted with selected cosolvents to measure oil recovery efficiency. The results indicate lower molecular weight additives, such as propane, are the most effective cosolvents to increase oil recovery.

Raible, C.

1992-01-01T23:59:59.000Z

330

Electromagnetic Imaging of CO2 Sequestration at an Enhanced Oil Recovery Site  

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

Electromagnetic Imaging of CO Electromagnetic Imaging of CO 2 Sequestration at an Enhanced Oil Recovery Site Barry Kirkendall (Kirkendall1@llnl.gov ; 925-423-1513) Jeff Roberts (Roberts17@llnl.gov ; 925-422-7108) Lawrence Livermore National Laboratory 7000 East Avenue Livermore, CA 94550 1.1 Introduction Lawrence Livermore National Laboratory (LLNL) is currently involved in a long term study using time-lapse multiple frequency electromagnetic (EM) characterization at a waterflood enhanced oil recovery (EOR) site in California operated by Chevron Heavy Oil Division in Lost Hills, California (Figure 1). The petroleum industry's interest and the successful imaging results from this project suggest that this technique be extended to monitor CO 2 sequestration at an EOR site also operated by Chevron. The impetus for this study is

331

Experimental Evaluation of Surfactant Application to Improve Oil Recovery  

E-Print Network [OSTI]

FIGURE 4. 20 PHOTO OF W11-34-3: 0.75% C16-17-7PO-SO4-, 0.25% C15-18 IOS, 1.67% EGBE, 0.33% DGBE, 0.5% NA2CO3, AFTER 6 DAYS, OIL CONC.=50% AT RES T (43°C). ......................... 104 FIGURE 4. 21 APSL AT RES T (43°C) CHANGES WITH TIME FOR TWO TYPICAL....14 % C15-18 IOS, 1.75% DGBE, 1% NA2CO3, 2000PPM FP3530S AFTER 29 DAYS, OIL CONC.=33% AT RES T (43°C). .. 115 FIGURE 4. 33 SOLUBILIZATION PLOT OF W12-20: 0.36% C16-17-7PO-SO4-, 0.14% C15-18 IOS, 1.75% DGBE, 1% NA2CO3, 2000PPM FP3430S AFTER 21 DAYS...

Liu, Zhijun

2011-09-16T23:59:59.000Z

332

Steam injection method and apparatus for recovery of oil  

SciTech Connect (OSTI)

A method and apparatus for recovering oil from an oil bearing formation utilizing steam injected into the formation. A working fluid is heated at the surface to produce a reversible, chemical reaction, particularly a reforming reaction in a reforming/methanation reaction cycle. The products of the reforming reaction are transported at near ambient temperatures to a downhole heat exchanger through which water is circulated. There a catalyst triggers the methanation reaction, liberating heat energy to convert the water to steam. The products of the methanation reaction are recirculated to the surface to repeat the cycle. In one embodiment the products of the methanation reaction are injected into the formation along with the steam. Various catalysts, and various systems for heating the working fluid are disclosed.

Meeks, T.; Rhoades, C.A.

1983-02-08T23:59:59.000Z

333

Improved techniques for fluid diversion in oil recovery. Final report  

SciTech Connect (OSTI)

This three-year project had two technical objectives. The first objective was to compare the effectiveness of gels in fluid diversion (water shutoff) with those of other types of processes. Several different types of fluid-diversion processes were compared, including those using gels, foams, emulsions, particulates, and microorganisms. The ultimate goals of these comparisons were to (1) establish which of these processes are most effective in a given application and (2) determine whether aspects of one process can be combined with those of other processes to improve performance. Analyses and experiments were performed to verify which materials are the most effective in entering and blocking high-permeability zones. The second objective of the project was to identify the mechanisms by which materials (particularly gels) selectively reduce permeability to water more than to oil. A capacity to reduce water permeability much more than oil or gas permeability is critical to the success of gel treatments in production wells if zones cannot be isolated during gel placement. Topics covered in this report include (1) determination of gel properties in fractures, (2) investigation of schemes to optimize gel placement in fractured systems, (3) an investigation of why some polymers and gels can reduce water permeability more than oil permeability, (4) consideration of whether microorganisms and particulates can exhibit placement properties that are superior to those of gels, and (5) examination of when foams may show placement properties that are superior to those of gels.

Seright, R.

1996-01-01T23:59:59.000Z

334

Oil and Natural Gas Program Commericialized Technologies and...  

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

Energy Technology Laboratory (NETL) works to ensure that domestic natural gas and oil can remain part of the U.S. energy portfolio for decades to come. Research focused on...

335

Discussion on a Code Comparison Effort for the Geothermal Technologies...  

Office of Environmental Management (EM)

gas hydrate accumulations * Suboceanic gas hydrate accumulations * Piceance Basin oil shale * Enhanced oil recovery technologies Experimental Links * CCl 4 Migration and...

336

Activities of the Oil Implementation Task Force; Contracts for field projects and supporting research on enhanced oil recovery, July--September 1990  

SciTech Connect (OSTI)

The report contains a general introduction and background to DOE's revised National Energy Strategy Advanced Oil Recovery Program and activities of the Oil Implementation Task Force; a detailed synopsis of the symposium, including technical presentations, comments and suggestions; a section of technical information on deltaic reservoirs; and appendices containing a comprehensive listing of references keyed to general deltaic and geological aspects of reservoirs and those relevant to six selected deltaic plays. Enhanced recovery processes include chemical floodings, gas displacement, thermal recovery, geoscience, and microbial recovery.

Tiedemann, H.A. (ed.) (USDOE Bartlesville Project Office, OK (USA))

1991-05-01T23:59:59.000Z

337

[Passamaquoddy Technology Recovery Scrubber{trademark}, March 1992  

SciTech Connect (OSTI)

The Passamaquoddy Technology Recovery Scrubber{trademark} has been built and is being demonstrated on-line at the Dragon Products Plant in Thomaston, Maine. This Innovative Clean Coal Technology is using waste cement kiln dust (CKD) to scrub sulfur dioxide, some NO{sub x}, as well as a small amount of carbon dioxide from a coal burning kiln exhaust flue gas. The process also enables the cement plant to reuse the treated CKD, eliminating the need to landfill this material. Potassium, the offending contaminant in the CKD, is extracted in a useful form, potassium sulfate, which is used as a fertilizer. These useful products generate income from operation of this Recovery Scrubber. System start-up was begun in late December of 1990. At that time, several mechanical problems were encountered. These relatively minor problems were resolved enabling Phase III to begin on August 20, 1991. While inefficiencies are still being worked out, major program objectives are being met. Resolution of remaining operability problems is well in hand and should not hamper attainment of all project goals.

Not Available

1992-03-03T23:59:59.000Z

338

Offshore oil and gas: global resource knowledge and technological change  

Science Journals Connector (OSTI)

It is argued that the contribution of technological change to the offshore oil and gas industry's progress is under-researched. As a prelude this theme, the changing geography of known offshore oil and gas resources is reviewed. Significant, and largely technologically dependent, developments are identified in terms of the industry's global spread, its extension into deep and ultradeep waters and its ability to enhance output from well-established oil and gas provinces. Three sections (on the evolution of exploration and production rigs, drilling techniques and the application of IT to improve resource knowledge and access) then examine the relationships between technological change and the offshore industry's progress. It is concluded that new technologies improve knowledge of, and access to, resources via four distinctive routes, but that the full impact of R & D is frequently related to the inter-dependence of technologies. Opportunities for further research are identified.

David Pinder

2001-01-01T23:59:59.000Z

339

Quantitation of microbial products and their effectiveness in enhanced oil recovery. Final report  

SciTech Connect (OSTI)

A three-dimensional, three-phase, multiple-component numerical simulator was developed to investigate transport and growth of microorganisms in porous media and the impacts of microbial activities on oil recovery. The microbial activities modeled in this study included: (1) growth, retention, chemotaxis, and end product inhibition of growth, (2) the formation of metabolic products, and (3) the consumption of nutrients. Major mechanisms for microbial enhanced oil recovery (MEOR) processes were modeled as follows: (1) improvement in sweep efficiency of a displacement process due to in situ plugging of highly-permeable production zones by cell mass or due to improved mobility control achieved by increasing the viscosity of the displacing fluid with a biopolymer, and (2) solubilization and mobilization of residual oil in porous media due to the reduction of the interfacial tension between oleic and aqueous phases by the production of a biosurfactant. The numerical solutions for mathematical models involved two steps. The distributions of pressure and phase saturations were solved from continuity equations and Darcy flow velocities for the aqueous phase were computed. This was followed by the solution of convection-dispersion equations for individual components. Numerical solutions from the proposed model were compared to results obtained from analytical equations, commercial simulators, and laboratory experiments. The comparison indicated that the model accurately quantified microbial transport and metabolism in porous media, and predicted additional crude oil recovery due to microbial processes. 50 refs., 41 figs., 26 tabs.

Zhang, X.; Knapp, R.M.; McInerney, M.J.

1995-02-01T23:59:59.000Z

340

The utilization of the microflora indigenous to and present in oil-bearing formations to selectively plug the more porous zones thereby increasing oil recovery during waterflooding, Class 1  

SciTech Connect (OSTI)

The objectives of this project were (1) to demonstrate the in situ microbial population in a fluvial dominated deltaic reservoir could be induced to proliferate to such an extent that they will selectively restrict flow in the more porous zones in the reservoir thereby forcing injection water to flow through previously unswept areas thus improving the sweep efficiency of the waterflood and (2) to obtain scientific validation that microorganisms are indeed responsible for the increased oil recovery. One expected outcome of this new technology was the prolongation of economical life of the reservoir, i.e. economical oil recovery should continue for much longer periods in areas of the reservoir subjected to the MPPM technology than it would if it followed its historic trend.

Stephens, James O.; Brown, Lewis R.; Vadie, A. Alex

2000-02-02T23:59:59.000Z

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


341

NREL: Technology Deployment - Disaster Recovery Support at FEMA...  

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

Disaster Recovery Support at FEMA Incorporates Sustainability in Rebuilding Efforts News FEMA Engages NREL in Hurricane Sandy Recovery Effort NREL's Federal Fueling Station Data...

342

Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump  

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

Ground Source Heat Pump Demonstration Projects to someone by E-mail Ground Source Heat Pump Demonstration Projects to someone by E-mail Share Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump Demonstration Projects on Facebook Tweet about Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump Demonstration Projects on Twitter Bookmark Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump Demonstration Projects on Google Bookmark Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump Demonstration Projects on Delicious Rank Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump Demonstration Projects on Digg Find More places to share Building Technologies Office: Recovery Act-Funded Ground Source Heat Pump Demonstration Projects on AddThis.com...

343

An investigation of the effect of ammonia and amines on the recovery of oil  

E-Print Network [OSTI]

AE INVESTIGATION OF THE EFFECT OF AMMONIA A?D ANIEES OE THE RECOVERT OF OIL A Thesis EF~ %0 JAMES MP RICHARDSON Submitted to the Graduate School of the Agricultural and Mechanical College of Texas in partial fulfillment of the requirements... for the degree of MASTER OF SCIENCE ~J1 8 Na)or Subject: Petroleum En carin AE IEVESTIGATIOE OF TEE EFFECT OF AMMOBIA AED AMIEES OE TRE RECOVERY OF OIL JAMES M, RICRARDSOE Approve& as to sty1e aad eoateat by". Cha1rsan o CeeeeAt e Read of Departaeat J~18...

Richardson, James Malone

2012-06-07T23:59:59.000Z

344

Assessment of oil-shale technology in Brazil. Final technical report, October 27, 1980-July 27, 1981  

SciTech Connect (OSTI)

The development of an oil shale industry in the United States will require the solution of a variety of technical, economic, environmental, and health and safety problems. This assessment investigates whether US oil shale developers might benefit from the experience gained by the Brazilians in the operation of their Usina Prototipo do Irati oil shale demonstration plant at Sao Mateus do Sul, and from the data generated from their oil shale research and development programs. A chapter providing background information on Brazil and the Brazilian oil shale deposits is followed by an examination of the potential recovery processes applicable to Brazilian oil shale. The evolution of the Brazilian retorting system is reviewed and compared with the mining and retorting proposed for US shales. Factors impacting on the economics of shale oil production in Brazil are reviewed and compared to economic analyses of oil shale production in the US. Chapters examining the consequences of shale development in terms of impact on the physical environment and the oil shale worker complete the report. Throughout the report, where data permits, similarities and differences are drawn between the oil shale programs underway in Brazil and the US. In addition, research areas in which technology or information transfer could benefit either or both countries' oil shale programs are identified.

Not Available

1981-07-27T23:59:59.000Z

345

Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas -- Near-term. Quarterly report, January 1--March 31, 1998  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Morrow sandstone reservoirs in southwestern Kansas and in Cherokee Group reservoirs in southeastern Kansas. Two demonstration sites operated by different independent oil operators are involved in this project. The Stewart Field is located in Finney County, Kansas and is operated by PetroSantander, Inc. The Nelson Lease is located in Allen County, Kansas, in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. General topics to be addressed are (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. Progress is described for the Stewart field on the following tasks: design/construct waterflood plant; design/construct injection system; design/construct battery consolidation and gathering system; waterflood operations and reservoir management; and technology transfer. Progress for the Savonburg Field includes: water plant development; profile modification treatments; pattern changes and wellbore cleanup; reservoir development (polymer flooding); field operations; and technology transfer.

Green, D.W.; Willhite, G.P.; Walton, A.; McCune, D.; Reynolds, R.; Michnick, M.; Watney, L.

1998-04-15T23:59:59.000Z

346

Monte Carlo simulation-based dynamic mixed integer nonlinear programming for supporting oil recovery and devices allocation during offshore oil spill responses  

Science Journals Connector (OSTI)

Abstract In response to an offshore oil spill, many devices such as skimmers are deployed to recover spilled oil. The lack of effective decision support for device allocation and operation can usually result in a compromise of recovery efficiency and/or waste of resources and manpower. It is therefore much desired to optimize such processes by integrating the simulation of oil recovery and weathering processes, an optimization module, and an uncertainty handling approach. However, limited studies have reported on such integration. Furthermore, no studies have considered the allocation and management of oil recovery devices. To help fill the gaps, this study developed a Monte Carlo simulation-based dynamic mixed integer nonlinear programming (MC-DMINP) approach to provide sound decisions for devices allocation and recovery operation in a fast, dynamic and cost-efficient manner. In a case study, regression models were developed to simulate the efficiencies of three types of drum skimmers based on the past performance evaluation tests. The models were further integrated with the simulation of oil weathering processes and the optimization method. Finally, the uncertainties in slick area, temperature, and wind speed were also involved in the case study. The optimization results without the consideration of uncertainty indicated a 79.3% of oil recovery efficiency. Meanwhile, 18.5% of the spilled oil was evaporated and 2.1% was dispersed. With the consideration of uncertainties, the mechanical collection of oil still had a major contribution to the transport and fate of oil. Negative effects on mechanical collection and positive effects on evaporation were observed from the uncertainties associated with slick area and temperature. The uncertainties of wind speed had positive effects on dispersion. The results demonstrated that the developed MC-DMINP approach could help making timely, sound decisions on the allocation and operation of oil recovery devices and therefore ensure more efficient response actions under dynamic and uncertainty.

Pu Li; Bing Chen; Baiyu Zhang; Liang Jing; Jisi Zheng

2014-01-01T23:59:59.000Z

347

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

SciTech Connect (OSTI)

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 existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Scott Hara

2004-03-05T23:59:59.000Z

348

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

SciTech Connect (OSTI)

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 existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Scott Hara

2003-09-04T23:59:59.000Z

349

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

SciTech Connect (OSTI)

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 existing steam drive area to improve thermal efficiency. (7) Installing an 2400 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Scott Hara

2003-06-04T23:59:59.000Z

350

Technical constraints limiting application of enhanced oil recovery techniques to petroleum production in the United States  

SciTech Connect (OSTI)

In the interval since the publication in September 1980 of the technical constraints that inhibit the application of enhanced oil recovery techniques in the United States, there has been a large number of successful field trials of enhanced oil recovery (EOR) techniques. The Department of Energy has shared the costs of 28 field demonstrations of EOR with industry, and the results have been made available to the public through DOE documents, symposiums and the technical literature. This report reexamines the constraints listed in 1980, evaluates the state-of-the-art and outlines the areas where more research is needed. Comparison of the 1980 constraints with the present state-of-the-art indicates that most of the constraints have remained the same; however, the constraints have become more specific. 26 references, 6 tables.

Not Available

1984-01-01T23:59:59.000Z

351

Immediate Deployment of Waste Energy Recovery Technologies at Multi Sites  

SciTech Connect (OSTI)

Verso Paper Corp. implemented a portfolio of 13 commercially available proven industrial technologies each exceeding 30% minimum threshold efficiency and at least 25% efficiency increase. These sub-projects are a direct result of a grant received from the Department of Energy (DOE) through its FOA 0000044 (Deployment of Combined Heat and Power (CHP) Systems, District Energy Systems, Waste Energy Recovery Systems, and Efficient Industrial Equipment), which was funded by the American Recovery Act. These were installed at 3 sites in 2 states and are helping to reduce Verso costs, making the facilities more competitive. This created approximately 100 construction jobs (FTE's) and reduced impacted Verso facilities' expense budgets. These sub-projects were deployed at Verso paper mills located in Jay, Maine, Bucksport, Maine, and Sartell, Minnesota. The paper mills are the economic engines of the rural communities in which these mills are located. Reinvestment in waste energy recovery capital improvements is providing a stimulus to help maintain domestic jobs and to competitively position the US pulp and paper industry with rising energy costs. Energy efficiency improvements are also providing a positive environmental impact by reducing greenhouse gas emissions, the quantity of wastewater treated and discharged, and fossil fuel demand. As a result of these projects, when fully operating, Verso realized a total of approximately 1.5 TBtu/Year reduction in overall energy consumption, which is 119% of the project objectives. Note that three paper machines have since been permanently curtailed. However even with these shutdowns, the company still met its energy objectives. Note also that the Sartell mill's paper machine is down due to a recent fire which damaged the mill's electrical infrastructure (the company has not decided on the mill's future).

Dennis Castonguay

2012-06-29T23:59:59.000Z

352

Quantitative Methods for Reservoir Characterization and Improved Recovery: Application to Heavy Oil Sands  

SciTech Connect (OSTI)

Improved prediction of interwell reservoir heterogeneity is needed to increase productivity and to reduce recovery cost for California's heavy oil sands, which contain approximately 2.3 billion barrels of remaining reserves in the Temblor Formation and in other formations of the San Joaquin Valley. This investigation involved application of advanced analytical property-distribution methods conditioned to continuous outcrop control for improved reservoir characterization and simulation.

Castle, James W.; Molz, Fred J.

2003-02-07T23:59:59.000Z

353

Modeling effects of diffusion and gravity drainage on oil recovery in naturally fractured reservoirs under gas injection  

E-Print Network [OSTI]

Gas injection in naturally fractured reservoirs maintains the reservoir pressure, and increases oil recovery primarily by gravity drainage and to a lesser extent by mass transfer between the flowing gas in the fracture and the porous matrix...

Jamili, Ahmad

2010-04-22T23:59:59.000Z

354

An Analytical Model for Determination of the Solvent Convective Dispersion Coefficient in the Vapor Extraction Heavy Oil Recovery Process  

Science Journals Connector (OSTI)

In this article, a new model is developed to determine the solvent convective dispersion coefficient in a solvent vapor extraction (VAPEX) heavy oil recovery process. It is assumed that solvent mass transfer b...

Mohammad Derakhshanfar; Yongan Gu

2012-03-01T23:59:59.000Z

355

Deep Placement Gel Bank as an Improved Oil Recovery Process: Modeling, Economic Analysis and Comparison to Polymer Flooding  

E-Print Network [OSTI]

have conducted relevant literature review about the development, design, modeling and economics of the enhanced oil recovery methods. Schlumberger's Eclipse simulator software has been used for modeling purposes. Modeling runs have demonstrated...

Seyidov, Murad

2011-08-08T23:59:59.000Z

356

Integrated, multidisciplinary reservoir characterization, modeling and engineering leading to enhanced oil recovery from the Midway-Sunset field, California  

SciTech Connect (OSTI)

The Pru Fee property is developed in a heavy oil, Class III (slope and basin clastic sand), reservoir of the Midway-Sunset field, San Joaquin Basin, California. Wells on the property were shut-in with an estimated 85% of the original oil remaining in place because the reservoir failed to respond to conventional cyclic steaming. Producibility problems are attributed to the close proximity of the property to the margin of the field. Specific problems include complex reservoir geometry, thinning pay, bottom water, and dipping beds. These problems are likely common at the margins of the Midway-Sunset and other Class III reservoirs. This project forms the first step in returning the property to production and explores strategies that might be applied elsewhere. Reservoir characterization, modeling, and engineering methods are integrated to design, simulate, and implement a pilot steam flood. A new drillhole provides good quality, core through the pay zone and a full suite of geophysical logs. Correlations between geological and petrophysical data are used to extrapolate reservoir conditions from older logs and yield a 3-dimensional petrophysical model. Numerical results illustrate how each producibility problem might influence production and provide a framework for designing the pilot steam flood. This first phase illustrates how a multidisciplinary team can use established technologies in developing the detailed petrophysical, geological, and numerical models needed to enhance oil recovery from marginal areas of Class III reservoirs.

Schamel, S.; Forster, C.; Deo, M. (Univ. of Utah, Salt Lake City, UT (United States)) (and others)

1996-01-01T23:59:59.000Z

357

Integrated, multidisciplinary reservoir characterization, modeling and engineering leading to enhanced oil recovery from the Midway-Sunset field, California  

SciTech Connect (OSTI)

The Pru Fee property is developed in a heavy oil, Class III (slope and basin clastic sand), reservoir of the Midway-Sunset field, San Joaquin Basin, California. Wells on the property were shut-in with an estimated 85% of the original oil remaining in place because the reservoir failed to respond to conventional cyclic steaming. Producibility problems are attributed to the close proximity of the property to the margin of the field. Specific problems include complex reservoir geometry, thinning pay, bottom water, and dipping beds. These problems are likely common at the margins of the Midway-Sunset and other Class III reservoirs. This project forms the first step in returning the property to production and explores strategies that might be applied elsewhere. Reservoir characterization, modeling, and engineering methods are integrated to design, simulate, and implement a pilot steam flood. A new drillhole provides good quality, core through the pay zone and a full suite of geophysical logs. Correlations between geological and petrophysical data are used to extrapolate reservoir conditions from older logs and yield a 3-dimensional petrophysical model. Numerical results illustrate how each producibility problem might influence production and provide a framework for designing the pilot steam flood. This first phase illustrates how a multidisciplinary team can use established technologies in developing the detailed petrophysical, geological, and numerical models needed to enhance oil recovery from marginal areas of Class III reservoirs.

Schamel, S.; Forster, C.; Deo, M. [Univ. of Utah, Salt Lake City, UT (United States)] [and others

1996-12-31T23:59:59.000Z

358

Investigation of Multiscale and Multiphase Flow, Transport and Reaction in Heavy Oil Recovery Processes  

SciTech Connect (OSTI)

This project is an investigation of various multi-phase and multiscale transport and reaction processes associated with heavy oil recovery. The thrust areas of the project include the following: Internal drives, vapor-liquid flows, combustion and reaction processes, fluid displacements and the effect of instabilities and heterogeneities and the flow of fluids with yield stress. These find respective applications in foamy oils, the evolution of dissolved gas, internal steam drives, the mechanics of concurrent and countercurrent vapor-liquid flows, associated with thermal methods and steam injection, such as SAGD, the in-situ combustion, the upscaling of displacements in heterogeneous media and the flow of foams, Bingham plastics and heavy oils in porous media and the development of wormholes during cold production.

Yortsos, Yanis C.

2001-08-07T23:59:59.000Z

359

Investigation of Multiscale and Multiphase Flow, Transport and Reaction in Heavy Oil Recovery Processes  

SciTech Connect (OSTI)

This report is an investigation of various multi-phase and multiscale transport and reaction processes associated with heavy oil recovery. The thrust areas of the project include the following: Internal drives, vapor-liquid flows, combustion and reaction processes, fluid displacements and the effect of instabilities and heterogeneities and the flow of fluids with yield stress. These find respective applications in foamy oils, the evolution of dissolved gas, internal steam drives, the mechanics of concurrent and countercurrent vapor-liquid flows, associated with thermal methods and steam injection, such as SAGD, the in-situ combustion, the upscaling of displacements in heterogeneous media and the flow of foams, Bingham plastics and heavy oils in porous media and the development of wormholes during cold production.

Yortsos, Y.C.

2001-05-29T23:59:59.000Z

360

Zhuhai Oil Energy Science and Technology | Open Energy Information  

Open Energy Info (EERE)

Zhuhai Oil Energy Science and Technology Zhuhai Oil Energy Science and Technology Jump to: navigation, search Name Zhuhai Oil Energy Science and Technology Place Zhuhai, China Sector Biofuels Stock Symbol BMGP Coordinates 22.27094°, 113.577261° Loading map... {"minzoom":false,"mappingservice":"googlemaps3","type":"ROADMAP","zoom":14,"types":["ROADMAP","SATELLITE","HYBRID","TERRAIN"],"geoservice":"google","maxzoom":false,"width":"600px","height":"350px","centre":false,"title":"","label":"","icon":"","visitedicon":"","lines":[],"polygons":[],"circles":[],"rectangles":[],"copycoords":false,"static":false,"wmsoverlay":"","layers":[],"controls":["pan","zoom","type","scale","streetview"],"zoomstyle":"DEFAULT","typestyle":"DEFAULT","autoinfowindows":false,"kml":[],"gkml":[],"fusiontables":[],"resizable":false,"tilt":0,"kmlrezoom":false,"poi":true,"imageoverlays":[],"markercluster":false,"searchmarkers":"","locations":[{"text":"","title":"","link":null,"lat":22.27094,"lon":113.577261,"alt":0,"address":"","icon":"","group":"","inlineLabel":"","visitedicon":""}]}

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


361

High efficiency shale oil recovery. Fourth quarterly report, October 1, 1992--December 31, 1992  

SciTech Connect (OSTI)

The overall project objective is to demonstrate the high efficiency of the Adams Counter-Current shale oil recovery process. The efficiency will first be demonstrated on a small scale, in the current phase, after which the demonstration will be extended to the operation of a small pilot plant. Thus the immediate project objective is to obtain data on oil shale retorting operations in a small batch rotary kiln that will be representative of operations in the proposed continuous process pilot plant. Although an oil shale batch sample is sealed in the batch kiln from the start until the end of the run, the process conditions for the batch are the same as the conditions that an element of oil shale would encounter in a continuous process kiln. Similar chemical and physical (heating, mixing) conditions exist in both systems. The two most important data objectives in this phase of the project are to demonstrate (1) that the heat recovery projected for this project is reasonable and (2) that an oil shale kiln will run well and not plug up due to sticking and agglomeration. The following was completed and is reported on this quarter: (1) A software routine was written to eliminate intermittently inaccurate temperature readings. (2) We completed the quartz sand calibration runs, resolving calibration questions from the 3rd quarter. (3) We also made low temperature retorting runs to identify the need for certain kiln modifications and kiln modifications were completed. (4) Heat Conductance data on two Pyrolysis runs were completed on two samples of Occidental oil shale.

Adams, D.C.

1992-12-31T23:59:59.000Z

362

Sandia National Laboratories: oil and gas technology  

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

industriell og teknisk forskning) will now tackle energy challenges such as renewable-energy integration, grid modernization, gas technologies, and algae-based biofuels. SINTEF is...

363

Develop Thermoelectric Technology for Automotive Waste Heat Recovery...  

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

More Documents & Publications Skutterudite Thermoelectric Generator For Automotive Waste Heat Recovery Thermoelectric Conversion of Exhaust Gas Waste Heat into Usable...

364

Optical Fiber Sensor Technologies for Efficient and Economical Oil Recovery  

SciTech Connect (OSTI)

The overall goal of this project was to develop reliable cost effective sensors for application in the down-hole environment. The physical parameters measured by these sensors were temperature, pressure, flow and acoustic signals. Sensor head configurations for each of the physical measurands were optimized to increase the sensitivity to the particular measurand of interest while decreasing the cross-sensitivity to the other physical measurands and to environmental influences. In addition, the optical signal demodulation electronics was designed to be insensitive to environmental influences while maintaining the required resolution, precision and accuracy of the parameter being sensed. The influence of potentially detrimental agents such as water in the down-hole environment was investigated as well as methods to protect both the optical fiber and the sensor from these detrimental effects.

Wang, a.; Pickrell, G.; Xiao, H.; May, r.

2003-02-27T23:59:59.000Z

365

Visual display of reservoir parameters affecting enhanced oil recovery. FY 1994 annual report  

SciTech Connect (OSTI)

Evaluation of oil and gas properties for enhanced oil recovery (EOR) involves a high degree of risk, especially when the fields are old and well past their prime. The purpose of this project is to provide the small-to-medium size oil field operator with the tools necessary to do an EOR evaluation of the same quality and sophistication that only large international oil companies have been able to afford to date. This approach utilizes readily available, affordable computer software and analytical services. This project will provide a detailed example, based on a field trial, of how to evaluate a field for EOR operations utilizing data typically available in a field which has undergone primary development. After reviewing PC-based software from most major vendors, the authors decided that the most effective way to provide a user-friendly, state-of-the-art package to the independent producers who are primary clients is to link the best modules from four different systems: a commercial database, a wireline log analysis program, a mapping program, and a 2D and 3D visualization program, into a flexible, user-friendly unit. This would result in a product that could be used by small oil and gas companies to perform computerized reservoir studies. Progress to date is described.

Wood, J.R.

1995-06-01T23:59:59.000Z

366

Chemicals for enhanced oil recovery. Semiannual report, 1 April 1980-30 September 1980  

SciTech Connect (OSTI)

The objective of Chemicals for Enhanced Oil Recovery is to lower barriers to implementation of the micellar flood approach by decreasing cost and increasing availability of chemicals used in the process. This is done by finding alternative feedstocks in wastes or low valued organic byproducts and by development of lower cost production procedures. For this semiannual report, progress reports are presented for the following research areas: phase behavior in multicomponent systems containing tall oil ethoxylates; anionic tall oil derivatives (materials and methods, phase studies, interfacial tensions); sacrificial agents; economic considerations in materials selection; and materials and methods. A survey on the availability of materials, such as alcohols and unsaturated long-chain fatty acids, which could be used for micellar flooding revealed that some of the alternative chemicals which have been studied here such as oleic acid surfactants could substantially decrease micellar flooding chemical costs, if they are successful on further testing. Production of C/sub 3/ and C/sub 4/ alcohols and vegetable and tall oil fatty acids appear at a high enough level so that one million bbl of incremental oil per day would consume a substantial but not prohibitive fraction on the basis of requirements given in a recent Lewin report. However, substantial market disallocations could result from this level of chemical requirement, affecting the elastic prices of these materials. The effect of use of various alcohols and surfactants in novel fuel blends, such as gasohol and microemulsion diesel fuels, is unclear, since both competition and stimulation of production are involved.

Compere, A.L.; Crenshaw, J.M.; Greene, S.V.; Griffith, W.L. Johnson, J.S. Jr.; Jones, R.M.; Magid, L.J.; Triolo, R.; Westmoreland, C.G.

1981-11-01T23:59:59.000Z

367

NETL: Oil & Natural Gas Technologies Reference Shelf - Presentation on  

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

De-Watering of Hunton Reservoirs De-Watering of Hunton Reservoirs De-Watering of Hunton Reservoirs Author: Mohan Kelkar, University of Tulsa, Tulsa, OK. Venue: Tulsa Association of Petroleum Landmen meeting in Tulsa, OK, April 19, 2007 (http://www.landman.org [external site]). Abstract: The Hunton reservoir in Oklahoma represents one of the largest discoveries in Oklahoma in recent history. Since 1995, several Hunton reservoir fields have been exploited by various operators. The principle behind this exploitation remains the same: The wells produce large quantities of water, and along with it, significant quantities of natural gas and sometimes oil. Examination of various fields producing from the Hunton reservoir indicates that the economic success from these fields is not uniform. Some fields produce significant quantities of oil, whereas some fields only produce gas. In some fields, horizontal wells work best, whereas in some other fields, vertical wells do a good job. The water production from the fields ranges from as low as few hundred barrels per day to several thousand barrels per day. In this paper, we present the results from various fields to indicate the parameters needed in a Hunton field to make it economically successful. We restrict our evaluation to parameters that can be easily measured or are readily available. These include log data (gamma ray, resistivity, neutron, and density), initial potential data, production data (oil, gas, and water—if available) and well configuration (vertical or horizontal). By analyzing the recovery of oil and gas according to various reservoir parameters, we developed a methodology for predicting the future success of the field. For example, a clear relationship exists between porosity of the rock and initial hydrocarbon saturation: The higher the oil saturation, the better the recovery factor. Initial potential is critical in determining possible recovery. Horizontal wells cost 1.5 to 2 times more than vertical wells and may not provide the additional recovery to justify the costs. The Hunton formation is extensive in Oklahoma. If we want to extend the success of some of the fields to other areas, we need clear guidelines in terms of what is needed to exploit those fields. This paper provides some of those guidelines based on the examination of the currently producing fields.

368

Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 89  

SciTech Connect (OSTI)

Summaries are presented for the DOE contracts related to supported research for thermal recovery of petroleum, geoscience technology, and field demonstrations in high-priority reservoir classes. Data included for each project are: title, contract number, principal investigator, research organization, beginning date, expected completion date, amount of award, objectives of the research, and summary of technical progress.

NONE

1998-04-01T23:59:59.000Z

369

Technology experience and economics of oil shale mining in Estonia  

SciTech Connect (OSTI)

The exhaustion of fuel-energy resources became an evident problem of the European continent in the 1960s. Careful utilization of their own reserves of coal, oil, and gas (Germany, France, Spain) and assigned shares of imports of these resources make up the strategy of economic development of the European countries. The expansion of oil shale utilization is the most topical problem. The experience of mining oil shale deposits in Estonia and Russia, in terms of the practice and the economic results, is reviewed in this article. The room-and-pillar method of underground mining and the open-cut technology of clearing the ground ensure the fertility of a soil. The economics of underground and open pit oil shale mines is analyzed in terms of natural, organizational, and technical factors. These analyses are used in the planning and management of oil shale mining enterprises. The perspectives of the oil shale mining industry of Estonia and the economic expediency of multiproduction are examined. Recommendations and guidelines for future industrial utilization of oil shale are given in the summary.

Fraiman, J.; Kuzmiv, I. [Estonian Oil Shale State Co., Jyhvi (Estonia). Scientific Research Center

1995-11-01T23:59:59.000Z

370

Evaluation of CO2 enhanced oil recovery and sequestration potential in low permeability reservoirs, Yanchang Oilfield, China  

Science Journals Connector (OSTI)

Abstract Sequestrating CO2 in reservoirs can substantially enhance oil recovery and effectively reduce greenhouse gas emission. To evaluate the potential of CO2 enhanced oil recovery (EOR) and sequestration for Yanchang Oilfield in China, a screening standard which was suitable for CO2-EOR and sequestration in Yanchang Oilfield was proposed based on its characteristics of strong heterogeneity, high water content and severe fluid channeling after water flooding. In addition, an efficient calculation method – stream tube simulation method was presented to figure out CO2 sequestration coefficient and oil recovery factor. After screening and evaluating, it turned out that 148 out of 176 blocks in 22 oilfields were suitable for CO2-EOR and sequestration. CO2 flooding after water flooding can produce 180.21 × 106 t more crude oil and sequestrate 223.38 × 106 t CO2. The average incremental oil recovery rate of miscible reservoirs was 12.49% and the average CO2 sequestration coefficient was 0.27 t/t while the two values were 6.83% and 0.18 t/t for immiscible reservoirs. There are comparatively more reservoirs that are suitable for CO2-EOR and sequestration in Yanchang Oilfield than normal, which can obviously enhance oil recovery and means a great potential for CO2 sequestration. CO2-EOR and sequestration in Yanchang Oilfield has a bright application prospect.

D.F. Zhao; X.W. Liao; D.D. Yin

2014-01-01T23:59:59.000Z

371

Increased oil recovery from mature oil fields using gelled polymer treatments  

SciTech Connect (OSTI)

Gelled polymer treatments are applied to oil reservoirs to increase oil production to reduce water production by altering the fluid movement within the reservoir. This research program is aimed at reducing barriers to the widespread use of these treatments by developing methods to predict gel behavior during placement in matrix rock and fractures, determining the persistence of permeability reduction after gel placement, and by developing methods to design production well treatments to control water production. This report describes the progress of the research during the first six months of work. A Dawn EOS multi-angle laser light scattering detector was purchased, installed and calibrated. Experiments were conducted to determine the permeabilities of a bulk gel and of a filter cake which forms when a gel is dehydrated. The pressure at which a gel in a tube is ruptured was measured and was correlated to the length and diameter of the gel.

Willhite, G. Paul; Green, Down W.; McCool, Stan

2000-02-23T23:59:59.000Z

372

A study of the effects of enhanced oil recovery agents on the quality of Strategic Petroleum Reserves crude oil. Final technical report  

SciTech Connect (OSTI)

The project was initiated on September 1, 1990. The objective of the project was to carry out a literature search to estimate the types and extents of long time interactions of enhanced oil recovery (EOR) agents, such as surfactants, caustics and polymers, with crude oil. This information is necessary to make recommendations about mixing EOR crude oil with crude oils from primary and secondary recovery processes in the Strategic Petroleum Reserve (SPR). Data were sought on both adverse and beneficial effects of EOR agents that would impact handling, transportation and refining of crude oil. An extensive literature search has been completed, and the following informations has been compiled: (1) a listing of existing EOR test and field projects; (2) a listing of currently used EOR agents; and (3) evidence of short and long term physical and chemical interactions of these EOR-agents with hydrocarbons, and their effects on the quality of crude oil at long times. This information is presented in this report. Finally some conclusions are derived and recommendations are made. Although the conclusions are based mostly on extrapolations because of lack of specific data, it is recommended that the enhancement of the rates of biodegradation of oil catalyzed by the EOR agents needs to be further studied. There is no evidence of substantial long term effects on crude oil because of other interactions. Some recommendations are also made regarding the types of studies that would be necessary to determine the effect of certain EOR agents on the rates of biodegradation of crude oil.

Kabadi, V.N.

1992-10-01T23:59:59.000Z

373

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

SciTech Connect (OSTI)

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.

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

2002-09-30T23:59:59.000Z

374

Evolution of seismic velocities in heavy oil sand reservoirs during thermal recovery process  

E-Print Network [OSTI]

In thermally enhanced recovery processes like cyclic steam stimulation (CSS) or steam assisted gravity drainage (SAGD), continuous steam injection entails changes in pore fluid, pore pressure and temperature in the rock reservoir, that are most often unconsolidated or weakly consolidated sandstones. This in turn increases or decreases the effective stresses and changes the elastic properties of the rocks. Thermally enhanced recovery processes give rise to complex couplings. Numerical simulations have been carried out on a case study so as to provide an estimation of the evolution of pressure, temperature, pore fluid saturation, stress and strain in any zone located around the injector and producer wells. The approach of Ciz and Shapiro (2007) - an extension of the poroelastic theory of Biot-Gassmann applied to rock filled elastic material - has been used to model the velocity dispersion in the oil sand mass under different conditions of temperature and stress. A good agreement has been found between these pre...

Nauroy, Jean-François; Guy, N; Baroni, Axelle; Delage, Pierre; Mainguy, Marc; 10.2516/ogst/2012027

2013-01-01T23:59:59.000Z

375

American Recovery and Reinvestment Act of 2009: Bioenergy Technologies...  

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

Recovery and Reinvestment Act of 2009 funds; the projects accelerate advanced biofuels RD&D, speed the deployment of commercialization of biofuels, and further the U.S....

376

Develop Thermoelectric Technology for Automotive Waste Heat Recovery...  

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

for Automotive Waste Heat Recovery Cost-Competitive Advanced Thermoelectric Generators for Direct Conversion of Vehicle Waste Heat into Useful Electrical Power Development...

377

Develop Thermoelectric Technology for Automotive Waste Heat Recovery...  

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

Waste Heat Recovery Engineering and Materials for Automotive Thermoelectric Applications Electrical and Thermal Transport Optimization of High Efficient n-type Skutterudites...

378

Development of Thermoelectric Technology for Automotive Waste Heat Recovery  

Broader source: Energy.gov [DOE]

Overview and status of project to develop thermoelectric generator for automotive waste heat recovery and achieve at least 10% fuel economy improvement.

379

In situ generation of steam and alkaline surfactant for enhanced oil recovery using an exothermic water reactant (EWR)  

DOE Patents [OSTI]

A method for oil recovery whereby an exothermic water reactant (EWR) encapsulated in a water soluble coating is placed in water and pumped into one or more oil wells in contact with an oil bearing formation. After the water carries the EWR to the bottom of the injection well, the water soluble coating dissolves and the EWR reacts with the water to produce heat, an alkali solution, and hydrogen. The heat from the EWR reaction generates steam, which is forced into the oil bearing formation where it condenses and transfers heat to the oil, elevating its temperature and decreasing the viscosity of the oil. The aqueous alkali solution mixes with the oil in the oil bearing formation and forms a surfactant that reduces the interfacial tension between the oil and water. The hydrogen may be used to react with the oil at these elevated temperatures to form lighter molecules, thus upgrading to a certain extent the oil in situ. As a result, the oil can flow more efficiently and easily through the oil bearing formation towards and into one or more production wells.

Robertson, Eric P

2011-05-24T23:59:59.000Z

380

Quantitative Methods for Reservoir Characterization and Improved Recovery: Application to Heavy Oil Sands  

SciTech Connect (OSTI)

This project involved application of advanced analytical property-distribution methods conditioned to continuous outcrop control for improved reservoir characterization and simulation. The investigation was performed in collaboration with Chevron Production Company U.S.A. as an industrial partner, and incorporates data from the Temblor Formation in Chevron's West Coalinga Field, California. Improved prediction of interwell reservoir heterogeneity was needed to increase productivity and to reduce recovery cost for California's heavy oil sands, which contained approximately 2.3 billion barrels of remaining reserves in the Temblor Formation and in other formations of the San Joaquin Valley.

Castle, James W.; Molz, Fred W.; Bridges, Robert A.; Dinwiddie, Cynthia L.; Lorinovich, Caitlin J.; Lu, Silong

2003-02-07T23:59:59.000Z

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


381

Technical constraints limiting application of enhanced oil recovery techniques to petroleum production in the United States  

SciTech Connect (OSTI)

A critical examination of the potential and the technical constraint that inhibit the application of enhanced oil recovery techniques in the United States has been initiated and is expected to continue. The examination is based on the results of extensive laboratory and field applications now underway under various forms of Department of Energy support. This interim report will be amplified as data become available and as progress is made toward resolving technical constraints. Comments on the approach and substance of the information contained herein are welcome.

Not Available

1980-05-01T23:59:59.000Z

382

NETL: Oil & Natural Gas Technologies Reference Shelf - Presentation on  

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

Decreasing Air Emission Impacts From Oil and Gas Development Decreasing Air Emission Impacts From Oil and Gas Development Decreasing Air Emission Impacts From Oil and Gas Development Authors: Charles B. McComas, PE; J. Daniel Arthur, PE; Gerry Baker; G. Lee Moody; and David B. Cornue, PG, CHMM Venue: American Chemical Society (53rd Pentasectional Meeting) – Halliburton Energy Services Technology Center, Duncan, OK, March 8, 2008 (http://www.acs.org [external site]) Abstract: Research funded by the United States Department of Energy’s National Energy Technology Laboratory and conducted under the direction of the Interstate Oil and Gas Compact Commission has examined concerns related to air emissions resulting from domestic onshore oil and gas exploration and production operations. Current air issues such as ambient air quality standards and non-attainment areas, regulatory compliance and regional inconsistencies, as well as global climate change and carbon sequestration are a few of the subjects perceived to represent potential barriers to energy development. The topic of air quality and how it relates to onshore oil and gas exploration and production activities is examined from the position of environmental sustainability. These concerns can be addressed through reasonable and prudent practices that industry may implement in order to avoid, minimize, or mitigate air emissions. Additionally, air emissions parameters that are not currently regulated (e.g.: CH4 and CO2) may become the subject of increased concern in the future and, therefore, add to the list of issues facing oil and gas exploration and production. Suggestions for further research opportunities with the potential to benefit responsible energy resource development are also presented.

383

Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) 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 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 existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation. Summary of Technical Progress

Scott Hara

1997-08-08T23:59:59.000Z

384

Increasing Heavy Oil Reserves in the Wilmington Oil Field Through Advanced Reservoir Characterization and Thermal Production Technologies  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) 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 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 existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Scott Hara

1998-03-03T23:59:59.000Z

385

Increasing Heavy Oil Reservers in the Wilmington Oil field Through Advanced Reservoir Characterization and Thermal Production Technologies  

SciTech Connect (OSTI)

The project involves improving thermal recovery techniques in a slope and basin clastic (SBC) reservoir in the Wilmington field, Los Angeles Co., Calif. using advanced reservoir characterization and thermal production technologies. The existing steamflood in the Tar zone of Fault Block (FB) 11-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 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 existing steam drive area to improve thermal efficiency. (7) Installing a 2100 foot insulated, subsurface harbor channel crossing to supply steam to an island location. (8) Test a novel alkaline steam completion technique to control well sanding problems and fluid entry profiles. (9) Advanced reservoir management through computer-aided access to production and geologic data to integrate reservoir characterization, engineering, monitoring, and evaluation.

Hara, Scott [Tidelands Oil Production Co., Long Beach, CA (United States)

1997-05-05T23:59:59.000Z

386

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

SciTech Connect (OSTI)

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 geomechanical characteristics of the producing formations. The objectives were to further improve reservoir characterization of the heterogeneous turbidite sands, test the proficiency of the three-dimensional geologic and thermal reservoir simulation models, identify the high permeability thief zones to reduce water breakthrough and cycling, and analyze the nonuniform distribution of the remaining oil in place. This work resulted in the redevelopment of the Tar II-A and Tar V post-steamflood projects by drilling several new wells and converting idle wells to improve injection sweep efficiency and more effectively drain the remaining oil reserves. Reservoir management work included reducing water cuts, maintaining or increasing oil production, and evaluating and minimizing further thermal-related formation compaction. The BP2 project utilized all the tools and knowledge gained throughout the DOE project to maximize recovery of the oil in place.

Scott Hara

2007-03-31T23:59:59.000Z

387

Effect of well pattern and injection well type on the CO2-assisted gravity drainage enhanced oil recovery  

Science Journals Connector (OSTI)

Fundamental understanding and application of process parameters in numerical simulation that leads to optimized gravity drainage oil recovery at field scale is still a major challenge. Reservoir simulations studying the effects of well patterns and type of gas injection wells have not been reported so far. In first ever attempt, the mechanistic benefits of production strategy on gravity drainage oil recovery are identified in this paper. Effects of irregular and regular well patterns and vertical and horizontal gas injection wells are investigated using a fully compositional 3D reservoir model in secondary immiscible and miscible modes under the conditions of voidage balance, constant pressure of injection and production wells and injection rates below the critical rate. Regular well pattern provided longer oil production time at a constant rate until CO2 breakthrough compared to irregular well pattern. It then dropped almost vertically at the same cumulative oil recovery even at higher production rates. However, gravity drainage oil recovery was higher at higher rate combination after CO2 breakthrough. Results also suggested that the regular pattern could result in horizontal CO2 floodfront parallel to the horizontal producers, maintaining reservoir pressure, thus optimizing the oil recovery by additional 2.5% OOIP. Vertical injection and horizontal production wells in both the immiscible and miscible modes provided nearly identical cumulative gravity drainage oil recovery compared to the combination of horizontal injection and production wells in the regular well pattern. This suggests that the type of injection wells may not be a significant factor to impact the CO2-assisted gravity drainage mechanism. Results obtained herein would help in the optimization of CO2-assisted gravity drainage EOR process.

P.S. Jadhawar; H.K. Sarma

2012-01-01T23:59:59.000Z

388

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

SciTech Connect (OSTI)

Gelation technologies have been developed to provide more efficient vertical sweep efficiencies for flooding naturally fractured oil reservoirs or reservoirs with different sand lenses with high permeability contrast. The field proven alkaline-surfactant-polymer technology economically recovers 15% to 25% OOIP more crude oil than waterflooding from swept pore space of an oil reservoir. However, alkaline-surfactant-polymer technology is not amenable to naturally fractured reservoirs or reservoirs with high permeability contrast 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. Fluid-fluid interaction with different gel chemical compositions and alkaline-surfactant-polymer solution with pH values ranging from 9.2 to 12.9 have been tested. Aluminum-polyacrylamide gels are not stable to alkaline-surfactant-polymer solutions at any pH. Chromium-polyacrylamide gels with polymer to chromium ion ratios of 25 or greater were stable to alkaline-surfactant-polymer solutions if solution pH was 10.6 or less. When the polymer to chromium ion was 15 or less, chromium-polyacrylamide gels were stable to alkaline-surfactant-polymer solutions with pH values up to 12.9. Chromium-xanthan gum gels were stable to alkaline-surfactant-polymer solutions with pH values of 12.9 at the polymer to chromium ion ratios tested. Silicate-polyacrylamide, resorcinol-formaldehyde, and sulfomethylated resorcinol-formaldehyde gels were also stable to alkaline-surfactant-polymer solutions with pH values ranging from 9.2 to 12.9. Iron-polyacrylamide gels were immediately destroyed when contacted with any of the alkaline-surfactant-polymer solutions with pH values ranging from 9.2 to 12.9. Gel solutions under dynamic conditions of linear corefloods showed similar stability to alkaline-surfactant-polymer solutions as in the fluid-fluid analyses with the exception of the xanthan gum-chromium acetate gels. Aluminum-polyacrylamide flowing gels are not stable to alkaline-surfactant-polymer solutions of either pH 10.5 or 12.9, either in linear corefloods or in dual separate radial core, common manifold corefloods. Chromium acetate-polyacrylamide flowing and rigid tonguing gels are stable to subsequent alkaline-surfactant-polymer solution injection. Rigid tonguing chromium acetate-polyacrylamide gels maintained permeability reduction better than flowing chromium acetate-polyacrylamide gels. Chromium acetate gels were stable to injection of alkaline-surfactant-polymer solutions at 72 F, 125 F and 175 F in linear corefloods. Chromium acetate-polyacrylamide gels maintained diversion capability after injection of an alkaline-surfactant-polymer solution in stacked; radial coreflood with a common well bore. Chromium acetate-polyacrylamide gel used to seal fractured core maintain fracture closure if followed by an alkaline-surfactant-polymer solution. Chromium acetatexanthan gum rigid gels are not stable to subsequent alkaline-surfactant-polymer solution injection at 72, 125, and 175 F. Silicate-polyacrylamide gels are not stable with subsequent injection of either a pH 10.5 or a 12.9 alkaline-surfactant-polymer solution. 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 alkaline-surfactant-polymer injected solution were observed. Aluminum citrate-polyacrylamide, resorcinol-formaldehyde, and the silicate-polyacrylamide gel systems did not produce significant incremental oil in linear corefloods. Both flowing and rigid tonguing chromium acetate-polyacrylamide gels and the xanthan gum-chromium acetate gel system produced incremental oil with the rigid tonguing gel producing the greatest amount. Higher oil recovery could have been due to higher differential

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

2005-12-01T23:59:59.000Z

389

INCREASED OIL RECOVERY FROM MATURE OIL FIELDS USING GELLED POLYMER TREATMENTS  

SciTech Connect (OSTI)

Gelled polymer treatments are applied to oil reservoirs to increase oil production and to reduce water production by altering the fluid movement within the reservoir. This report describes the results of a three-year research program 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. The work focused on the gel system composed of polyacrylamide and chromium acetate. The molar mass of the polymer was about six million. Chromium(III) acetate reacted and formed crosslinks between polymer molecules. The crosslinked polymer molecules, or pre-gel aggregates, combine and grow to eventually form a 3-dimensional gel. A fundamental study to characterize the formation and growth of pre-gel aggregates was conducted. Two methods, flow field-flow fractionation (FFFF) and multi-angle laser light scattering (MALLS) were used. Studies using FFFF were inconclusive. Data taken using MALLS showed that at the gel time the average molar mass of gel aggregates increased by a factor of about three while the average size increase was approximately 50%. Increased acetate concentration in the gelant increases the gel time. The in situ performance of an added-acetate system was investigated to determine the applicability for in-depth treatments. Increased acetate concentrations delayed the development of increased flow resistance during gelant injection in short sandpacks. The development of increased flow resistance (in situ gelation) was extended from 2 to 34 days by increasing the acetate-to-chromium ratio from 38 to 153. In situ gelation occurred at a time that was approximately 22% of the bulk gelation time. When carbonate rocks are treated with gel, chromium retention in the rock may limit in-depth treatment. Chromium retention due to precipitation was investigated by flowing chromium acetate solutions through carbonate rock. Chromium precipitated faster in the rocks than in beaker experiments at similar conditions. A mathematical model previously developed fit the precipitation data reasonably well. The stability of gels when subjected to stress was investigated by experiments with gels placed in tubes and in laboratory-scale fractures. Rupture pressures for gels placed in small diameter tubes were correlated with the ratio of tube length to tube ID. In fractures, fluid leakoff from the fracture to adjacent matrix rock affected gel formation and gel stability in a positive way. Disproportionate permeability reduction (DPR) was studied in unconsolidated sandpacks and in Berea sandstone cores. A conceptual model was developed to explain the presence of DPR. The effect of a pressure gradient, imposed by injection of oil or brine, on the permeability of gel-treated cores was investigated. DPR increased significantly as the pressure gradient was decreased. The magnitude of the pressure gradient had a much larger effect on water permeability than on oil permeability.

G.P. Willhite; D.W. Green; C.S. McCool

2003-05-01T23:59:59.000Z

390

Characterization and Alteration of Wettability States of Alaskan Reserviors to Improve Oil Recovery Efficiency (including the within-scope expansion based on Cyclic Water Injection - a pulsed waterflood for Enhanced Oil Recovery)  

SciTech Connect (OSTI)

Numerous early reports on experimental works relating to the role of wettability in various aspects of oil recovery have been published. Early examples of laboratory waterfloods show oil recovery increasing with increasing water-wetness. This result is consistent with the intuitive notion that strong wetting preference of the rock for water and associated strong capillary-imbibition forces gives the most efficient oil displacement. This report examines the effect of wettability on waterflooding and gasflooding processes respectively. Waterflood oil recoveries were examined for the dual cases of uniform and non-uniform wetting conditions. Based on the results of the literature review on effect of wettability and oil recovery, coreflooding experiments were designed to examine the effect of changing water chemistry (salinity) on residual oil saturation. Numerous corefloods were conducted on reservoir rock material from representative formations on the Alaska North Slope (ANS). The corefloods consisted of injecting water (reservoir water and ultra low-salinity ANS lake water) of different salinities in secondary as well as tertiary mode. Additionally, complete reservoir condition corefloods were also conducted using live oil. In all the tests, wettability indices, residual oil saturation, and oil recovery were measured. All results consistently lead to one conclusion; that is, a decrease in injection water salinity causes a reduction in residual oil saturation and a slight increase in water-wetness, both of which are comparable with literature observations. These observations have an intuitive appeal in that water easily imbibes into the core and displaces oil. Therefore, low-salinity waterfloods have the potential for improved oil recovery in the secondary recovery process, and ultra low-salinity ANS lake water is an attractive source of injection water or a source for diluting the high-salinity reservoir water. As part of the within-scope expansion of this project, cyclic water injection tests using high as well as low salinity were also conducted on several representative ANS core samples. These results indicate that less pore volume of water is required to recover the same amount of oil as compared with continuous water injection. Additionally, in cyclic water injection, oil is produced even during the idle time of water injection. It is understood that the injected brine front spreads/smears through the pores and displaces oil out uniformly rather than viscous fingering. The overall benefits of this project include increased oil production from existing Alaskan reservoirs. This conclusion is based on the performed experiments and results obtained on low-salinity water injection (including ANS lake water), vis-a-vis slightly altering the wetting conditions. Similarly, encouraging cyclic water-injection test results indicate that this method can help achieve residual oil saturation earlier than continuous water injection. If proved in field, this would be of great use, as more oil can be recovered through cyclic water injection for the same amount of water injected.

Abhijit Dandekar; Shirish Patil; Santanu Khataniar

2008-12-31T23:59:59.000Z

391

Use of amine oxide surfactants for chemical flooding EOR (enhanced oil recovery)  

SciTech Connect (OSTI)

The use of amine oxides with and without alcohols as cosolvents, and in combination with other surfactants as mixed micellar formulations for enhanced oil recovery by surfactant flooding was investigated. Amine oxides are a salt-tolerant class of surfactants that produce low interfacial tension and can develop viscosity without the addition of polymers. These salt-tolerant formulations generate three-phase regions with hydrocarbons over a broad salinity range, develop moderate solubilization, and produce low interfacial tensions, however oil recovery from amine oxide-alcohol phase behavior optimized formulations was directly dependent upon the quantity of surfactant injected. The large pore volume and high concentration of surfactant required prohibits their economic use as the primary surfactant in chemical flooding EOR. Dimethylalkylamine oxides are useful as cosurfactants and viscosifiers in formulations with other surfactants for chemical flooding EOR but the use of ethoxylated and propoxylated amine oxides should be avoided due to the decomposition of these amine oxides under reservoir conditions. Phase behavior, phase inversion temperatures, and viscosity scans have been correlated with surfactant structures to provide a guide for amine oxide applications in chemical flooding. 36 refs., 5 figs., 6 tabs.

Olsen, D.K.

1989-11-01T23:59:59.000Z

392

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

SciTech Connect (OSTI)

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.

Scott Hara

2001-05-07T23:59:59.000Z

393

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

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman; James J. Justice

2001-06-16T23:59:59.000Z

394

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

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman; James J. Justice

2001-08-10T23:59:59.000Z

395

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

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

Raj Kumar; Keith Brown; T. Scott Hickman; James J. Justice

2000-04-27T23:59:59.000Z

396

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

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman; James J. Justice

2001-12-11T23:59:59.000Z

397

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

SciTech Connect (OSTI)

The Class 2 Project at West Welch was designed to demonstrate the use of advanced technologies to enhance the economics of improved oil recovery (IOR) projects in lower quality Shallow Shelf Carbonate (SSC) reservoirs, resulting in recovery of additional oil that would otherwise be left in the reservoir at project abandonment. Accurate reservoir description is critical to the effective evaluation and efficient design of IOR projects in the heterogeneous SSC reservoirs. Therefore, the majority of Budget Period 1 was devoted to reservoir characterization. Technologies being demonstrated include: (1) Advanced petrophysics; (2) Three-dimensional (3-D) seismic; (3) Crosswell bore tomography; (4) Advanced reservoir simulation; (5) Carbon dioxide (CO{sub 2}) stimulation treatments; (6) Hydraulic fracturing design and monitoring; and (7) Mobility control agents.

T. Scott Hickman

2003-01-17T23:59:59.000Z

398

Teapot Dome: Site Characterization of a CO2- Enhanced Oil Recovery Site in Eastern Wyoming  

SciTech Connect (OSTI)

Naval Petroleum Reserve No. 3 (NPR-3), better known as the Teapot Dome oil field, is the last U.S. federally-owned and -operated oil field. This provides a unique opportunity for experiments to provide scientific and technical insight into CO{sub 2}-enhanced oil recovery (EOR) and other topics involving subsurface fluid behavior. Towards that end, a combination of federal, academic, and industrial support has produced outstanding characterizations of important oil- and brine-bearing reservoirs there. This effort provides an unparalleled opportunity for industry and others to use the site. Data sets include geological, geophysical, geochemical, geomechanical, and operational data over a wide range of geological boundary conditions. Importantly, these data, many in digital form, are available in the public domain due to NPR-3's federal status. Many institutions are already using portions of the Teapot Dome data set as the basis for a variety of geoscience, modeling, and other research efforts. Fifteen units, 9 oil-bearing and 6 brine-bearing, have been studied to varying degrees. Over 1200 wells in the field are active or accessible, and over 400 of these penetrate 11 formations located below the depth that corresponds to the supercritical point for CO{sub 2}. Studies include siliciclastic and carbonate reservoirs; shale, carbonate, and anhydrite cap rocks; fractured and unfractured units; and over-pressured and under-pressured zones. Geophysical data include 3D seismic and vertical seismic profiles. Reservoir data include stratigraphic, sedimentological, petrologic, petrographic, porosity, and permeability data. These have served as the basis for preliminary 3D flow simulations. Geomechanical data include fractures (natural and drilling induced), in-situ stress determination, pressure, and production history. Geochemical data include soil gas, noble gas, organic, and other measures. The conditions of these reservoirs directly or indirectly represent many reservoirs in the U.S., Canada, and overseas.

Friedmann, S J; Stamp, V

2005-11-01T23:59:59.000Z

399

Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 71, quarter ending June 30, 1992  

SciTech Connect (OSTI)

Progress reports are presented for the following tasks: chemical flooding--supporting research; gas displacement--supporting research; thermal recovery--supporting research; geoscience technology; resource assessment technology; microbial technology; and novel technology. A list of available publication is also provided.

Not Available

1993-06-01T23:59:59.000Z

400

Vehicle Technologies Office: Fact #742: August 27, 2012 Oil Price and  

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

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401

Vehicle Technologies Office: Fact #334: August 23, 2004 China Is #2 in Oil  

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

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402

Using Biosurfactants Produced from Agriculture Process Waste Streams to Improve Oil Recovery in Fractured Carbonate Reservoirs  

SciTech Connect (OSTI)

This report describes the progress of our research during the first 30 months (10/01/2004 to 03/31/2007) of the original three-year project cycle. The project was terminated early due to DOE budget cuts. This was a joint project between the Tertiary Oil Recovery Project (TORP) at the University of Kansas and the Idaho National Laboratory (INL). The objective was to evaluate the use of low-cost biosurfactants produced from agriculture process waste streams to improve oil recovery in fractured carbonate reservoirs through wettability mediation. Biosurfactant for this project was produced using Bacillus subtilis 21332 and purified potato starch as the growth medium. The INL team produced the biosurfactant and characterized it as surfactin. INL supplied surfactin as required for the tests at KU as well as providing other microbiological services. Interfacial tension (IFT) between Soltrol 130 and both potential benchmark chemical surfactants and crude surfactin was measured over a range of concentrations. The performance of the crude surfactin preparation in reducing IFT was greater than any of the synthetic compounds throughout the concentration range studied but at low concentrations, sodium laureth sulfate (SLS) was closest to the surfactin, and was used as the benchmark in subsequent studies. Core characterization was carried out using both traditional flooding techniques to find porosity and permeability; and NMR/MRI to image cores and identify pore architecture and degree of heterogeneity. A cleaning regime was identified and developed to remove organic materials from cores and crushed carbonate rock. This allowed cores to be fully characterized and returned to a reproducible wettability state when coupled with a crude-oil aging regime. Rapid wettability assessments for crushed matrix material were developed, and used to inform slower Amott wettability tests. Initial static absorption experiments exposed limitations in the use of HPLC and TOC to determine surfactant concentrations. To reliably quantify both benchmark surfactants and surfactin, a surfactant ion-selective electrode was used as an indicator in the potentiometric titration of the anionic surfactants with Hyamine 1622. The wettability change mediated by dilute solutions of a commercial preparation of SLS (STEOL CS-330) and surfactin was assessed using two-phase separation, and water flotation techniques; and surfactant loss due to retention and adsorption on the rock was determined. Qualitative tests indicated that on a molar basis, surfactin is more effective than STEOL CS-330 in altering wettability of crushed Lansing-Kansas City carbonates from oil-wet to water-wet state. Adsorption isotherms of STEOL CS-330 and surfactin on crushed Lansing-Kansas City outcrop and reservoir material showed that surfactin has higher specific adsorption on these oomoldic carbonates. Amott wettability studies confirmed that cleaned cores are mixed-wet, and that the aging procedure renders them oil-wet. Tests of aged cores with no initial water saturation resulted in very little spontaneous oil production, suggesting that water-wet pathways into the matrix are required for wettability change to occur. Further investigation of spontaneous imbibition and forced imbibition of water and surfactant solutions into LKC cores under a variety of conditions--cleaned vs. crude oil-aged; oil saturated vs. initial water saturation; flooded with surfactant vs. not flooded--indicated that in water-wet or intermediate wet cores, sodium laureth sulfate is more effective at enhancing spontaneous imbibition through wettability change. However, in more oil-wet systems, surfactin at the same concentration performs significantly better.

Stephen Johnson; Mehdi Salehi; Karl Eisert; Sandra Fox

2009-01-07T23:59:59.000Z

403

Enhanced-oil-recovery thermal processes, annex IV. Venezuela-MEM/USA-DOE fossil-energy report IV-1  

SciTech Connect (OSTI)

The Agreement between the United States and Venezuela was designed to further energy research and development in six areas. This report focuses on Annex IV - Enhanced-Oil-Recovery Thermal Processes which was divided into seven tasks. This report will discuss the information developed within Task I related to the Department of Energy providing data on the performance of insulated oil-well tubulars. Surface generated steam has been traditionally used in thermal enhanced oil recovery processes. In past years the tubing through which the steam is injected into the reservoir has been bare with relatively high heat losses. In recent years however various materials and designs for insulating the tubing to reduce heat losses have been developed. Evaluation of several of these designs in an instrumented test tower and in an oil field test environment was undertaken. These tests and the resulting data are presented.

Peterson, G.; Schwartz, E.

1983-04-01T23:59:59.000Z

404

Technology on In-Situ Gas Generation to Recover Residual Oil Reserves  

SciTech Connect (OSTI)

This final technical report covers the period October 1, 1995 to February 29, 2008. This chapter begins with an overview of the history of Enhanced Oil Recovery techniques and specifically, CO2 flood. Subsequent chapters conform to the manner consistent with the Activities, Tasks, and Sub-tasks of the project as originally provided in Exhibit C1 in the Project Management Plan dated September 20, 1995. These chapters summarize the objectives, status and conclusions of the major project activities performed during the project period. The report concludes by describing technology transfer activities stemming from the project and providing a reference list of all publications of original research work generated by the project team or by others regarding this project. The overall objective of this project was a final research and development in the United States a technology that was developed at the Institute for Geology and Development of Fossil Fuels in Moscow, Russia. Before the technology can be convincingly adopted by United States oil and gas producers, the laboratory research was conducted at Mew Mexico Institute of Mining and Technology. The experimental studies were conducted to measure the volume and the pressure of the CO{sub 2} gas generated according to the new Russian technology. Two experimental devices were designed, built and used at New Mexico Tech facilities for these purposes. The designed setup allowed initiating and controlling the reaction between the 'gas-yielding' (GY) and 'gas-forming' (GF) agents proposed by Russian technology. The temperature was controlled, and the generated gas pressure and volume were recorded during the reaction process. Additionally, the effect of surfactant addition on the effectiveness of the process was studied. An alternative GY reactant was tested in order to increase the efficiency of the CO2 gas generation process. The slim tube and the core flood experimental studies were conducted to define the sweep efficiency of the in-situ generated CO{sub 2} gas. A set of core flood experiments were conducted to define effect of surfactant on recovery efficiency. The results demonstrated obvious advantages of the foamy system over the brine solution in order to achieve higher sweep efficiency and recovery coefficient. It is shown that a slug injection is not an efficient method for mixing GY and GF solutions and it can't generate considerable gas inside the slim-tube.

Sayavur Bakhtiyarov

2008-02-29T23:59:59.000Z

405

Vehicle Technologies Office: Materials for Energy Recovery Systems...  

Energy Savers [EERE]

penalties associated with many emission control technologies. These technologies include diesel particulate filters, catalysts, filter substrates, and exhaust-gas recirculation...

406

Evaluation of Low-Salinity Enhanced Oil Recovery Effects in Sandstone: Effects of the Temperature and pH Gradient  

Science Journals Connector (OSTI)

Evaluation of Low-Salinity Enhanced Oil Recovery Effects in Sandstone: Effects of the Temperature and pH Gradient ... (1-4) It was very interesting to see that the model compound, quinoline, and an asphaltenic crude oil responded similarly regarding adsorption/desorption from clays at different salinities and pH values. ... (3) Can the slopes of the pH gradients give information about the rate of desorption and adsorption of cations? ...

Hakan Aksulu; Dagny Hĺmsř; Skule Strand; Tina Puntervold; Tor Austad

2012-04-24T23:59:59.000Z

407

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

SciTech Connect (OSTI)

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 complete well A-605 in Tar V in the first quarter 2003. Plans have been approved to update the Tar II-A 3-D deterministic reservoir simulation model and run sensitivity cases to evaluate the accelerated oil recovery and reservoir cooling plan. 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. Well work related to the Tar II-A accelerated oil recovery and reservoir cooling plan began in March 2002 with oil production increasing from 1009 BOPD in the first quarter to 1145 BOPD in the third quarter. Reservoir pressures have been increased during the quarter from 88% to 91% hydrostatic levels in the ''T'' sands and from 91% to 94% hydrostatic levels in the ''D'' sands. Well work during the quarter is described in the Reservoir Management section. The post-steamflood production performance in the Tar V pilot project has been below projections because of wellbore mechanical limitations and the loss of a horizontal producer a second time to sand inflow that are being addressed in the fourth quarter. As the fluid production temperatures exceeded 350 F, our self-imposed temperature limit, the pilot steamflood was converted to a hot waterflood project in June 2001 and converted to cold water injection on April 19, 2002.

Scott Hara

2002-11-08T23:59:59.000Z

408

Demonstrated Petroleum Reduction Using Oil Bypass Filter Technology on Heavy and Light Vehicles  

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

Demonstrated Petroleum Demonstrated Petroleum Reduction Using Oil Bypass Filter Technology on Heavy and Light Vehicles James Francfort (PI) Timothy Murphy Larry Zirker Oil Bypass Filter Technology Evaluation * Funded by the U.S. Department of Energy's FreedomCAR & Vehicle Technologies Program * Performed by Idaho National Engineering and Environmental Laboratory (INEEL) Fleet Operations * Goal - Support DOE's efforts to reduce petroleum consumption & ensure the energy security of the United States Oil Bypass Filter Technology Evaluation * Objectives - Test the concept of using oil bypass filters to minimize engine oil changes & the generation of waste oils - Demonstration the economics of oil bypass filter systems - Estimate potential engine oil saving from bypass filter technologies that can be achieved by INEEL,

409

Optimization of experimental conditions for recovery of coking coal fines by oil agglomeration technique  

Science Journals Connector (OSTI)

The significance of coking coal in the metallurgical sector as well as the meager coking coal reserves across the globe increase the necessity to recover coking coal fines from the fine coking coal slurries generated from coal preparation and utilization activities. Oil agglomeration studies were carried out by varying the experimental conditions for maximum recovery of coking coal fines i.e., yield of the agglomerates. The various operational parameters studied were oil dosage, agitation speed, agglomeration time and pulp density. By using Taguchi experimental design, oil dosage (20%), agitation speed (1100 rpm), agglomeration time (3 min) and pulp density (4.5%) were identified as the optimized conditions. A confirmation experiment has also been carried out at the optimized conditions. The percentage contribution of each parameter on agglomerate yield was analyzed by adopting analysis of variance (ANOVA) statistical method as well as multiple linear regression analysis. The order of influence of the parameters on the agglomerate yield is of the following order: pulp density > oil dosage > agitation speed > agglomeration time. A mathematical model was developed to fit the set of experimental conditions with the yield obtained at each test run and also at the optimized conditions. The experimentally obtained yield was compared with the predicted yield of the model and the results indicate a maximum error of 5% between the two. A maximum yield of 90.42% predicted at the optimized conditions appeared to be in close agreement with the experimental yield thus indicating the accuracy of the model in predicting the results.

G.H.V.C. Chary; M.G. Dastidar

2010-01-01T23:59:59.000Z

410

The effect of flooding velocity and degree of reservoir depletion on the recovery of oil by water flooding  

E-Print Network [OSTI]

the kerosene until the pressure in the reservoir oil sturage cylinder reached approximately the desired bubble point. The fluids were then circulated until the pressure stabilized at the bubble point at which time the excess gas was dis placed..., 1951) 15, 7 Z9. Guerrero, E. T. and Kennedy, H. T. : Effect of Surface and Interfacial Tension on Recovery of Oil by Water Flooding, " Transactions AIME, (1954) 201, 124. 30. Holmgren, C. R. and Morse, R. A, : "Effect of Free Gas Saturation on Oil...

Hall, Phillips C

2012-06-07T23:59:59.000Z

411

Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and  

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

5: November 12, 5: November 12, 2007 Oil Price and Economic Growth, 1971-2006 to someone by E-mail Share Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and Economic Growth, 1971-2006 on Facebook Tweet about Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and Economic Growth, 1971-2006 on Twitter Bookmark Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and Economic Growth, 1971-2006 on Google Bookmark Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and Economic Growth, 1971-2006 on Delicious Rank Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and Economic Growth, 1971-2006 on Digg Find More places to share Vehicle Technologies Office: Fact #495: November 12, 2007 Oil Price and Economic Growth, 1971-2006 on

412

Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil  

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

2: December 6, 2: December 6, 2010 U.S. Crude Oil Production Rises to someone by E-mail Share Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil Production Rises on Facebook Tweet about Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil Production Rises on Twitter Bookmark Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil Production Rises on Google Bookmark Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil Production Rises on Delicious Rank Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil Production Rises on Digg Find More places to share Vehicle Technologies Office: Fact #652: December 6, 2010 U.S. Crude Oil Production Rises on AddThis.com... Fact #652: December 6, 2010

413

Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas, Near-term. Third quarterly report, January 1, 1994--April 1, 1994  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Cherokee Group reservoirs in southeastern Kansas and in Morrow sandstone reservoirs in southwestern Kansas. Two demonstration sites operated by different independent oil operators are involved in the project. The Nelson Lease (an existing waterflood) is located in Allen County, Kansas in the N.E. Savonburg Field. The Stewart Field is located in Finney County, Kansas. General topics to be addressed will be (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. The reservoir management portion of the project will involve performance evaluation and will include such work as (1) reservoir characterization and the development of a reservoir database, (2) identification of operational problems, (3) identification of near wellbore problems, (4) identification of unrecovered mobile oil and estimation of recovery factors, and (5) identification of the most efficient and economical recovery process. The waterflood optimization portion of the project involves only the Nelson Lease. It will be based on the performance evaluation and will involve (1) design and implementation of a water cleanup system for the waterflood, (2) application of well remedial work such as polymer gel treatments to improve vertical sweep efficiency, and (3) changes in waterflood patterns to increase sweep efficiency. Finally, it is planned to implement an improved recovery process, possibly polymer augmented waterflooding on both field demonstration sites. Progress reports are presented for the following tasks: engineering and geological analysis; water plant development; pattern changes and wellbore cleanup; field operations; laboratory testing; and utilization.

Green, D.W.; Willhite, G.P.; Walton, A.; Schoeling, L.; Reynolds, R.; Michnick, M.; Watney, L.

1994-04-15T23:59:59.000Z

414

Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas -- near-term. Eighth quarterly report, April 1, 1995--June 30, 1995  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Cherokee Group reservoirs in southeastern Kansas and in Morrow sandstone reservoirs in southwestern Kansas. Two demonstration sites operated by different independent oil operators are involved in the project. The Nelson Lease (an existing waterflood) is located in Allen County, Kansas in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. The Stewart Field (on latter stage of primary production) is located in Finney County, Kansas and is operated by North American Resources Company General topics to be addressed will be (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration, of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. The reservoir management portion of the project will involve performance evaluation and will include such work as (1) reservoir characterization and the development of a reservoir database, (2) identification of operational problems, (3) identification of near wellbore problems, (4) identification of unrecovered mobile oil and estimation of recovery factors, and 5) identification of the most efficient and economical recovery process. The waterflood optimization portion of the project involves only the Nelson Lease. It will be based on the performance evaluation and will involve (1) design and implementation of a water cleanup system for the waterflood, (2) application of well remedial work such as polymer gel treatments to improve vertical sweep efficiency, and (3) changes in waterflood patterns to increase sweep efficiency. Finally, it is planned to implement an improved recovery process on both field demonstration sites.

Green, D.W.; Willhite, G.P.; Walton, A.; Schoeling, L.; Reynolds, R.; Michnick, M.; Watney, L.

1995-07-15T23:59:59.000Z

415

Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas -- near-term. Seventh quarterly report, February 1, 1995--April 1, 1995  

SciTech Connect (OSTI)

The objective of this project is to address waterflood problems of the type found in Cherokee Group reservoirs in southeastern Kansas and in Morrow sandstone reservoirs in southwestern Kansas. Two demonstration sites operated by different independent oil operators are involved in the project. The Nelson Lease (an existing waterflood) is located in Allen County, Kansas in the N.E. Savonburg Field and is operated by James E. Russell Petroleum, Inc. The Stewart Field (on latter stage of primary production) is located in Finney County, Kansas and is operated by Sharon Resources, Inc. General topics to be addressed will be (1) reservoir management and performance evaluation, (2) waterflood optimization, and (3) the demonstration of recovery processes involving off-the-shelf technologies which can be used to enhance waterflood recovery, increase reserves, and reduce the abandonment rate of these reservoir types. The reservoir management portion of the project will involve performance evaluation and will include such work as (1) reservoir characterization and the development of a reservoir database, (2) identification of operational problems, (3) identification of near wellbore problems, (4) identification of unrecovered mobile oil and estimation of recovery factors, and (5) identification of the most efficient and economical recovery process. The waterflood optimization portion of the project involves only the Nelson Lease. It will be based on the performance evaluation and will involve (1) design and implementation of a water cleanup system for the waterflood, (2) application of well remedial work such as polymer gel treatments to improve vertical sweep efficiency, and (3) changes in waterflood patterns to increase sweep efficiency. Finally, it is planned to implement an improved recovery process, possibly polymer augmented waterflood: on both field demonstration sites.

Green, D.W.; Willhite, G.P.; Walton, A.; Schoeling, L.; Reynolds, R.; Michnick, M.; Watney, L.

1995-04-15T23:59:59.000Z

416

Enhanced oil recovery for thermal processes. First amendment and extension to Annex IV  

SciTech Connect (OSTI)

This report contains the result of efforts under the several tasks of the First Amendment and Extension of Annex IV, Enhanced Oil Recovery Thermal processes. The report is presented in six sections (for each of the six tasks) and each section contains one or more reports prepared by various individuals or groups describing the results of efforts under each one of the tasks. Each section has been abstracted and processed for inclusion in the Energy Data Base. A statement of each task, taken from the agreement, is presented on the first page of each section. The tasks are numbered 8-13. The first report on Annex IV, Venezuela-MEM/USE-DOE Fossil Energy Report IV-1, (DOE/BETC/SP-83/15), contains the results from the first seven tasks. That report is dated April 1983, entitled, EOR Thermal Processes.

Peterson, G.; Schwartz, E.

1984-08-01T23:59:59.000Z

417

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

SciTech Connect (OSTI)

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.

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

2002-09-30T23:59:59.000Z

418

Develop Thermoelectric Technology for Automotive Waste Heat Recovery  

Broader source: Energy.gov [DOE]

2011 DOE Hydrogen and Fuel Cells Program, and Vehicle Technologies Program Annual Merit Review and Peer Evaluation