National Library of Energy BETA

Sample records for oil recovery tool

  1. Imbibition assisted oil recovery 

    E-Print Network [OSTI]

    Pashayev, Orkhan H.

    2004-11-15

    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...

  2. Biochemically enhanced oil recovery and oil treatment

    DOE Patents [OSTI]

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

    1994-01-01

    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.

  3. Biochemically enhanced oil recovery and oil treatment

    DOE Patents [OSTI]

    Premuzic, E.T.; Lin, M.

    1994-03-29

    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.

  4. Optimize carbon dioxide sequestration, enhance oil recovery

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

    Optimize carbon dioxide sequestration, enhance oil recovery Optimize carbon dioxide sequestration, enhance oil recovery The simulation provides an important approach to estimate...

  5. Enhanced oil recovery system

    DOE Patents [OSTI]

    Goldsberry, Fred L. (Spring, TX)

    1989-01-01

    All energy resources available from a geopressured geothermal reservoir are used for the production of pipeline quality gas using a high pressure separator/heat exchanger and a membrane separator, and recovering waste gas from both the membrane separator and a low pressure separator in tandem with the high pressure separator for use in enhanced oil recovery, or in powering a gas engine and turbine set. Liquid hydrocarbons are skimmed off the top of geothermal brine in the low pressure separator. High pressure brine from the geothermal well is used to drive a turbine/generator set before recovering waste gas in the first separator. Another turbine/generator set is provided in a supercritical binary power plant that uses propane as a working fluid in a closed cycle, and uses exhaust heat from the combustion engine and geothermal energy of the brine in the separator/heat exchanger to heat the propane.

  6. Engine breather oil recovery system

    SciTech Connect (OSTI)

    Speer, S.R.; Norton, J.G.; Wilson, J.D.

    1990-08-14

    This patent describes an engine breather oil recovery system, for use with reciprocating engines having an oil breather and an oil reservoir recovery system. It comprises:an engine breather outlet from the engine; a vapor and oil separator device in fluid flow connection with the engine breather outlet; a motive flow suction means in fluid flow connection between the separator device and the engine, so as to provide a substantially continuous pressure drop between the separator device and the engine oil reservoir; an engine fluid system in parallel with the separator device; and an engine driven pump in fluid flow connection with such other engine fluid system, wherein the motive force for the motive flow suction means is provided by the fluid from the engine pump.

  7. Brushing up on oil recovery

    SciTech Connect (OSTI)

    Mackey, J.

    1995-12-01

    To be prepared for a range of oil spills, emergency response organizations must have an arsenal of powerful and adaptable equipment. Around the coastal United States, a network of oil spill cooperatives and emergency response organizations stand ready with the technology and the know-how to respond to the first sign of an oil spill. When the telephone rings, they may be required to mop up 200 gallons of oil that leaked off the deck of a ship or to contain and skim 2,000 gallons of oil from a broken hose at a loading terminal. In a few cases each year, they may find themselves responding to a major pollution incident, one that involves hundreds of people and tons of equipment. To clean an oil spill at a New Jersey marine terminal, the local cooperative used the Lundin Oil Recovery Inc. (LORI) skimming system to separate the oil and water and the lift the oil out of the river. The LORI skimming technology is based on sound principles of fluid management - using the natural movement of water instead of trying to fight against it. A natural feeding mechanism delivers oily water through the separation process, and a simple mechanical separation and recovery device - a brush conveyor - removes the pollutants from the water.

  8. Successful Sequestration and Enhanced Oil Recovery Project Could...

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

    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...

  9. Biosurfactant and enhanced oil recovery

    DOE Patents [OSTI]

    McInerney, Michael J. (Norman, OK); Jenneman, Gary E. (Norman, OK); Knapp, Roy M. (Norman, OK); Menzie, Donald E. (Norman, OK)

    1985-06-11

    A pure culture of Bacillus licheniformis strain JF-2 (ATCC No. 39307) and a process for using said culture and the surfactant lichenysin produced thereby for the enhancement of oil recovery from subterranean formations. Lichenysin is an effective surfactant over a wide range of temperatures, pH's, salt and calcium concentrations.

  10. Shale oil recovery process

    DOE Patents [OSTI]

    Zerga, Daniel P. (Concord, CA)

    1980-01-01

    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.

  11. Method for enhanced oil recovery

    DOE Patents [OSTI]

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

    1980-01-01

    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.

  12. 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

  13. Microbial enhanced oil recovery and compositions therefor

    DOE Patents [OSTI]

    Bryant, Rebecca S. (Bartlesville, OK)

    1990-01-01

    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.

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

    E-Print Network [OSTI]

    Goddard III, William A.

    esters sorbitan ester ultra-low interfacial tension enhanced oil recovery surfactant flood chemical flood sandstones. In addition to the corefloods, one sandpack surfactant flood was performed. The porous media were by polymer drive slug injection, and incremental oil recovery was measured against time. The tested

  15. Aqueous flooding methods for tertiary oil recovery

    DOE Patents [OSTI]

    Peru, Deborah A. (Bartlesville, OK)

    1989-01-01

    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.

  16. SURFACTANT BASED ENHANCED OIL RECOVERY AND FOAM MOBILITY CONTROL

    SciTech Connect (OSTI)

    George J. Hirasaki; Clarence A. Miller; Gary A. Pope; Richard E. Jackson

    2004-07-01

    Surfactant flooding has the potential to significantly increase recovery over that of conventional waterflooding. The availability of a large number of surfactants makes it possible to conduct a systematic study of the relation between surfactant structure and its efficacy for oil recovery. Also, the addition of an alkali such as sodium carbonate makes possible in situ generation of surfactant and significant reduction of surfactant adsorption. In addition to reduction of interfacial tension to ultra-low values, surfactants and alkali can be designed to alter wettability to enhance oil recovery. An alkaline surfactant process is designed to enhance spontaneous imbibition in fractured, oil-wet, carbonate formations. It is able to recover oil from dolomite core samples from which there was no oil recovery when placed in formation brine. Mobility control is essential for surfactant EOR. Foam is evaluted to improve the sweep efficiency of surfactant injected into fractured reservoirs. UTCHEM is a reservoir simulator specially designed for surfactant EOR. A dual-porosity version is demonstrated as a potential scale-up tool for fractured reservoirs.

  17. Water-related Issues Affecting Conventional Oil and Gas Recovery...

    Office of Scientific and Technical Information (OSTI)

    Water-related Issues Affecting Conventional Oil and Gas Recovery and Potential Oil-Shale Development in the Uinta Basin, Utah Michael Vanden Berg; Paul Anderson; Janae Wallace;...

  18. RESEARCH OIL RECOVERY MECHANISMS IN HEAVY OIL RESERVOIRS

    SciTech Connect (OSTI)

    Anthony R. Kovscek; William E. Brigham

    1999-06-01

    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.

  19. Development of More Effective Biosurfactants for Enhanced Oil Recovery

    SciTech Connect (OSTI)

    McInerney, M.J.; Mouttaki, H.; Folmsbee, M.; Knapp, R.; Nagle, D.

    2003-01-24

    The overall goal of this research was to develop effective biosurfactant production for enhanced oil recovery in the United States.

  20. From the hills to the mountain. [Oil recovery in California

    SciTech Connect (OSTI)

    McDonald, J.

    1980-05-01

    The oil reserves at Elk Hills field, California, are listed as amounting to 835 million bbl. There is 12 times that amount lying in shallow sands in the San Joaquin Valley, although the oil is much heavier and requires more refining before use. Improved recovery techniques have enabled higher rates of recovery for heavy oil than in the past. Some of these techniques are described, including bottom-hole heating, steam injection, and oil mining. Bottom-hole heating alone raised recovery rates for heavy oil to 25%, and steam injection raised rates to 50%. It is predicted that oil mining may be able to accomplish 100% recovery of the heavy oil.

  1. A field laboratory for improved oil recovery

    SciTech Connect (OSTI)

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

    1992-09-01

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

  2. An evaluation of known remaining oil resources in the United States. Appendix, Project on Advanced Oil Recovery and the States

    SciTech Connect (OSTI)

    Not Available

    1994-10-01

    This volume contains appendices for the following: Overview of improved oil recovery methods (enhanced oil recovery methods and advanced secondary recovery methods); Benefits of improved oil recovery, selected data for the analyzed states; and List of TORIS fields and reservoirs.

  3. Process for tertiary oil recovery using tall oil pitch

    DOE Patents [OSTI]

    Radke, C.J.

    1983-07-25

    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)

  4. HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS

    SciTech Connect (OSTI)

    Anthony R. Kovscek; Louis M. Castanier

    2002-09-30

    The Stanford University Petroleum Research Institute (SUPRI-A) conducts a broad spectrum of research intended to help improve the recovery efficiency from difficult to produce reservoirs including heavy oil and fractured low permeability systems. Our scope of work is relevant across near-, mid-, and long-term time frames. The primary functions of the group are to conduct direction-setting research, transfer research results to industry, and educate and train students for careers in industry. Presently, research in SUPRI-A is divided into 5 main project areas. These projects and their goals include: (1) Multiphase flow and rock properties--to develop better understanding of the physics of displacement in porous media through experiment and theory. This category includes work on imbibition, flow in fractured media, and the effect of temperature on relative permeability and capillary pressure. (2) Hot fluid injection--to improve the application of nonconventional wells for enhanced oil recovery and elucidate the mechanisms of steamdrive in low permeability, fractured porous media. (3) Mechanisms of primary heavy oil recovery--to develop a mechanistic understanding of so-called ''foamy oil'' and its associated physical chemistry. (4) In-situ combustion--to evaluate the effect of different reservoir parameters on the insitu combustion process. (5) Reservoir definition--to develop and improve techniques for evaluating formation properties from production information. What follows is a report on activities for the past year. Significant progress was made in all areas.

  5. Enhanced oil recovery projects data base

    SciTech Connect (OSTI)

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

    1992-04-01

    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.

  6. Microbial enhancement of oil recovery: Recent advances

    SciTech Connect (OSTI)

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

    1992-01-01

    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.

  7. "Smart" Multifunctional Polymers for Enhanced Oil Recovery

    SciTech Connect (OSTI)

    Charles McCormick; Andrew Lowe

    2007-03-20

    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.

  8. Enhanced Oil Recovery: Aqueous Flow Tracer Measurement

    SciTech Connect (OSTI)

    Joseph Rovani; John Schabron

    2009-02-01

    A low detection limit analytical method was developed to measure a suite of benzoic acid and fluorinated benzoic acid compounds intended for use as tracers for enhanced oil recovery operations. Although the new high performance liquid chromatography separation successfully measured the tracers in an aqueous matrix at low part per billion levels, the low detection limits could not be achieved in oil field water due to interference problems with the hydrocarbon-saturated water using the system's UV detector. Commercial instrument vendors were contacted in an effort to determine if mass spectrometry could be used as an alternate detection technique. The results of their work demonstrate that low part per billion analysis of the tracer compounds in oil field water could be achieved using ultra performance liquid chromatography mass spectrometry.

  9. Enhanced Heavy Oil Recovery by Emulsification With Injected Nanoparticles 

    E-Print Network [OSTI]

    Martinez Cedillo, Arturo Rey

    2013-11-26

    by investing early in methods and techniques to enhance recovery. Primary heavy oil recovery methods are being applied widely in Canada and Venezuela. For example, cold heavy oil production with sand (CHOPS) in Canada 2 currently contributes to more... these methods have been applied to heavy oil reservoirs with different levels of success (Shah et al. 2010). Poor conformance is the principal factor of unsuccessful heavy oil waterflooding projects. Emulsifying the injected water with crude oil...

  10. Process for tertiary oil recovery using tall oil pitch

    DOE Patents [OSTI]

    Radke, Clayton J. (El Cerrito, CA)

    1985-01-01

    Compositions and process employing same for enhancing the recovery of residual acid crudes, particularly heavy crudes, by injecting a composition comprising caustic in an amount sufficient to maintain a pH of at least about 11, preferably at least about 13, and a small but effective amount of a multivalent cation for inhibiting alkaline silica dissolution with the reservoir. Preferably a tall oil pitch soap is included and particularly for the heavy crudes a polymeric mobility control agent.

  11. LINEAR TRANSIENT FLOW SOLUTION FOR PRIMARY OIL RECOVERY

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    in a low-permeability, compressible, layered reservoir filled with oil, water and gas. The sample for pressure support and incremental oil recovery. We analyze the pressure response and fluid flow ratesLINEAR TRANSIENT FLOW SOLUTION FOR PRIMARY OIL RECOVERY WITH INFILL AND CONVERSION TO WATER

  12. 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...

  13. Environmental regulations handbook for enhanced oil recovery

    SciTech Connect (OSTI)

    Madden, M.P. [National Inst. for Petroleum and Energy Research, Bartlesville, OK (United States); Blatchford, R.P.; Spears, R.B. [Spears and Associates, Inc., Tulsa, OK (United States)

    1991-12-01

    This handbook is intended to assist owners and operators of enhanced oil recovery (EOR) operations in acquiring some introductory knowledge of the various state agencies, the US Environmental Protection Agency, and the many environmental laws, rules and regulations which can have jurisdiction over their permitting and compliance activities. It is a compendium of summarizations of environmental rules. It is not intended to give readers specific working details of what is required from them, nor can it be used in that manner. Readers of this handbook are encouraged to contact environmental control offices nearest to locations of interest for current regulations affecting them.

  14. Solar enhanced oil recovery: a potential early market for industrial solar energy

    SciTech Connect (OSTI)

    Bergeron, K.D.; Dugan, V.L.

    1980-01-01

    Enhanced oil recovery and the possibility of using solar energy to replace current methods are discussed. The market potential for solar enhanced oil recovery is explored. (MHR)

  15. Aerobic enhanced oil recovery: analysis of the mechanisms and a pilot study 

    E-Print Network [OSTI]

    Eide, Karen

    1998-01-01

    The technique that uses microorganisms to improve oil production in petroleum reservoirs is known as microbial enhanced oil recovery (MEOR). Aerobic microbial enhanced oil recovery is a method which is based on stimulating indigenous oil degrading...

  16. Seismic stimulation for enhanced oil recovery

    E-Print Network [OSTI]

    Pride, S.R.

    2008-01-01

    aims to enhance oil production by sending seismic wavesbe expected to enhance oil production. INTRODUCTION The hopethe reservoir can cause oil production to increase. Quite

  17. Evaluation of Reservoir Wettability and its Effect on Oil Recovery

    SciTech Connect (OSTI)

    Buckley, Jill S.

    2002-01-29

    The objectives of this five-year project were: (1) to achieve improved understanding of the surface and interfacial properties of crude oils and their interactions with mineral surfaces, (2) to apply the results of surface studies to improve predictions of oil production from laboratory measurements, and (3) to use the results of this research to recommend ways to improve oil recovery by waterflooding.

  18. SURFACTANT BASED ENHANCED OIL RECOVERY AND FOAM MOBILITY CONTROL

    SciTech Connect (OSTI)

    George J. Hirasaki; Clarence A. Miller; Gary A. Pope; Richard E. Jackson

    2004-02-01

    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. Also, the addition of an alkali such as sodium carbonate makes possible in situ generation of surfactant and significant reduction of surfactant adsorption. In addition to reduction of interfacial tension to ultra-low values, surfactants and alkali can be designed to alter wettability to enhance oil recovery. An alkaline surfactant process is designed to enhance spontaneous imbibition in fractured, oil-wet, carbonate formations. It is able to recover oil from dolomite core samples from which there was no oil recovery when placed in formation brine.

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

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

    Enhanced Oil Recovery Affects the Future Energy Mix Click to email this to a friend (Opens in new window) Share on Facebook (Opens in new window) Click to share (Opens in new...

  20. On inverse problems in secondary oil recovery Victor Isakov

    E-Print Network [OSTI]

    Isakov, Victor

    recommendations for drilling new wells and finding pumping regimes to optimize oil recovery. Looking equations describing fluids in porous media. This inverse problem is called "history matching". Despite its

  1. Recovery of oil from fractured reservoirs by gas displacement 

    E-Print Network [OSTI]

    Unneberg, Arild

    1974-01-01

    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...

  2. Uncertainty quantification for CO2 sequestration and enhanced oil recovery

    E-Print Network [OSTI]

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

    2014-01-01

    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...

  3. CO2 Enhanced Oil Recovery Feasibility Evaluation for East Texas Oil Field

    E-Print Network [OSTI]

    Lu, Ping

    2012-08-31

    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...

  4. Experimental Study of Solvent Based Emulsion Injection to Enhance Heavy Oil Recovery 

    E-Print Network [OSTI]

    Qiu, Fangda

    2011-08-08

    (enhanced oil recovery) process for some heavy oil reservoirs in Alaska, Canada and Venezuela after primary production. Heavy oil lacks mobility under reservoir conditions and is not suitable for the application of the thermal recovery method because...

  5. Shale oil recovery systems incorporating ore beneficiation : final report, October 1982

    E-Print Network [OSTI]

    Weiss, M. A.

    1982-01-01

    This study analyzed the recovery of oil from oil shale by use of proposed systems which incorporate beneficiation of the shale ore (that is, concentration of the kerogen) before the oil-recovery step. The objective was to ...

  6. Microbial enhanced oil recovery and wettability research program

    SciTech Connect (OSTI)

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

    1991-07-01

    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.

  7. Method for maximizing shale oil recovery from an underground formation

    DOE Patents [OSTI]

    Sisemore, Clyde J. (Livermore, CA)

    1980-01-01

    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.

  8. Chemical and Microbial Characterization of North Slope Viscous Oils to Assess Viscosity Reduction and Enhanced Recovery

    SciTech Connect (OSTI)

    Shirish Patil; Abhijit Dandekar; Mary Beth Leigh

    2008-12-31

    A large proportion of Alaska North Slope (ANS) oil exists in the form of viscous deposits, which cannot be produced entirely using conventional methods. Microbially enhanced oil recovery (MEOR) is a promising approach for improving oil recovery for viscous deposits. MEOR can be achieved using either ex situ approaches such as flooding with microbial biosurfactants or injection of exogenous surfactant-producing microbes into the reservoir, or by in situ approaches such as biostimulation of indigenous surfactant-producing microbes in the oil. Experimental work was performed to analyze the potential application of MEOR to the ANS oil fields through both ex situ and in situ approaches. A microbial formulation containing a known biosurfactant-producing strain of Bacillus licheniformis was developed in order to simulate MEOR. Coreflooding experiments were performed to simulate MEOR and quantify the incremental oil recovery. Properties like viscosity, density, and chemical composition of oil were monitored to propose a mechanism for oil recovery. The microbial formulation significantly increased incremental oil recovery, and molecular biological analyses indicated that the strain survived during the shut-in period. The indigenous microflora of ANS heavy oils was investigated to characterize the microbial communities and test for surfactant producers that are potentially useful for biostimulation. Bacteria that reduce the surface tension of aqueous media were isolated from one of the five ANS oils (Milne Point) and from rock oiled by the Exxon Valdez oil spill (EVOS), and may prove valuable for ex situ MEOR strategies. The total bacterial community composition of the six different oils was evaluated using molecular genetic tools, which revealed that each oil tested possessed a unique fingerprint indicating a diverse bacterial community and varied assemblages. Collectively we have demonstrated that there is potential for in situ and ex situ MEOR of ANS oils. Future work should focus on lab and field-scale testing of ex situ MEOR using Bacillus licheniformis as well as the biosurfactant-producing strains we have newly isolated from the Milne Point reservoir and the EVOS environment.

  9. Optimize carbon dioxide sequestration, enhance oil recovery

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

    CO2-EOR provides about 5 percent of the total U.S. current crude oil production. Due to carbon capture and storage technology advances, prolonged high oil prices and the...

  10. Exsolution Enhanced Oil Recovery with Concurrent CO2 Sequestration

    SciTech Connect (OSTI)

    Zuo, Lin; Benson, Sally M.

    2013-01-01

    A novel EOR method using carbonated water injection followed by depressurization is introduced. Results from micromodel experiments are presented to demonstrate the fundamental principles of this oil recovery method. A depressurization process (1 MPa/hr) was applied to a micromodel following carbonated water injection (Ca ? 10-5). The exsolved CO2 in water-filled pores blocked water flow in swiped portions and displaced water into oil-filled pores. Trapped oil after the carbonated water injection was mobilized by sequentially invading water. This method's self-distributed mobility control and local clogging was tested in a sandstone sample under reservoir conditions. A 10% incremental oil recovery was achieved by lowering the pressure 2 MPa below the CO2 liberation pressure. Additionally, exsolved CO2 resides in the pores of a reservoir as an immobile phase with a high residual saturation after oil production, exhibiting a potential synergy opportunity between CO2 EOR and CO2 sequestration

  11. Evaluation of Reservoir Wettability and its Effect on Oil Recovery

    SciTech Connect (OSTI)

    Buckley, Jill S.

    1999-07-01

    The objective of this five-year project are: (1) to achieve improved understanding of the surface and interfacial properties of crude oils and their interactions with mineral surfaces, (2) to apply the results of surface studies to improve predictions of oil production from laboratory measurements, and (3) to use the results of this research to recommend ways to improve oil recovery by waterflooding. During the second year of this project we have tested the generality of the proposed mechanisms by which crude oil components can alter wetting. Using these mechanisms, we have begun a program of characterizing crude oils with respect to their wettability altering potential. Wettability assessment has been improved by replacing glass with mica as a standard surface material and crude oils have been used to alter wetting in simple square glass capillary tubes in which the subsequent imbibition of water can be followed visually.

  12. Assessment of central receiver solar thermal enhanced oil recovery systems

    SciTech Connect (OSTI)

    Gorman, D.N.

    1987-07-01

    In November 1982, ARCO Solar, Incorporated, with the cooperation of ARCO Oil and Gas Company, completed installation and began operation of a central receiver solar thermal pilot plant to produce steam for enhanced oil recovery. The highly automated plant can produce approximately one megawtt of thermal power in the form of 80% quality steam, which is delivered to a distribution header for injection into heavy oil formations. An engineering evaluation of data from the ARCO plant has been performed, with the conclusion that central receiver solar systems can be very effective sources of power to generate steam for the enhanced recovery of heavy oil. The highly automated pilot plant exhibited outstanding reliability of the solar power conversion components while operating routinely with a single attendant, demonstrating the capability for very low operating and maintenance costs for these systems relative to the use of conventional oil-burning steam generators. This document reports the operating and performance characteristics of the ARCO solar thermal enhanced oil recovery (STEOR) system over a full year of operation. System sizing and performance projection for a much larger commercial plant is also presented.

  13. Surfactant Based Enhanced Oil Recovery and Foam Mobility Control

    SciTech Connect (OSTI)

    George J. Hirasaki; Clarence A. Miller; Gary A. Pope

    2005-07-01

    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 combination of two surfactants was found to be particularly effective for application in carbonate formations at low temperature. A formulation has been designed for a particular field application. The addition of an alkali such as sodium carbonate makes possible in situ generation of surfactant and significant reduction of surfactant adsorption. In addition to reduction of interfacial tension to ultra-low values, surfactants and alkali can be designed to alter wettability to enhance oil recovery. The design of the process to maximize the region of ultra-low IFT is more challenging since the ratio of soap to synthetic surfactant is a parameter in the conditions for optimal salinity. Compositional simulation of the displacement process demonstrates the interdependence of the various components for oil recovery. An alkaline surfactant process is designed to enhance spontaneous imbibition in fractured, oil-wet, carbonate formations. It is able to recover oil from dolomite core samples from which there was no oil recovery when placed in formation brine. Mobility control is essential for surfactant EOR. Foam is evaluated to improve the sweep efficiency of surfactant injected into fractured reservoirs. UTCHEM is a reservoir simulator specially designed for surfactant EOR. It has been modified to represent the effects of a change in wettability. Simulated case studies demonstrate the effects of wettability.

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

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

    of the fascinating things of my job is contemplating questions like: What will the future energy mix look like? This is difficult to predict but it is fair to argue that oil will...

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

    SciTech Connect (OSTI)

    Munroe, Norman

    2009-01-30

    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.

  16. Effect of fluid rheology on enhanced oil recovery in a microfluidic sandstone device

    E-Print Network [OSTI]

    Rothstein, Jonathan

    Effect of fluid rheology on enhanced oil recovery in a microfluidic sandstone device Michael A 2013 Keywords: Microfluidics Enhanced oil recovery Shear-thickening Viscoelastic Sandstone Interfacial tension a b s t r a c t As global energy usage increases, maximizing oil recovery from known reserves

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

    SciTech Connect (OSTI)

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

    1992-09-01

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

  18. Enhanced Oil Recovery | Department of Energy

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE: Alternative Fuels DataEnergyInformationVulnerabilitiesEnergyPlus Logo DebutsEnhanced Oil

  19. Improved oil recovery using horizontal wells at Elk Hills, California

    SciTech Connect (OSTI)

    Gangle, F.J.; Schultz, K.L.; McJannet, G.S.; Ezekwe, N.

    1995-03-01

    Eight horizontal wells have been drilled and completed in a steeply dipping Stevens sand reservoir in the Elk Hills field, Kern County, California. The subject reservoir, called the Stevens 26R, is a turbidite channel sand deposit one mile wide, three miles long, and one mile deep. Formation beds have a gross thickness up to 1,500 feet and dips as high as 60 degrees on the flanks. The original oil column of 1,810 feet has been pulled down to 200 feet by continual production since 1976. The reservoir management operating strategy has been full pressure maintenance by crestal gas injection since 1976. The steep dip of the formation makes gravity drainage the dominant drive mechanism. Additionally, improved recovery is coming from cycling dry gas through the large secondary gas cap region. The prudent placement of the horizontal wells above the oil/water contact promises to improve oil recovery and extend the operating life of the reservoir. Field results are given to compare the performance of the horizontal wells with the conventional wells. The horizontal wells produce at higher rates, lower draw downs, and lower gas/oil ratio which will extend the life of the project and result in higher recovery.

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

    SciTech Connect (OSTI)

    Forsberg, Charles W.

    2006-07-01

    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)

  1. Microbial enhancement of oil recovery: Recent advances. Proceedings

    SciTech Connect (OSTI)

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

    1992-12-31

    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.

  2. Geomechanical Study of Bakken Formation for Improved Oil Recovery

    SciTech Connect (OSTI)

    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

    2013-12-31

    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.

  3. A Management Tool for Analyzing CHP Natural Gas Liquids Recovery System 

    E-Print Network [OSTI]

    Olsen, C.; Kozman, T. A.; Lee, J.

    2008-01-01

    The objective of this research is to develop a management tool for analyzing combined heat and power (CHP) natural gas liquids (NGL) recovery systems. The methodology is developed around the central ideas of product recovery, possible recovery...

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

    E-Print Network [OSTI]

    Cirpka, Olaf Arie

    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

  5. THEORY OF THREE-PHASE FLOW APPLIED TO WATER-ALTERNATING-GAS ENHANCED OIL RECOVERY

    E-Print Network [OSTI]

    THEORY OF THREE-PHASE FLOW APPLIED TO WATER-ALTERNATING-GAS ENHANCED OIL RECOVERY D. MARCHESIN is the key to this improvement. 1. Introduction In secondary oil recovery, water or gas is injected in three-phase ow in a porous medium, we consider the idealized ow of water, oil, and gas

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

    E-Print Network [OSTI]

    Daripa, Prabir

    of the objective functions in tertiary oil recovery by polymer flooding is the "op- timal" viscous profileFLUID DYNAMICAL AND MODELING ISSUES OF CHEMICAL FLOODING FOR ENHANCED OIL RECOVERY Prabir Daripa are succinctly summarized including characteri- zation of the optimal flooding scheme that leads to maximum oil

  7. An optimal viscosity profile in enhanced oil recovery by polymer flooding

    E-Print Network [OSTI]

    Daripa, Prabir

    An optimal viscosity profile in enhanced oil recovery by polymer flooding Prabir Daripa a,*, G; accepted 3 July 2004 (Communicated by L. DEBNATH) Abstract Forced displacement of oil by polymer flooding reserved. Keywords: Enhanced oil recovery; Polymer flooding; Linear stability 0020-7225/$ - see front

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

    SciTech Connect (OSTI)

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

    1980-03-01

    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.

  9. Enhanced Oil Recovery by Horizontal Waterflooding

    SciTech Connect (OSTI)

    Scott Robinowitz; Dwight Dauben; June Schmeling

    2005-09-05

    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

  10. Experimental study of Morichal heavy oil recovery using combined steam and propane injection 

    E-Print Network [OSTI]

    Goite Marcano, Jose Gregorio

    1999-01-01

    with steam (for the purpose of increasing steam recovery efficiency) are being evaluated. An experimental study has been performed to investigate the effect of combined steam and propane injection on recovery of heavy oil from the Morichal field, Venezuela...

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

    SciTech Connect (OSTI)

    Mark B. Murphy

    2005-09-30

    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

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

    SciTech Connect (OSTI)

    Murphy, Mark B.

    1999-02-24

    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.

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

    E-Print Network [OSTI]

    Hervas Ordonez, Rafael Alejandro

    1994-01-01

    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...

  14. enhanced_oil_recovery | netl.doe.gov

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity ofkandz-cm11 Outreach Home RoomPreservationBio-Inspired SolarAboutXu Named| Princetondefault Sign InEnhanced Oil Recovery

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

    SciTech Connect (OSTI)

    Mark B. Murphy

    2004-01-31

    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.

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

    SciTech Connect (OSTI)

    Mark B. Murphy

    2002-12-31

    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.

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

    SciTech Connect (OSTI)

    Mark B. Murphy

    2003-07-30

    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.

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

    SciTech Connect (OSTI)

    Mark B. Murphy

    2003-10-31

    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.

  19. Supporting technology for enhanced oil recovery: Sixth amendment and extension to Annex IV enhanced oil recovery thermal processes

    SciTech Connect (OSTI)

    Reid, T.B. (USDOE Bartlesville Project Office, OK (United States)); Rivas, O. (INTEVEP, Filial de Petroleos de Venezuela, SA, Caracas (Venezuela))

    1991-10-01

    This report contains the results of efforts under the six tasks of the Sixth Amendment and Extension of Annex 4, 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 44 through 49. Tasks are: DOE-SUPRI-laboratory research on steam foam, CAT-SCAN, and in-situ combustion; INTEVEP-laboratory research and field projects on steam foam; DOE-NIPER-laboratory research and field projects light oil steam flooding; INTEVEP-laboratory research and field studies on wellbore heat losses; DOE-LLNL-laboratory research and field projects on electromagnetic induction tomography; INTEVEP-laoboratory research on mechanistic studies.

  20. Monitoring of thermal enhanced oil recovery processes with electromagnetic methods

    SciTech Connect (OSTI)

    Wilt, M.

    1992-09-01

    Research in applying electromagnetic methods for imaging thermal enhanced oil recovery has progressed significantly during the past eighteen months. Working together with researchers at Lawrence Berkeley Laboratory (LBL) and supported by a group of industrial sponsors we have focused our effort on field system development and doing field surveys connected with EOR operations. Field surveys were recently completed at the Lost Hills No.3 oil field and at UC Richmond Field station. At Lost Hills, crosshole EM data sets were collected before a new phase of steam injection for EOR and again four months after the onset of steaming. The two data sets were nearly identical suggesting that very little steam had been injected into this borehole. This is in accord with the operators records which indicate injectivity problems with this particular well. At Richmond we conducted a salt water injection monitoring experiment where 50,000 gallons of salt water were injected in a shallow aquifer and crosshole EM data were collected using the injection well and several observation wells. We applied the imaging code to some of the collected data and produced an image showing that the salt water slug has propagated 8--10 m from the injector into the aquifer. This result is partially confirmed by prior calculations and well logging data. Applying the EM methods to the problem of oil field characterization essentially means extending the borehole resistivity log into the region between wells. Since the resistivity of a sedimentary environment is often directly dependent on the fluids in the rock the knowledge of the resistivity distribution within an oil field can be invaluable for finding missed or bypassed oil or for mapping the overall structure. With small modification the same methods used for mapping EOR process can be readily applied to determining the insitu resistivity structure.

  1. Electromagnetic Imaging of CO2 Sequestration at an Enhanced Oil Recovery Site

    SciTech Connect (OSTI)

    Kirkendall, B.; Roberts, J.

    2001-02-28

    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{sub 2} sequestration at an EOR site also operated by Chevron. The impetus for this study is to develop the ability to image subsurface injected CO{sub 2} during EOR processes while simultaneously discriminating between pre-existing petroleum and water deposits. The goals of this study are to combine laboratory and field methods to image a pilot CO{sub 2} sequestration EOR site using the cross-borehole EM technique, improve the inversion process in CO{sub 2} studies by coupling results with petrophysical laboratory measurements, and focus on new gas interpretation techniques. In this study we primarily focus on how joint field and laboratory results can provide information on subsurface CO{sub 2} detection, CO{sub 2} migration tracking, and displacement of petroleum and water over time. This study directly addresses national energy issues in two ways: (1) the development of field and laboratory techniques to improve in-situ analysis of oil and gas enhanced recovery operations and, (2) this research provides a tool for in-situ analysis of CO{sub 2} sequestration, an international technical issue of growing importance.

  2. OPTICAL FIBER SENSOR TECHNOLOGIES FOR EFFICIENT AND ECONOMICAL OIL RECOVERY

    SciTech Connect (OSTI)

    Kristie Cooper; Gary Pickrell; Anbo Wang

    2003-04-01

    This report summarizes technical progress over the fourth year of the ''Optical Fiber Sensor Technologies for Efficient and Economical Oil Recovery'' program, funded by the Federal Energy Technology Center 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. During the reporting period, research efforts under the program were focused on the development and evaluation of the fiber optic flow sensor system, and field testing in Tulsa, OK and the second field test of the pressure and temperature sensors in Coalinga, CA. The feasibility of a self-compensating fiber optic flow sensor based on a cantilever beam and interferometer for real-time flow rate measurements in the fluid filled pipes of oil field was clearly demonstrated. In addition, field testing of the pressure and temperature sensors deployed downhole continued. These accomplishments are summarized here: (1) Theoretical analysis and simulations were performed to ensure performance of the design. (2) The sensor fabrication and packaging techniques were investigated and improved. (3) Prototype flow sensors were fabricated based on the fabrication experience of hundreds of test sensors. (4) A lab-scale flow testing system was constructed and used for sensor evaluation. (5) Field-testing was performed in both the indoor and outdoor flow testing facility at the University of Tulsa, OK. (6) Testing of a multimode white light pressure and temperature sensor system continued at the oil site of Chevron/Texaco Company (Coalinga CA).

  3. Thermally-enhanced oil recovery method and apparatus

    DOE Patents [OSTI]

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

    1987-01-01

    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.

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

    E-Print Network [OSTI]

    Cox, Simon

    as one reason why CO2 foams for enhanced oil recovery (EOR) are less resistant to flow than N2 foams weakness of CO2 foam therefore evidently lies in factors other than CO2's large diffusion rate through foam. Keywords Foam ·Diffusion · Enhanced oil recovery · Foam stability ·CO2 foam · Steam foam 1 Introduction

  5. Enhanced Oil Recovery of Viscous Oil by Injection of Water-in-Oil Emulsion Made with Used Engine Oil 

    E-Print Network [OSTI]

    Fu, Xuebing

    2012-08-20

    Solids-stabilized water-in-oil emulsions have been suggested as a drive fluid to recover viscous oil through a piston-like displacement pattern. While crude heavy oil was initially suggested as the base oil, an alternative oil ? used engine oil...

  6. Enhanced Oil Recovery with Downhole Vibration Stimulation in Osage County, Oklahoma

    SciTech Connect (OSTI)

    J. Ford Brett; Robert V. Westermark

    2002-06-30

    This Technical Quarterly Report is for the reporting period March 31, 2002 to June 30, 2002. The report provides details of the work done on the project entitled ''Enhanced Oil Recovery with Downhole Vibration Stimulation in Osage County Oklahoma''. The project is divided into nine separate tasks. Several of the tasks are being worked on simultaneously, while other tasks are dependent on earlier tasks being completed. The vibration stimulation Well 111-W-27 is located in section 8 T26N R6E of the North Burbank Unit (NBU), Osage County Oklahoma. It was drilled to 3090-feet cored, logged, cased and cemented. The rig moved off August 6, 2001. Phillips Petroleum Co. has performed several core studies on the cores recovered from the test well. Standard porosity, permeability and saturation measurements have been conducted. In addition Phillips has prepared a Core Petrology Report, detailing the lithology, stratigraphy and sedimentology for Well 111-W27, NBU. Phillips has also conducted the sonic stimulation core tests, the final sonic stimulation report has not yet been released. Calumet Oil Company, the operator of the NBU, began collecting both production and injection wells information to establish a baseline for the project in the pilot field test area since May 2001. The original 7-inch Downhole Vibration Tool (DHVT) has been thoroughly tested and it has been concluded that it needs to be redesigned. An engineering firm from Fayetteville AR has been retained to assist in developing a new design for the DHVT. The project participants requested from the DOE, a no-cost extension for the project through December 31, 2002. The no-cost extension amendment to the contract was signed during this reporting period. A technical paper SPE 75254 ''Enhanced Oil Recovery with Downhole Vibration Stimulation, Osage County, Oklahoma'' was presented at the 2002 SPE/DOE Thirteenth Symposium on Improved Oil Recovery, in Tulsa OK, April 17, 2002. A one-day short course was conducted at the SPE/DOE Thirteenth Symposium on Improved Oil Recovery in Tulsa, OK, April 13-14, 2002. Dan Maloney, Phillips and Bob Westermark, OGCI, Brett Davidson and Tim Spanos, Prism Production Technologies, were the instructors. The sixteen attendees also participated in the half-day field trip to the test facility near Tulsa.

  7. Waterflood control system for maximizing total oil recovery

    DOE Patents [OSTI]

    Patzek, Tadeusz Wiktor; Silin, Dimitriy Borisovic; De, Asoke Kumar

    2005-06-07

    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.

  8. Waterflood control system for maximizing total oil recovery

    DOE Patents [OSTI]

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

    2007-07-24

    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.

  9. Methods for enhancing mapping of thermal fronts in oil recovery

    DOE Patents [OSTI]

    Lee, D.O.; Montoya, P.C.; Wayland, J.R. Jr.

    1984-03-30

    A method for enhancing the resistivity contrasts of a thermal front in an oil recovery production field as measured by the controlled source audio frequency magnetotelluric (CSAMT) technique is disclosed. This method includes the steps of: (1) preparing a CSAMT-determined topological resistivity map of the production field; (2) introducing a solution of a dopant material into the production field at a concentration effective to alter the resistivity associated with the thermal front; said dopant material having a high cation exchange capacity which might be selected from the group consisting of montmorillonite, illite, and chlorite clays; said material being soluble in the conate water of the production field; (3) preparing a CSAMT-determined topological resistivity map of the production field while said dopant material is moving therethrough; and (4) mathematically comparing the maps from step (1) and step (3) to determine the location of the thermal front. This method is effective with the steam flood, fire flood and water flood techniques.

  10. Methods for enhancing mapping of thermal fronts in oil recovery

    DOE Patents [OSTI]

    Lee, David O. (Albuquerque, NM); Montoya, Paul C. (Albuquerque, NM); Wayland, Jr., James R. (Albuquerque, NM)

    1987-01-01

    A method for enhancing the resistivity contrasts of a thermal front in an oil recovery production field as measured by the CSAMT technique is disclosed. This method includes the steps of: (a) preparing a CSAMT-determined topological resistivity map of the production field; (b) introducing a solution of a dopant material into the production field at a concentration effective to alter the resistivity associated with the thermal front; said dopant material having a high cation exchange capacity which might be selected from the group consisting of montmorillonite, illite, and chlorite clays; said material being soluble in the connate water of the production field; (c) preparing a CSAMT-determined topological resistivity map of the production field while said dopant material is moving therethrough; and (d) mathematically comparing the maps from step (a) and step (c) to determine the location of the thermal front. This method is effective with the steam flood, fire flood and water flood techniques.

  11. An optimal viscosity profile in enhanced oil recovery by polymer Prabir Daripa1,

    E-Print Network [OSTI]

    Daripa, Prabir

    An optimal viscosity profile in enhanced oil recovery by polymer flooding Prabir Daripa1, and G. Pa. 2029-2039, 2004 (Nov. Issue) Abstract Forced displacement of oil by polymer flooding in oil reservoir, polymer flooding, linear stability. Author for correspondence (e-mail: prabir.daripa@math.tamu.edu) 1 #12;

  12. Enhanced Oil Recovery with Downhole Vibrations Stimulation in Osage County, Oklahoma

    SciTech Connect (OSTI)

    J. Ford Brett; Robert V. Westermark

    2001-09-30

    This Technical Quarterly Report is for the reporting period July 1, 2001 to September 30, 2001. The report provides details of the work done on the project entitled ''Enhanced Oil Recovery with Downhole Vibration Stimulation in Osage County Oklahoma''. The project is divided into nine separate tasks. Several of the tasks are being worked on simultaneously, while other tasks are dependent on earlier tasks being completed. The vibration stimulation well is permitted as Well 111-W-27, section 8 T26N R6E Osage County Oklahoma. It was spud July 28, 2001 with Goober Drilling Rig No. 3. The well was drilled to 3090-feet cored, logged, cased and cemented. The Rig No.3 moved off August 6, 2001. Phillips Petroleum Co. has begun analyzing the cores recovered from the test well. Standard porosity, permeability and saturation measurements will be conducted. They will then begin the sonic stimulation core tests Calumet Oil Company, the operator of the NBU, has begun to collect both production and injection wells information to establish a baseline for the project in the pilot field test area. Green Country Submersible Pump Company, a subsidiary of Calumet Oil Company, will provide both the surface equipment and downhole tools to allow the Downhole Vibration Tool to be operated by a surface rod rotating system. The 7-inch Downhole Vibration Tool (DHVT) has been built and is ready for initial shallow testing. The shallow testing will be done in a temporarily abandoned well operated by Calumet Oil Co. in the Wynona waterflood unit. The data acquisition doghouse and rod rotating equipment have been placed on location in anticipation of the shallow test in Well No.20-12 Wynona Waterflood Unit. A notice of invention disclosure was submitted to the DOE Chicago Operations Office. DOE Case No.S-98,124 has been assigned to follow the documentation following the invention disclosure. A paper covering the material presented to the Oklahoma Geologic Survey (OGS)/DOE Annual Workshop in Oklahoma City May 8,9 2001 has been submitted for publication to the OGS. A technical paper draft has been submitted for the ASME/ETCE conference (Feb 2002) Production Technology Symposium. A one-day SPE sponsored short course which is planned to cover seismic stimulation efforts around the world, will be offered at the SPE/DOE Thirteenth Symposium on Improved Oil Recovery in Tulsa, OK, April 13-17, 2002. Dan Maloney, Phillips and Bob Westermark, OGCI will be the instructors. In addition, a proposed technical paper has been submitted for this meeting.

  13. Enhanced oil recovery using flash-driven steamflooding

    DOE Patents [OSTI]

    Roark, Steven D. (Bartlesville, OK)

    1990-01-01

    The present invention is directed to a novel steamflooding process which utilizes three specific stages of steam injection for enhanced oil recovery. The three stages are as follows: As steam is being injected into an oil-bearing reservoir through an injection well, the production rate of a production well located at a distance from the injection well is gradually restricted to a point that the pressure in the reservoir increases at a predetermined rate to a predetermined maximum value. After the maximum pressure has been reached, the production rate is increased to a value such that the predetermined maximum pressure value is maintained. Production at maximum pressure is continued for a length of time that will be unique for each individual reservoir. In some cases, this step of the steamflooding process of the invention may be omitted entirely. In the third stage of the steamflooding process of the invention, production rates at the producing well are increased gradually to allow the pressure to decrease down from the maximum pressure value to the original pressure value at the producing well. The rate of pressure reduction will be unique for each reservoir. After completing stage three, the three stages can be repeated or the steamflood may be terminated as considered desirable.

  14. Oil Recovery Increases by Low-Salinity Flooding: Minnelusa and Green River Formations

    SciTech Connect (OSTI)

    Eric P. Robertson

    2010-09-01

    Waterflooding is by far the most widely used method in the world to increase oil recovery. Historically, little consideration has been given in reservoir engineering practice to the effect of injection brine composition on waterflood displacement efficiency or to the possibility of increased oil recovery through manipulation of the composition of the injected water. However, recent work has shown that oil recovery can be significantly increased by modifying the injection brine chemistry or by injecting diluted or low salinity brine. This paper reports on laboratory work done to increase the understanding of improved oil recovery by waterflooding with low salinity injection water. Porous media used in the studies included outcrop Berea sandstone (Ohio, U.S.A.) and reservoir cores from the Green River formation of the Uinta basin (Utah, U.S.A.). Crude oils used in the experimental protocols were taken from the Minnelusa formation of the Powder River basin (Wyoming, U.S.A.) and from the Green River formation, Monument Butte field in the Uinta basin. Laboratory corefloods using Berea sandstone, Minnelusa crude oil, and simulated Minnelusa formation water found a significant relationship between the temperature at which the oil- and water-saturated cores were aged and the oil recovery resulting from low salinity waterflooding. Lower aging temperatures resulted in very little to no additional oil recovery, while cores aged at higher temperatures resulted in significantly higher recoveries from dilute-water floods. Waterflood studies using reservoir cores and fluids from the Green River formation of the Monument Butte field also showed significantly higher oil recoveries from low salinity waterfloods with cores flooded with fresher water recovering 12.4% more oil on average than those flooded with undiluted formation brine.

  15. Surfactant Based Enhanced Oil Recovery and Foam Mobility Control

    SciTech Connect (OSTI)

    George J. Hirasaki; Clarence A. Miller

    2006-09-09

    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.

  16. Enhanced Oil Recovery with Downhole Vibration Stimulation in Osage County, Oklahoma

    SciTech Connect (OSTI)

    J. Ford Brett; Robert V. Westermark

    2001-12-31

    This Technical Quarterly Report is for the reporting period September 30, 2001 to December 31, 2001. The report provides details of the work done on the project entitled ''Enhanced Oil Recovery with Downhole Vibration Stimulation in Osage County Oklahoma''. The project is divided into nine separate tasks. Several of the tasks are being worked on simultaneously, while other tasks are dependent on earlier tasks being completed. The vibration stimulation well was permitted as Well 111-W-27, section 8 T26N R6E Osage County Oklahoma. It was spud July 28, 2001 with Goober Drilling Rig No. 3. The well was drilled to 3090-feet cored, logged, cased and cemented. The Rig No.3 moved off August 6, 2001. Phillips Petroleum Co. has performed standard core analysis on the cores recovered from the test well. Standard porosity, permeability and saturation measurements have been conducted. Phillips has begun the sonic stimulation core tests. Calumet Oil Company, the operator of the NBU, has been to collecting both production and injection wells information to establish a baseline for the project in the pilot field test area since May 2001. The 7-inch Downhole Vibration Tool (DHVT) has been built and has been run in a shallow well for initial power source testing. This testing was done in a temporarily abandoned well, Wynona Waterflood Unit, Well No.20-12 operated by Calumet Oil Co both in October and December 2001. The data acquisition system, and rod rotating equipment performed as designed. However, the DHVT experienced two internal failures during vibration operations. The DHVT has been repaired with modifications to improve its functionality. A proposed technical paper abstract has been accepted by the SPE to be presented at the 2002 SPE/DOE Thirteenth Symposium on Improved Oil Recovery, in Tulsa OK, 13-17 April 2002. A one-day SPE sponsored short course which is planned to cover seismic stimulation efforts around the world, will be offered at the SPE/DOE Thirteenth Symposium on Improved Oil Recovery in Tulsa, OK, April 13-17, 2002. Dan Maloney, Phillips and Bob Westermark, OGCI will be the instructors.

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

    SciTech Connect (OSTI)

    Stanford University; Department of Energy Resources Engineering Green Earth Sciences

    2007-09-30

    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

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

    E-Print Network [OSTI]

    Bhagia, Nanik S

    1965-01-01

    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...

  19. Wettability and Oil Recovery by Imbibition and Viscous Displacement from Fractured and Heterogeneous Carbonates

    SciTech Connect (OSTI)

    Norman R. Morrow; Jill Buckley

    2006-04-01

    About one-half of U.S. oil reserves are held in carbonate formations. The remaining oil in carbonate reservoirs is regarded as the major domestic target for improved oil recovery. Carbonate reservoirs are often fractured and have great complexity even at the core scale. Formation evaluation and prediction is often subject to great uncertainty. This study addresses quantification of crude oil/brine/rock interactions and the impact of reservoir heterogeneity on oil recovery by spontaneous imbibition and viscous displacement from pore to field scale. Wettability-alteration characteristics of crude oils were measured at calcite and dolomite surfaces and related to the properties of the crude oils through asphaltene content, acid and base numbers, and refractive index. Oil recovery was investigated for a selection of limestones and dolomites that cover over three orders of magnitude in permeability and a factor of four variation in porosity. Wettability control was achieved by adsorption from crude oils obtained from producing carbonate reservoirs. The induced wettability states were compared with those measured for reservoir cores. The prepared cores were used to investigate oil recovery by spontaneous imbibition and viscous displacement. The results of imbibition tests were used in wettability characterization and to develop mass transfer functions for application in reservoir simulation of fractured carbonates. Studies of viscous displacement in carbonates focused on the unexpected but repeatedly observed sensitivity of oil recovery to injection rate. The main variables were pore structure, mobility ratio, and wettability. The potential for improved oil recovery from rate-sensitive carbonate reservoirs by increased injection pressure, increased injectivity, decreased well spacing or reduction of interfacial tension was evaluated.

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

    SciTech Connect (OSTI)

    Mark B. Murphy

    2002-09-30

    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.

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

    SciTech Connect (OSTI)

    Poston, S.W.

    1991-12-31

    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.

  2. Contracts for field projects and supporting research on enhanced oil recovery. Quarterly technical progress report, July 1, 1995--September 30, 1995

    SciTech Connect (OSTI)

    1996-10-01

    This document presents brief descriptions of research programs concerned with enhanced oil recovery.

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

    SciTech Connect (OSTI)

    Yorstos, Yannis C.

    2003-03-19

    The report describes progress made in the various thrust areas of the project, which include internal drives for oil recovery, vapor-liquid flows, combustion and reaction processes and the flow of fluids with yield stress.

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

    Office of Energy Efficiency and Renewable Energy (EERE)

    Oil and Gas Recovery Data from the Riser Insertion Tube from May 17 until the Riser Insertion Tube was disconnected on May 24 in preparation for cutting off the riser.

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

    Office of Energy Efficiency and Renewable Energy (EERE)

    Oil and Gas Recovery Data from the Riser Insertion Tube from May 17 until the Riser Insertion Tube was disconnected on May 24 in preparation for cutting off the riser.

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

    E-Print Network [OSTI]

    Nasralla, Ramez

    2013-05-02

    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 ...

  7. ENHANCED OIL RECOVERY WITH DOWNHOLE VIBRATION STIMULATION IN OSAGE COUNTY OKLAHOMA

    SciTech Connect (OSTI)

    Robert Westermark; J. Ford Brett

    2003-11-01

    This Final Report covers the entire project from July 13, 2000 to June 30, 2003. The report summarizes the details of the work done on the project entitled ''Enhanced Oil Recovery with Downhole Vibration Stimulation in Osage County Oklahoma'' under DOE Contract Number DE-FG26-00BC15191. The project was divided into nine separate tasks. This report is written in an effort to document the lessons learned during the completion of each task. Therefore each task will be discussed as the work evolved for that task throughout the duration of the project. Most of the tasks are being worked on simultaneously, but certain tasks were dependent on earlier tasks being completed. During the three years of project activities, twelve quarterly technical reports were submitted for the project. Many individual topic and task specific reports were included as appendices in the quarterly reports. Ten of these reports have been included as appendices to this final report. Two technical papers, which were written and accepted by the Society of Petroleum Engineers, have also been included as appendices. The three primary goals of the project were to build a downhole vibration tool (DHVT) to be installed in seven inch casing, conduct a field test of vibration stimulation in a mature waterflooded field and evaluate the effects of the vibration on both the produced fluid characteristics and injection well performance. The field test results are as follows: In Phase I of the field test the DHVT performed exceeding well, generating strong clean signals on command and as designed. During this phase Lawrence Berkeley National Laboratory had installed downhole geophones and hydrophones to monitor the signal generated by the downhole vibrator. The signals recorded were strong and clear. Phase II was planned to be ninety-day reservoir stimulation field test. This portion of the field tests was abruptly ended after one week of operations, when the DHVT became stuck in the well during a routine removal activity. The tool cannot operate in this condition and remains in the well. There was no response measured during or afterwards to either the produced fluids from the five production wells or in the injection characteristics of the two injection wells in the pilot test area. Monitoring the pilot area injection and production wells ceased when the field test was terminated March 14, 2003. Thus, a key goal of this project, which was to determine the effects of vibration stimulation on improving oil recovery from a mature waterflood, was not obtained. While there was no improved oil recovery effect measured, there was insufficient vibration stimulation time to expect a change to occur. No conclusion can be drawn about the effectiveness of vibration stimulation in this test.

  8. Supporting technology for enhanced oil recovery for thermal processes

    SciTech Connect (OSTI)

    Reid, T.B.; Bolivar, J.

    1997-12-01

    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, eighth, 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-90/1/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 1987, November 1988, October 1991, February 1993, and March 1995 respectively.

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

    E-Print Network [OSTI]

    Arnold, Marion Denson

    1959-01-01

    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...

  10. Development of on-farm oil recovery and processing methods: Final report

    SciTech Connect (OSTI)

    Goodrum, J.W.; Kilgo, M.B.

    1987-09-02

    Using supercritical carbon dioxide (SC-CO2), peanut oil was extracted from ground peanuts at pressures of 2000 to 10,000 psi and temperatures of 25-120/degree/ C. Above 6000 psi, increasing the temperature to the maximum possible without heavily charring the peanuts (120/degree/C) significantly increased the initial extraction rate. Increasing the pressure at constant temperature increased the rate. At higher temperatures (75/degree/ C and above) roasting began to occur, however, this was not detrimental to the extraction rate or overall oil recovery. Decreasing the particle size increases the overall yield per batch of peanuts as seen in both the half factorial and particle size experiments. Increasing the moisture increases the amount of volatiles lost. The flow rate does not affect the solubility, percent oil recovered or volatiles lost for flow rates of 40 to 60 liters CO2/minute at STP. Recovery of peanut and rapeseed oil with a combined process of partial recovery in a screw press plus extraction of the remaining oil with SC-CO2 is technically a viable alternative to other oil recovery methods. Oil recoveries of 95% (peanuts) and 75% (rapeseed) have been demonstrated. The initial extraction rate for rapeseed was consistently lower than the rate for peanuts at the same extraction temperature and pressure. No differences in SC-CO2 extraction rates or yields were found between Dwarf Essex and Cascade varieties of rapeseed. 8 refs., 17 figs., 5 tabs.

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

    SciTech Connect (OSTI)

    1997-10-01

    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.

  12. ECMOR XIV 14th European Conference on the Mathematics of Oil Recovery

    E-Print Network [OSTI]

    Van den Hof, Paul

    for VOI assessment in real fields. #12;ECMOR XIV ­ 14th European Conference on the Mathematics of OilECMOR XIV ­ 14th European Conference on the Mathematics of Oil Recovery Catania, Sicily, Italy, 8 on other measures of information valuation, and we show that our method is a more complete, although also

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

    SciTech Connect (OSTI)

    Armstrong, Ryan T.; Wildenschild, Dorthe

    2012-10-24

    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.

  14. Review of technology for Arctic offshore oil and gas recovery

    SciTech Connect (OSTI)

    Sackinger, W. M.

    1980-08-01

    The technical background briefing report is the first step in the preparation of a plan for engineering research oriented toward Arctic offshore oil and gas recovery. A five-year leasing schedule for the ice-prone waters of the Arctic offshore is presented, which also shows the projected dates of the lease sale for each area. The estimated peak production rates for these areas are given. There is considerable uncertainty for all these production estimates, since no exploratory drilling has yet taken place. A flow chart is presented which relates the special Arctic factors, such as ice and permafrost, to the normal petroleum production sequence. Some highlights from the chart and from the technical review are: (1) in many Arctic offshore locations the movement of sea ice causes major lateral forces on offshore structures, which are much greater than wave forces; (2) spray ice buildup on structures, ships and aircraft will be considerable, and must be prevented or accommodated with special designs; (3) the time available for summer exploratory drilling, and for deployment of permanent production structures, is limited by the return of the pack ice. This time may be extended by ice-breaking vessels in some cases; (4) during production, icebreaking workboats will service the offshore platforms in most areas throughout the year; (5) transportation of petroleum by icebreaking tankers from offshore tanker loading points is a highly probable situation, except in the Alaskan Beaufort; and (6) Arctic pipelines must contend with permafrost, making instrumentation necessary to detect subtle changes of the pipe before rupture occurs.

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

    SciTech Connect (OSTI)

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

    1993-08-01

    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.

  16. 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)

    Tiedemann, H.A. )

    1991-03-01

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

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

    SciTech Connect (OSTI)

    Not Available

    1993-12-31

    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.

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

    SciTech Connect (OSTI)

    Tyler, R.; Major, R.P.; Holtz, M.H.

    1997-08-01

    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.

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

    SciTech Connect (OSTI)

    NONE

    1997-12-01

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

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

    SciTech Connect (OSTI)

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

    2000-04-30

    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.

  1. Surfactant-Polymer Interaction for Improved Oil Recovery

    SciTech Connect (OSTI)

    Gabitto, Jorge; Mohanty, Kishore K.

    2002-01-07

    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.

  2. The recovery of crude oil spilled on a ground water aquifer 

    E-Print Network [OSTI]

    Malter, Paul Lawrence

    1983-01-01

    THE RECOVERY OF CRUDE OIL SPILLED ON A GROUND WATER AQUIFER A Thesis by PAUL LAWRENCE MALTER Approved as to style and content by: oy W, ann, J (Ch irman of Committee) / Dona McDona (Head of Department) as (Me ) 0 s Le a . ~e e (Member...) May 1983 ABSTRACT The Recovery of Crude Oil Spilled on a Ground Water Aquifer. (Nay 1983) Paul Lawrence Malter, B. S. , Texas A6K University Chairman of Advisory Committee: Roy W. Bann, Jr. Case histories of previous petroleum spill cleanups...

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

    DOE Patents [OSTI]

    Rao, Dandina N. (Baton Rouge, LA)

    2012-07-10

    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).

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

    SciTech Connect (OSTI)

    Not Available

    1995-02-01

    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.

  5. Oil recovery from naturally fractured reservoirs by steam injection methods. Final report

    SciTech Connect (OSTI)

    Reis, J.C.; Miller, M.A.

    1995-05-01

    Oil recovery by steam injection is a proven, successful technology for nonfractured reservoirs, but has received only limited study for fractured reservoirs. Preliminary studies suggest recovery efficiencies in fractured reservoirs may be increased by as much as 50% with the application of steam relative to that of low temperature processes. The key mechanisms enhancing oil production at high temperature are the differential thermal expansion between oil and the pore volume, and the generation of gases within matrix blocks. Other mechanisms may also contribute to increased production. These mechanisms are relatively independent of oil gravity, making steam injection into naturally fractured reservoirs equally attractive to light and heavy oil deposits. The objectives of this research program are to quantify the amount of oil expelled by these recovery mechanisms and to develop a numerical model for predicting oil recovery in naturally fractured reservoirs during steam injection. The experimental study consists of constructing and operating several apparatuses to isolate each of these mechanisms. The first measures thermal expansion and capillary imbibition rates at relatively low temperature, but for various lithologies and matrix block shapes. The second apparatus measures the same parameters, but at high temperatures and for only one shape. A third experimental apparatus measures the maximum gas saturations that could build up within a matrix block. A fourth apparatus measures thermal conductivity and diffusivity of porous media. The numerical study consists of developing transfer functions for oil expulsion from matrix blocks to fractures at high temperatures and incorporating them, along with the energy equation, into a dual porosity thermal reservoir simulator. This simulator can be utilized to make predictions for steam injection processes in naturally-fractured reservoirs. Analytical models for capillary imbibition have also been developed.

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

    SciTech Connect (OSTI)

    Penner, S.S.

    1981-03-01

    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.

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

    SciTech Connect (OSTI)

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

    2006-09-30

    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.

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

    E-Print Network [OSTI]

    Musharova, Darya

    2010-07-14

    beneficial effect for the buildup water viscosity in EOR. The results show that acidic number of crude oil is a critical parameter that affects the optimal concentration for mixing chemicals and interfacial tension profile. The alkali and surfactant added...

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

    SciTech Connect (OSTI)

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

    2001-09-07

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

  10. Performance evaluation of starch based polymer for enhanced oil recovery 

    E-Print Network [OSTI]

    Skurner, James Andrew

    1997-01-01

    Ever since the first petroleum well was drilled, water production has been a deterring force in maximizing an oilfield's hydrocarbon reserves. To satisfy the ever increasing global demand for petroleum, many different techniques for enhancing oil...

  11. BIOTIGER, A NATURAL MICROBIAL PRODUCT FOR ENHANCED HYDROCARBON RECOVERY FROM OIL SANDS.

    SciTech Connect (OSTI)

    Brigmon, R; Topher Berry, T; Whitney Jones, W; Charles Milliken, C

    2008-05-27

    BioTiger{trademark} is a unique microbial consortia that resulted from over 8 years of extensive microbiology screening and characterization of samples collected from a century-old Polish waste lagoon. BioTiger{trademark} shows rapid and complete degradation of aliphatic and aromatic hydrocarbons, produces novel surfactants, is tolerant of both chemical and metal toxicity and shows good activity at temperature and pH extremes. Although originally developed and used by the U.S. Department of Energy for bioremediation of oil-contaminated soils, recent efforts have proven that BioTiger{trademark} can also be used to increase hydrocarbon recovery from oil sands. This enhanced ex situ oil recovery process utilizes BioTiger{trademark} to optimize bitumen separation. A floatation test protocol with oil sands from Ft. McMurray, Canada was used for the BioTiger{trademark} evaluation. A comparison of hot water extraction/floatation test of the oil sands performed with BioTiger{trademark} demonstrated a 50% improvement in separation as measured by gravimetric analysis in 4 h and a five-fold increase at 25 hr. Since BioTiger{trademark} performs well at high temperatures and process engineering can enhance and sustain metabolic activity, it can be applied to enhance recovery of hydrocarbons from oil sands or other complex recalcitrant matrices.

  12. 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)

    Murphy, Mark B.

    2002-01-16

    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.

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

    SciTech Connect (OSTI)

    Murphy, Mark B.

    1999-11-01

    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.

  14. 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)

    Murphy, Michael B.

    2002-02-21

    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.

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

    SciTech Connect (OSTI)

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

    2007-09-30

    The long-term economic potential for enhanced oil recovery (EOR) is large with more than 300 billion barrels of oil remaining in domestic reservoirs after conventional technologies reach their economic limit. Actual EOR production in the United States has never been very large, less than 10% of the total U. S. production even though a number of economic incentives have been used to stimulate the development and application of EOR processes. The U.S. DOE Reservoir Data Base contains more than 600 reservoirs with over 12 billion barrels of unrecoverable oil that are potential targets for microbially enhanced oil recovery (MEOR). If MEOR could be successfully applied to reduce the residual oil saturation by 10% in a quarter of these reservoirs, more than 300 million barrels of oil could be added to the U.S. oil reserve. This would stimulate oil production from domestic reservoirs and reduce our nation's dependence on foreign imports. Laboratory studies have shown that detergent-like molecules called biosurfactants, which are produced by microorganisms, are very effective in mobilizing entrapped oil from model test systems. The biosurfactants are effective at very low concentrations. Given the promising laboratory results, it is important to determine the efficacy of using biosurfactants in actual field applications. The goal of this project is to move biosurfactant-mediated oil recovery from laboratory investigations to actual field applications. In order to meet this goal, several important questions must be answered. First, it is critical to know whether biosurfactant-producing microbes are present in oil formations. If they are present, then it will be important to know whether a nutrient regime can be devised to stimulate their growth and activity in the reservoir. If biosurfactant producers are not present, then a suitable strain must be obtained that can be injected into oil reservoirs. We were successful in answering all three questions. The specific objectives of the project were (1) to determine the prevalence of biosurfactant producers in oil reservoirs, and (2) to develop a nutrient regime that would stimulate biosurfactant production in the oil reservoir.

  16. 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)

    Kabadi, V.N.

    1992-10-01

    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.

  17. Shale Gas Production Theory and Case Analysis We researched the process of oil recovery and shale gas

    E-Print Network [OSTI]

    Huang, Xun

    Shale Gas Production Theory and Case Analysis (Siemens) We researched the process of oil recovery and shale gas recovery and compare the difference between conventional and unconventional gas reservoir and recovery technologies. Then we did theoretical analysis on the shale gas production. According

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

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Analysis of Heavy Oil Recovery by Thermal EOR in a Meander Belt: From Geological to Reservoir- zation of fluvial meandering reservoirs and petrophysical properties are required for uncertainty Modeling R. Deschamps*, N. Guy, C. Preux and O. Lerat 1 IFP Energies nouvelles, 1-4 avenue de Bois

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

    E-Print Network [OSTI]

    Rueda Silva, Carlos Fernando

    2003-01-01

    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...

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

    E-Print Network [OSTI]

    Ferguson,Mark Anthony

    2000-01-01

    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...

  1. Research on improved and enhanced oil recovery in Illinois through reservoir characterization

    SciTech Connect (OSTI)

    Not Available

    1990-06-25

    The Illinois Department of Energy and Natural Resources through a Memorandum of Understanding with the US Department of Energy has commenced a research program in Improved and Enhanced Oil Recovery from Illinois Reservoirs Through Reservoir Characterization.'' The program will include studies on mineralogy, petrography of reservoir rock, database management, engineering assessment, seismic studies and acoustic logs, and mapping. 8 figs. (CBS)

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

    SciTech Connect (OSTI)

    Eric P. Robertson

    2007-11-01

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

  3. Near Miscible CO2 Application to Improve Oil Recovery

    E-Print Network [OSTI]

    Bui, Ly H.

    2010-07-26

    control due to the reduction of oil viscosity. This suggested that application of carbon dioxide in the field would require injection and recycling of large volumes of carbon dioxide. Further study is needed to determine if such a process is economically...

  4. Augmenting a Microbial Selective Plugging Technique with Polymer Flooding to Increase the Efficiency of Oil Recovery - A Search for Synergy

    SciTech Connect (OSTI)

    Brown, Lewis R.; Pittman Jr., Charles U.; Lynch, F. Leo; Vadie, A. Alex

    2003-02-10

    The overall objective of this project was to improve the effectiveness of a microbial selective plugging technique of improving oil recovery through the use of polymer floods. More specifically, the intent was to increase the total amount of oil recovered and to reduce the cost per barrel of incremental oil.

  5. Microbial Enhanced Oil Recovery and Wettability Research Program. Annual report, FY 1991

    SciTech Connect (OSTI)

    Bala, G.A.; Barrett, K.B.; Eastman, S.L.; Herd, M.D.; Jackson, J.D.; Robertson, E.P.; Thomas, C.P.

    1993-09-01

    This report covers research results for fiscal year 1991 for the Microbial Enhanced Oil Recovery (MEOR) and Wettability Research Program conducted by EG&G Idaho, Inc. at the Idaho National Engineering Laboratory ONEL) for the US Department of Energy Idaho Field Office (DOE-ID). The program is funded by the Assistant Secretary of Fossil Energy, and managed by DOE-ID and the Bartlesville Project Office (BPO). The objectives of this multi-year program are to develop MEOR systems for application to reservoirs containing medium to heavy crude oils and to design and implement an industry cost-shared field demonstration project of the developed technology. An understanding of the controlling mechanisms will first be developed through the use of laboratory scale testing to determine the ability of microbially mediated processes to recover oil under reservoir conditions and to develop the design criteria for scale-up to the field. Concurrently with this work, 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. Research focus includes the study of biogenic product and formation souring processes including mitigation and prevention. Souring research performed in FY 1991 also included the development of microsensor probe technology for the detection of total sulfide in collaboration with the Montana State University Center for Interfacial Microbial Process Engineering (CIMPE). Wettability research is a multi-year collaborative effort with the New Mexico Petroleum Recovery Research Center (NMPRRC) at the New Mexico institute of Mining and Technology, Socorro, NM 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.

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

    SciTech Connect (OSTI)

    Tiedemann, H.A. )

    1991-05-01

    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.

  7. Improved techniques for fluid diversion in oil recovery. Final report

    SciTech Connect (OSTI)

    Seright, R.

    1996-01-01

    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.

  8. Activities of the Oil Implementation Task Force, reporting period March--August 1991; Contracts for field projects and supporting research on enhanced oil recovery, reporting period October--December 1990

    SciTech Connect (OSTI)

    Not Available

    1991-10-01

    Activities of DOE's Oil Implementation Task Force for the period March--August 1991 are reviewed. Contracts for fields projects and supporting research on enhanced oil recovery are discussed, with a list of related publications given. Enhanced recovery processes covered include chemical flooding, gas displacement, thermal recovery, and microbial recovery.

  9. CP Based Tool for Tightening the MILP Relaxation of a Crude-Oil Operations Scheduling MINLP

    E-Print Network [OSTI]

    Grossmann, Ignacio E.

    CP Based Tool for Tightening the MILP Relaxation of a Crude-Oil Operations Scheduling MINLP Sylvain;Introduction Goals Optimize the schedule of operations for the crude-oil unloading and blending problem using the MILP relaxation of the MINLP 1 / 14 #12;Crude-oil operations scheduling problem Scheduling horizon [0

  10. A CP Based Branching Tool for Breaking Symmetries in Crude-Oil Operations Scheduling

    E-Print Network [OSTI]

    Grossmann, Ignacio E.

    A CP Based Branching Tool for Breaking Symmetries in Crude-Oil Operations Scheduling Sylvain Mouret Goals Optimize the schedule of operations for the crude-oil unloading and blending problem using in the MINLP model Use CP inference techniques to improve performance 1 / 14 #12;Crude-oil operations

  11. A Symmetry-Breaking Tool for the Optimization of Crude-Oil Operations Scheduling

    E-Print Network [OSTI]

    Grossmann, Ignacio E.

    A Symmetry-Breaking Tool for the Optimization of Crude-Oil Operations Scheduling Sylvain Mouret the schedule of operations for the crude-oil unloading and blending problem using a continuous and Mann (2003) #12;Crude-oil operations scheduling problem Scheduling horizon [0, H] 4 types of resources

  12. An experimental and theoretical study to relate uncommon rock/fluid properties to oil recovery. Final report

    SciTech Connect (OSTI)

    Watson, R.

    1995-07-01

    Waterflooding is the most commonly used secondary oil recovery technique. One of the requirements for understanding waterflood performance is a good knowledge of the basic properties of the reservoir rocks. This study is aimed at correlating rock-pore characteristics to oil recovery from various reservoir rock types and incorporating these properties into empirical models for Predicting oil recovery. For that reason, this report deals with the analyses and interpretation of experimental data collected from core floods and correlated against measurements of absolute permeability, porosity. wettability index, mercury porosimetry properties and irreducible water saturation. The results of the radial-core the radial-core and linear-core flow investigations and the other associated experimental analyses are presented and incorporated into empirical models to improve the predictions of oil recovery resulting from waterflooding, for sandstone and limestone reservoirs. For the radial-core case, the standardized regression model selected, based on a subset of the variables, predicted oil recovery by waterflooding with a standard deviation of 7%. For the linear-core case, separate models are developed using common, uncommon and combination of both types of rock properties. It was observed that residual oil saturation and oil recovery are better predicted with the inclusion of both common and uncommon rock/fluid properties into the predictive models.

  13. Research on improved and enhanced oil recovery in Illinois through reservoir characterization

    SciTech Connect (OSTI)

    Oltz, D.F.

    1992-01-01

    This project will provide information that can maximize hydrocarbon production minimize formation damage and stimulate new production in Illinois. Such information includes definition of hydrocarbon resources, characterization of hydrocarbon reservoirs, and the implementation of methods that will improve hydrocarbon extractive technology. Increased understanding of reservoir heterogeneities that affect oil recovery can aid in identifying producible resources. The transfer of technology to industry and the general public is a significant component of the program. The project is designed to examine selected subsurface oil reservoirs in Illinois. Scientists use advanced scientific techniques to gain a better understanding of reservoir components and behavior and address ways of potentially increasing the amount of recoverable oil. Initial production rates for wells in the Illinois Basin commonly decline quite rapidly and as much as 60 percent of the oil in place can be unrecoverable using standard operating procedures. Heterogeneities (geological differences in reservoir make-up) affect a reservoir's capability to release fluids. By-passed mobile and immobile oil remain in the reservoir. To learn how to get more of the oil out of reservoirs, the ISGS is studying the nature of reservoir rock heterogeneities and their control on the distribution and production of by-passed, mobile oil.

  14. Sacrificial adsorbate for surfactants utilized in chemical floods of enhanced oil recovery operations

    DOE Patents [OSTI]

    Johnson, J.S. Jr.; Westmoreland, C.G.

    1980-08-20

    The present invention is directed to a sacrificial or competitive adsorbate for surfactants contained in chemical flooding emulsions for enhanced oil recovery operations. The adsorbate to be utilized in the method of the present invention is a caustic effluent from the bleach stage or the weak black liquor from the digesters and pulp washers of the kraft pulping process. This effluent or weak black liquor is injected into an oil-bearing subterranean earth formation prior to or concurrent with the chemical flood emulsion and is adsorbed on the active mineral surfaces of the formation matrix so as to effectively reduce adsorption of surfactant in the chemical flood. Alternatively, the effluent or liquor can be injected into the subterranean earth formation subsequent to a chemical flood to displace the surfactant from the mineral surfaces for the recovery thereof.

  15. Sacrificial adsorbate for surfactants utilized in chemical floods of enhanced oil recovery operations

    DOE Patents [OSTI]

    Johnson, Jr., James S. (Oak Ridge, TN); Westmoreland, Clyde G. (Rockwood, TN)

    1982-01-01

    The present invention is directed to a sacrificial or competitive adsorbate for surfactants contained in chemical flooding emulsions for enhanced oil recovery operations. The adsorbate to be utilized in the method of the present invention is a caustic effluent from the bleach stage or the weak black liquor from the digesters and pulp washers of the kraft pulping process. This effluent or weak black liquor is injected into an oil-bearing subterranean earth formation prior to or concurrent with the chemical flood emulsion and is adsorbed on the active mineral surfaces of the formation matrix so as to effectively reduce adsorption of surfactant in the chemical flood. Alternatively, the effluent or liquor can be injected into the subterranean earth formation subsequent to a chemical flood to displace the surfactant from the mineral surfaces for the recovery thereof.

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

    SciTech Connect (OSTI)

    Not Available

    1984-01-01

    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.

  17. Phase behavior and oil recovery investigations using mixed and alkaline-enhanced surfactant systems

    SciTech Connect (OSTI)

    Llave, F.M.; Gall, B.L.; French, T.R.; Noll, L.A.; Munden, S.A.

    1992-03-01

    The results of an evaluation of different mixed surfactant and alkaline-enhanced surfactant systems for enhanced oil recovery are described. Several mixed surfactant systems have been studies to evaluate their oil recovery potential as well as improved adaptability to different ranges of salinity, divalent ion concentrations, and temperature. Several combinations of screening methods were used to help identify potential chemical formulations and determine conditions where particular chemical systems can be applied. The effects of different parameters on the behavior of the overall surfactant system were also studied. Several commercially available surfactants were tested as primary components in the mixtures used in the study. These surfactants were formulated with different secondary as well as tertiary components, including ethoxylated and non-ethoxylated sulfonates and sulfates. Improved salinity and hardness tolerance was achieved for some of these chemical systems. The salinity tolerance of these systems were found to be dependent on the molecular weight, surfactant type, and concentration of the surfactant components.

  18. 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)

    Not Available

    1994-11-01

    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.

  19. An evaluation of known remaining oil resources in the state of Kansas and Oklahoma. Volume 5, Project on Advanced Oil Recovery and the States

    SciTech Connect (OSTI)

    Not Available

    1994-11-01

    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 Kansas, Illinois and Oklahoma for five 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 Kansas` 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 state of Kansas, Illinois and Oklahoma and the nation as a whole.

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

    E-Print Network [OSTI]

    Jamili, Ahmad

    2010-04-22

    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...

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

    SciTech Connect (OSTI)

    Castle, James W.; Molz, Fred J.; Brame, Scott; Current, Caitlin J.

    2003-02-07

    Improved prediction of interwell reservoir heterogeneity was 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.

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

    SciTech Connect (OSTI)

    Castle, James W.; Molz, Fred J.

    2003-02-07

    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.

  3. A study of the effect of process variables on forward combustion oil recovery 

    E-Print Network [OSTI]

    Berry, Holland James

    1966-01-01

    in following years, the publication by Kuhn and 3. Koch in 1953 outlining results of laboratory and field experiments with the forward combustion process demonstrated a modern interest in thermal recovery of major importance. Their work proved that a.... 4. Grant and Szasz, in 1954, presented a paper demonstrating the feasibility of creating and propagating a combustion- supported heat wave through an oil-bearing reservoir in the Delaware-Childers Field, Nowata County, Oklahoma. Methods used...

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

    E-Print Network [OSTI]

    Fineout, James Mark

    1992-01-01

    , they developed both a single matrix block model and a dual matrix block model with variable fracture width. These tests related imbibition theory with regard to matrix block size, permeability and fluid viscosity affects on oil recovery. They also determined... in naturally fractured reservoirs have relied upon material balance calculations to determine saturation changes. Through the use of Computed Tomography scanning, we have developed a technique not only to determine saturation changes but also positional...

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

    SciTech Connect (OSTI)

    Yortsos, Y.C.

    2001-05-29

    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.

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

    SciTech Connect (OSTI)

    Adams, D.C.

    1992-12-31

    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.

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

    SciTech Connect (OSTI)

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

    1997-07-15

    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.

  8. Advanced oil recovery technologies for improved recovery from slope basin clastic reservoirs, Nash Draw Brushy Canyon Pool, Eddy County, NM. Quarterly technical progress report

    SciTech Connect (OSTI)

    Murphy, M.B.

    1996-04-22

    The overall objective of this project is to demonstrate that 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 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. This is the second quarterly progress report on the project. Results obtained to date are summarized.

  9. Cost Effective Surfactant Formulations for Improved Oil Recovery in Carbonate Reservoirs

    SciTech Connect (OSTI)

    William A. Goddard; Yongchun Tang; Patrick Shuler; Mario Blanco; Yongfu Wu

    2007-09-30

    This report summarizes work during the 30 month time period of this project. This was planned originally for 3-years duration, but due to its financial limitations, DOE halted funding after 2 years. The California Institute of Technology continued working on this project for an additional 6 months based on a no-cost extension granted by DOE. The objective of this project is to improve the performance of aqueous phase formulations that are designed to increase oil recovery from fractured, oil-wet carbonate reservoir rock. This process works by increasing the rate and extent of aqueous phase imbibition into the matrix blocks in the reservoir and thereby displacing crude oil normally not recovered in a conventional waterflood operation. The project had three major components: (1) developing methods for the rapid screening of surfactant formulations towards identifying candidates suitable for more detailed evaluation, (2) more fundamental studies to relate the chemical structure of acid components of an oil and surfactants in aqueous solution as relates to their tendency to wet a carbonate surface by oil or water, and (3) a more applied study where aqueous solutions of different commercial surfactants are examined for their ability to recover a West Texas crude oil from a limestone core via an imbibition process. The first item, regarding rapid screening methods for suitable surfactants has been summarized as a Topical Report. One promising surfactant screening protocol is based on the ability of a surfactant solution to remove aged crude oil that coats a clear calcite crystal (Iceland Spar). Good surfactant candidate solutions remove the most oil the quickest from the surface of these chips, plus change the apparent contact angle of the remaining oil droplets on the surface that thereby indicate increased water-wetting. The other fast surfactant screening method is based on the flotation behavior of powdered calcite in water. In this test protocol, first the calcite power is pre-treated to make the surface oil-wet. The next step is to add the pre-treated powder to a test tube and add a candidate aqueous surfactant formulation; the greater the percentage of the calcite that now sinks to the bottom rather than floats, the more effective the surfactant is in changing the solids to become now preferentially water-wet. Results from the screening test generally are consistent with surfactant oil recovery performance reported in the literature. The second effort is a more fundamental study. It considers the effect of chemical structures of different naphthenic acids (NA) dissolved in decane as model oils that render calcite surfaces oil-wet to a different degree. NAs are common to crude oil and are at least partially responsible for the frequent observation that carbonate reservoirs are oil-wet. Because pure NA compounds are used, trends in wetting behavior can be related to NA molecular structure as measured by solid adsorption, contact angle and our novel, simple flotation test with calcite. Experiments with different surfactants and NA-treated calcite powder provide information about mechanisms responsible for sought after reversal to a water-wet state. Key findings include: (1) more hydrophobic NA's are more prone to induce oil-wetting, and (2) recovery of the model oil from limestone core was better with cationic surfactants, but one nonionic surfactant, Igepal CO-530, also had favorable results. This portion of the project included theoretical calculations to investigate key basic properties of several NAs such as their acidic strength and their relative water/oil solubility, and relate this to their chemical structure. The third category of this project focused on the recovery of a light crude oil from West Texas (McElroy Field) from a carbonate rock (limestone outcrop). For this effort, the first item was to establish a suite of surfactants that would be compatible with the McElroy Field brine. Those were examined further for their ability to recover oil by imbibition. Results demonstrate several types of promising candida

  10. An evaluation of known remaining oil resources in the state of New Mexico: Project on advanced oil recovery and the states. Volume 6

    SciTech Connect (OSTI)

    NONE

    1993-11-01

    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 New Mexico. 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 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 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, New Mexico 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 New Mexico and the nation as a whole.

  11. An evaluation of known remaining oil resources in the state of Oklahoma: Project on advanced oil recovery and the states. Volume 7

    SciTech Connect (OSTI)

    NONE

    1993-11-01

    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 Oklahoma. 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 Oklahoma`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, Oklahoma 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 Oklahoma and the nation as a whole.

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

    SciTech Connect (OSTI)

    NONE

    1993-11-01

    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.

  13. An evaluation of known remaining oil resources in the state of Kansas: Project on advanced oil recovery and the states. Volume 4

    SciTech Connect (OSTI)

    NONE

    1993-11-01

    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 Kansas. 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, Kansas oil production could be maximized. The resulting increase in production rates, employment, operator profits, state and Federal tax revenues, energy security will benefit the state of Kansas and the nation as a whole.

  14. Integrated Mid-Continent Carbon Capture, Sequestration & Enhanced Oil Recovery Project

    SciTech Connect (OSTI)

    Brian McPherson

    2010-08-31

    A consortium of research partners led by the Southwest Regional Partnership on Carbon Sequestration and industry partners, including CAP CO2 LLC, Blue Source LLC, Coffeyville Resources, Nitrogen Fertilizers LLC, Ash Grove Cement Company, Kansas Ethanol LLC, Headwaters Clean Carbon Services, Black & Veatch, and Schlumberger Carbon Services, conducted a feasibility study of a large-scale CCS commercialization project that included large-scale CO{sub 2} sources. The overall objective of this project, entitled the 'Integrated Mid-Continent Carbon Capture, Sequestration and Enhanced Oil Recovery Project' was to design an integrated system of US mid-continent industrial CO{sub 2} sources with CO{sub 2} capture, and geologic sequestration in deep saline formations and in oil field reservoirs with concomitant EOR. Findings of this project suggest that deep saline sequestration in the mid-continent region is not feasible without major financial incentives, such as tax credits or otherwise, that do not exist at this time. However, results of the analysis suggest that enhanced oil recovery with carbon sequestration is indeed feasible and practical for specific types of geologic settings in the Midwestern U.S.

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

    SciTech Connect (OSTI)

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

    1995-03-01

    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.

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

    SciTech Connect (OSTI)

    Not Available

    1989-08-01

    This report analyzes the economics of producing syncrude from oil shale combining underground and surface processing using Occidental's Modified-In-Situ (MIS) technology and Lawrence Livermore National Laboratory's (LLNL) Hot Recycled Solids (HRS) retort. These retorts form the basic technology employed for oil extraction from oil shale in this study. Results are presented for both Commercial and Pre-commercial programs. Also analyzed are Pre-commercialization cost of Demonstration and Pilot programs which will confirm the HRS and MIS concepts and their mechanical designs. These programs will provide experience with the circulating Fluidized Bed Combustor (CFBC), the MIS retort, the HRS retort and establish environmental control parameters. Four cases are considered: commercial size plant, demonstration size plant, demonstration size plant minimum CFBC, and a pilot size plant. Budget cost estimates and schedules are determined. Process flow schemes and basic heat and material balances are determined for the HRS system. Results consist of summaries of major equipment sizes, capital cost estimates, operating cost estimates and economic analyses. 35 figs., 35 tabs.

  17. 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)

    Kabadi, V.N.

    1992-10-01

    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.

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

    E-Print Network [OSTI]

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

    2013-01-01

    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...

  19. Contracts for field projects and supporting research on enhanced oil recovery. Quarterly progress review No. 85, October 1, 1995--December 31, 1995

    SciTech Connect (OSTI)

    Godley, P.; Waisley, S.

    1996-12-01

    This documents presents progress on enhanced oil recovery programs and reservoir characterization programs. Information is presented on contract numbers, awards, investigators, and project managers.

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

    DOE Patents [OSTI]

    Robertson, Eric P

    2011-05-24

    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.

  1. Water-soluble hydrophobically associating polymers for improved oil recovery: A literature review

    SciTech Connect (OSTI)

    Taylor, K.C. [Petroleum Recovery Inst., Calgary, Alberta (Canada); Nasr-El-Din, H.A. [Saudi Aramco, Dhahran (Saudi Arabia)

    1995-11-01

    Water-soluble hydrophobically associating polymers are reviewed with particular emphasis on their application in improved oil recovery (IOR). These polymers are very similar to conventional water-soluble polymers used in IOR, except that they have a small number of hydrophobic groups incorporated into the polymer backbone. At levels of incorporation of less than 1 mol%, these hydrophobic groups can significantly change polymer performance. These polymers have potential for use in mobility control, drilling fluids and profile modification. This review includes synthesis, characterization, stability, rheology and flow in porous media of associating polymers in IOR are also examined. 100 refs., 2 tabs.

  2. Improved Oil Recovery in Mississippian Carbonate Reservoirs of Kansas -- Near-Term -- Class

    SciTech Connect (OSTI)

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

    1999-10-29

    The objective of this project is to demonstrate incremental reserves from Osagian and Meramecian (Mississippian) dolomite reservoirs in western Kansas through application of reservoir characterization to identify areas of unrecovered mobile oil. The project addresses producibility problems in two fields: Specific reservoirs target the Schaben Field in Ness County, Kansas, and the Bindley Field in Hodgeman County, Kansas. The producibility problems to be addressed include inadequate reservoir characterization, drilling and completion design problems, non-optimum recovery efficiency. The results of this project will be disseminated through various technology transfer activities. At the Schaben demonstration site, the Kansas team will conduct a field project to demonstrate better approaches to identify bypassed oil within and between reservoir units.

  3. Improved oil recovery in mature fields through reservoir characterization and management

    SciTech Connect (OSTI)

    Leetaru, H.E. (Illinois State Geological Survey, Champaign, IL (United States))

    1993-09-01

    The Illinois basin is mature with respect to hydrocarbon exploitation in the Pennsylvanian and Mississippian strata. Available subsurface data for the basin commonly are 30 to 50 yr old and of lower quality than today's state-of-the-art data. Recent evaluation of two geologically similar Illinois oil fields shows how the application of new concepts and technologies to the old data can be used to improve oil recovery. Boyd and King fields, located in Jefferson County, Illinois, produce from the Mississippian Aux Vases formation, a unit that was deposited in nearshore mixed siliciclastic-carbonate environments. Prospective areas for further development were delineated by conventional reservoir-characterization methods. Three-dimensional modeling was used to enhance visualization of the lateral and vertical heterogeneity of these reservoirs. At King field, mixing of intercalated siliciclastic-carbonate facies causes significant reservoir heterogeneity; numerous compartments have been bypassed by the existing waterflood. Targeted infill drilling of additional producing and injector wells should recover 1-2 million bbl of additional hydrocarbons. At Boyd field, delineation of areas that contain bypassed oil is more difficult because many of the wells have not penetrated the entire reservoir. An additional problem is that almost all of the production from the original Aux Vases wells was severely inhibited by backflow from a higher pressured, shallower reservoir with which it is commingled. In this type of field, reservoir management must focus on isolating the Aux Vases, producing intervals and deepening individual wells through the entire reservoir. The study of these two fields suggests that detailed geologic characterization of the internal reservoir architecture is not enough. Effective reservoir characterization for improved oil recovery must include both reservoir geology and an understanding of previous reservoir management techniques.

  4. Secondary oil recovery from selected Carter sandstone oilfields--Black Warrior Basin, Alabama. Final report

    SciTech Connect (OSTI)

    Anderson, J.C.

    1995-02-01

    Producibility problems, such as low reservoir pressure and reservoir heterogeneity, have severely limited oil production from the Central Bluff and North Fairview fields. Specific objectives for this project were: To successfully apply detailed geologic and engineering studies with conventional waterflood technologies to these fields in an effort to increase the ultimate economic recovery of oil from Carter sandstone fields; To extensively model, test and evaluate these technologies; thereby, developing a sound methodology for their use and optimization; and To team with Advanced Resources International and the US DOE to assimilate and transfer the information and results gathered from this study to other oil companies to encourage the widespread use of these technologies. At Central Bluff, water injection facilities were constructed and water injection into one well began in January 1993. Oil response from the waterflood has been observed at both producing wells. One of the producing wells has experienced early water breakthrough and a concomitant drop in secondary oil rate. A reservoir modeling study was initiated to help develop an appropriate operating strategy for Central Bluff. For the North Fairview unit waterflood, a previously abandoned well was converted for water injection which began in late June 1993. The reservoir is being re-pressurized, and unit water production has remained nil since flood start indicating the possible formation of an oil bank. A reservoir simulation to characterize the Carter sand at North Fairview was undertaken and the modeling results were used to forecast field performance. The project was terminated due to unfavorable economics. The factors contributing to this decision were premature water breakthrough at Central Bluff, delayed flood response at North Fairview and stalled negotiations at the South Bluff site.

  5. OCCIDENTAL VERTICAL MODIFIED IN SITU PROCESS FOR THE RECOVERY OF OIL FROM OIL SHALE. PHASE II

    SciTech Connect (OSTI)

    Nelson, Reid M.

    1980-09-01

    The progress presented in this report covers the period June 1, 1980 through August 31, 1980 under the work scope for.Phase II of the DOE/Occidental Oil Shale, Inc. (OOSI) Cooperative Agreement. The major activities at OOSI 1s Logan Wash site during the quarter were: mining the voids at all levels for Retorts 7, 8 and 8x; completing Mini-Retort (MR) construction; continuing surface facility construction; tracer testing the MR 1 s; conducting Retorts 7 & 8 related Rock Fragmentation tests; setting up and debugging the Sandia B-61 trailer; and preparing the Phase II instrumentation plan.

  6. Investigation of oil recovery improvement by coupling an interfacial tension agent and a mobility control agent in light oil reservoirs. Technical progress report, October--December 1994

    SciTech Connect (OSTI)

    Pitts, M.J.

    1994-01-01

    The study will investigate two major areas concerning co-injecting an interfacial tension reduction agent(s) and a mobility control agent into petroleum reservoirs. The first will consist of defining the mechanisms of interaction of an alkaline agent, a surfactant, and a polymer on a fluid-fluid and a fluid-rock basis. The second is the improvement of the economics of the combined technology. This report examines effect of rock type on oil recovery by an alkaline-surfactant-polymer solutions. This report also begins a series of evaluations to improve the economics of alkaline-surfactant-polymer oil recovery.

  7. Rapid deployment of oil-drilling tools utilizing distribution network and inventory strategies

    E-Print Network [OSTI]

    Rahim, Ryan

    2010-01-01

    DTS is an oil and gas services company that delivers drilling tools to six major customer districts in the continental U.S. After the tools are used at a rig, they are transported to the closest repair and maintenance (MTC) ...

  8. 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)

    Abhijit Dandekar; Shirish Patil; Santanu Khataniar

    2008-12-31

    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.

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

    SciTech Connect (OSTI)

    Not Available

    1994-10-01

    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.

  10. Application of reservoir geology of enhanced oil recovery from upper Devonian Nisku Reefs, Alberta, Canada

    SciTech Connect (OSTI)

    Watts, N.R. (AEC Oil and Gas Company, Calgary, Alberta (Canada)); Coppold, M.P. (Imperial Oil Resources Limited (Esso), Calgary, Alberta (Canada)); Douglas, J.L. (Saudi Aramco, Dhahran (Saudi Arabia))

    1994-01-01

    The Upper Devonian West Pembina reef trend of west-central Alberta contains recoverable reserves of over 79 x 10[sup 6] m[sup 3] (500 million bbl) of oil and 1.4 x 10[sup 10] m[sup 3] (500 billion ft[sup 3]) of gas within approximately 50 pinnacle reefs in the Nisku Formation. Although the oil is saturated with gas at original reservoir pressure, primary depletion would soon lower the reservoir pressure below the bubble point, decreasing recovery. Thus, pressure maintenance is applied early in the producing life of the pools through waterflood or miscible flood schemes. Selection of the appropriate enhanced recovery scheme depends upon the internal flow-unit geometry of the reefs. The Bigoray Nisku C pool and the Pembina Nisku L pool form end members of the reservoir spectrum. They can be used as flow-unit models in the geological input for reservoir simulation studies. The Bigoray Nisku C pool is dominantly limestone. The primary textures, well perserved in this reef, provide the key to interpreting the relict textures in fully dolomitized reefs. Due to the presence of horizontal permeability barriers associated with the limestone lithology, the pool is developed with a waterflood displacement scheme. Ultimate recovery is estimated to be on the order of 0.55 x 10[sup 6] m[sup 3] (3.5 million bbl) or 46% or original oil in place (OOIP). The Pembina Nisku L pool is a completely dolomitized reef. In contrast to the Bigoray Nisku C pool, the complete dolomitization reduces the number of generic reservoir flow units observed in the L pool reef from six to three. Due to the excellent reservoir quality and absence of horizontal permeability barriers, it is being exploited by a vertical miscible flood. The Nisku L pool is one of the largest pinnacle reefs discovered in the Nisku reef fairway and contains an estimated 5 x 10[sup 6] m[sup 3] (31 million bbl) OOIP. Ultimate recovery is estimated to be approximately 4.1 x 10[sup 6] m[sup 3] (25.8 million bbl) or 82% of OOIP.

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

    SciTech Connect (OSTI)

    NONE

    1997-05-01

    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.

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

    SciTech Connect (OSTI)

    Martin, F.D.; Kendall, R.P.; Whitney, E.M.

    1997-08-01

    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.

  13. Solar thermal enhanced oil recovery (STEOR). Sections 2-8. Final report, October 1, 1979-June 30, 1980

    SciTech Connect (OSTI)

    Elzinga, E.; Arnold, C.; Allen, D.; Garman, R.; Joy, P.; Mitchell, P. Shaw, H.

    1980-11-01

    The program objectives were: (1) determine the technical, economic, operational, and environmental feasibility of solar thermal enhanced oil recovery using line focusing distributed collectors at Exxon's Edison Field, and (2) estimate the quantity of solar heat which might be applied to domestic enhanced oil recovery. This volume of the report summarizes all of the work done under the contract Statement of Work. Topics include the selection of the solar system, trade-off studies, preliminary design for steam raising, cost estimate for STEOR at Edison Field, the development plan, and a market and economics analysis. (WHK)

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

    SciTech Connect (OSTI)

    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)

    1993-02-01

    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.

  15. Using Biosurfactants Produced from Agriculture Process Waste Streams to Improve Oil Recovery in Fractured Carbonate Reservoirs

    SciTech Connect (OSTI)

    Stephen Johnson; Mehdi Salehi; Karl Eisert; Sandra Fox

    2009-01-07

    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.

  16. Evaluation of reservoir wettability and its effect on oil recovery. Annual report, February 1, 1996--January 31, 1997

    SciTech Connect (OSTI)

    Buckley, J.S.

    1998-03-01

    We report on the first year of the project, {open_quotes}Evaluation of Reservoir Wettability and its Effect on Oil Recovery.{close_quotes} 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 mineral surfaces, (2) to apply the results of surface studies to improve predictions of oil production from laboratory measurements, and (3) to use the results of this research to recommend ways to improve oil recovery by waterflooding. During the first year of this project we have focused on understanding the interactions between crude oils and mineral surfaces that establish wetting in porous media. Mixed-wetting can occur in oil reservoirs as a consequence of the initial fluid distribution. Water existing as thick films on flat surfaces and as wedges in comers can prevent contact of oil and mineral. Water-wet pathways are thus preserved. Depending on the balance of surface forces-which depend on oil, solid, and brine compositions-thick water films can be either stable or unstable. Water film stability has important implications for subsequent alteration of wetting in a reservoir. On surfaces exposed to oil, the components that are likely to adsorb and alter wetting can divided into two main groups: those containing polar heteroatoms, especially organic acids and bases; and the asphaltenes, large molecules that aggregate in solution and precipitate upon addition of n-pentane and similar agents. In order to understand how crude oils interact with mineral surfaces, we must first gather information about both these classes of compounds in a crude oil. Test procedures used to assess the extent of wetting alteration include adhesion and adsorption on smooth surfaces and spontaneous imbibition into porous media. Part 1 of this project is devoted to determining the mechanisms by which crude oils alter wetting.

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

    SciTech Connect (OSTI)

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

    1999-06-01

    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.

  18. Improved Oil Recovery in Mississippian Carbonate Reservoirs of Kansas -- Near-Term -- Class 2

    SciTech Connect (OSTI)

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

    1999-07-08

    This 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 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.

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

    SciTech Connect (OSTI)

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

    2004-10-01

    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.

  20. Experimental comparison of hot water/propane injection to steam/propane injection for recovery of heavy oil 

    E-Print Network [OSTI]

    Nesse, Thomas

    2005-02-17

    , attempts have been made to inject hot water instead of steam. The results have all been rather poor, the major problem being low sweep efficiency. The hot water just doesn?t enhance oil recovery enough. Adding propane to the steam injected in the reservoir...

  1. Improved oil recovery in fluvial dominated reservoirs of Kansas--near-term. Annual report

    SciTech Connect (OSTI)

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

    1996-11-01

    Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep efficiency and lack of reservoir management. The poor waterflood sweep efficiency is due to (1) reservoir heterogeneity, (2) channeling of injected water through high permeability zones or fractures, and (3) clogging of injection wells due to solids in the injection water. In many instances the lack of reservoir management results from (1) poor data collection and organization, (2) little or no integrated analysis of existing data by geological and engineering personnel, (3) the presence of multiple operators within the field, and (4) not identifying optimum recovery techniques. 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. This field was in the latter stage of primary production at the beginning of this project and is currently being waterflooded as a result of this 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 objective is to increase recovery efficiency and economics in these type of reservoirs. The technologies being applied to increase waterflood sweep efficiency are (1) in situ permeability modification treatments, (2) infill drilling, (3) pattern changes, and (4) air flotation to improve water quality. The technologies being applied to improve reservoir management are (1) database development, (2) reservoir simulation, (3) transient testing, (4) database management and (5) integrated geological and engineering analysis. Results of these two field projects are discussed.

  2. Improved Oil Recovery In Fluvial Dominated Deltaic Reservoirs of Kansas - Near Term

    SciTech Connect (OSTI)

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

    1999-01-14

    Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep efficiency and lack of reservoir management. The poor waterflood sweep efficiency is due to (1) reservoir heterogeneity, (2) channeling of injected water through high permeability zones or fractures, and (3) clogging of injection wells due to solids in the injection water. In many instances the lack of reservoir management results from (1) poor data collection and organization, (2) little or no integrated analysis of existing data by geological and engineering personnel, (3) the presence of multiple operators within the field, and (4) not identifying optimum recovery techniques. 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. This field was in the latter stage of primary production at the beginning of this project and is currently being waterflooded as a result of this 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 objective is to increase recovery efficiency and economics in these types of reservoirs. The technologies being applied to increase waterflood sweep efficiency are (1) in situ permeability modification treatments, (2) infill drilling, (3) pattern changes, and (4) air flotation to improve water quality. The technologies being applied to improve reservoir management are (1) database development, (2) reservoir simulation, (3) transient testing, (4) database management, and (5) integrated geological and engineering analysis.

  3. TIME-LAPSE SEISMIC MODELING & INVERSION OF CO2 SATURATION FOR SEQUESTRATION AND ENHANCED OIL RECOVERY

    SciTech Connect (OSTI)

    Mark A. Meadows

    2006-03-31

    Injection of carbon dioxide (CO2) into subsurface aquifers for geologic storage/sequestration, and into subsurface hydrocarbon reservoirs for enhanced oil recovery, has become an important topic to the nation because of growing concerns related to global warming and energy security. In this project we developed new ways to predict and quantify the effects of CO2 on seismic data recorded over porous reservoir/aquifer rock systems. This effort involved the research and development of new technology to: (1) Quantitatively model the rock physics effects of CO2 injection in porous saline and oil/brine reservoirs (both miscible and immiscible). (2) Quantitatively model the seismic response to CO2 injection (both miscible and immiscible) from well logs (1D). (3) Perform quantitative inversions of time-lapse 4D seismic data to estimate injected CO2 distributions within subsurface reservoirs and aquifers. This work has resulted in an improved ability to remotely monitor the injected CO2 for safe storage and enhanced hydrocarbon recovery, predict the effects of CO2 on time-lapse seismic data, and estimate injected CO2 saturation distributions in subsurface aquifers/reservoirs. We applied our inversion methodology to a 3D time-lapse seismic dataset from the Sleipner CO2 sequestration project, Norwegian North Sea. We measured changes in the seismic amplitude and traveltime at the top of the Sleipner sandstone reservoir and used these time-lapse seismic attributes in the inversion. Maps of CO2 thickness and its standard deviation were generated for the topmost layer. From this information, we estimated that 7.4% of the total CO2 injected over a five-year period had reached the top of the reservoir. This inversion approach could also be applied to the remaining levels within the anomalous zone to obtain an estimate of the total CO2 injected.

  4. 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)

    Linville, B.

    1983-07-01

    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)

  5. European Conference on the Mathematics of Oil Recovery --Freiberg, Germany, 3 -6 September 2002 We consider a model for immiscible three-phase (e.g., water, oil, and gas) flow in a porous

    E-Print Network [OSTI]

    New York at Stoney Brook, State University of

    2002 Abstract We consider a model for immiscible three-phase (e.g., water, oil, and gas) flow of three-phase (water-oil-gas) flow in a core sample of porous rock, taking into account hysteresis effects the effects of hysteresis on the Water-Alternating-Gas (WAG) oil-recovery process. In outline, the remainder

  6. Research on improved and enhanced oil recovery in Illinois through reservoir characterization, March 28, 1992--June 28, 1992

    SciTech Connect (OSTI)

    Oltz, D.F.

    1992-01-01

    This project will provide information that can maximize hydrocarbon production, minimize formation damage and stimulate new production in Illinois. Such information includes definition of hydrocarbon resources, characterization of hydrocarbon reservoirs, and the implementation of methods that will improve hydrocarbon extractive technology. Increased understanding of reservoir heterogeneities that affect oil recovery can aid in identifying producible resources. The transfer of technology to industry and the general public is a significant component of the program. The project is designed to examine selected subsurface oil reservoirs in Illinois. Scientists use advanced scientific techniques to gain a better understanding of reservoir components and behavior and address ways of potentially increasing the amount of recoverable oil. Initial production rates for wells in the Illinois Basin commonly decline quite rapidly and as much as 60 percent of the oil in place can be unrecoverable using standard operating procedures. Heterogeneities (geological differences in reservoir make-up) affect a reservoir's capability to release fluids. By-passed mobile and immobile oil remain in the reservoir. To learn how to get more of the oil out of reservoirs, the ISGS is studying the nature of reservoir rock heterogeneities and their control on the distribution and production of bypassed, mobile oil. Accomplishment for this period are summarized for the following tasks: mapping, cross-sections; subsurface depo-systems; outcrop studies; oil and gas development maps; engineering work; SEM/EDX; and clay minerals.

  7. Research on improved and enhanced oil recovery in Illinois through reservoir characterization, March 28, 1992--June 28, 1992

    SciTech Connect (OSTI)

    Oltz, D.F.

    1992-09-01

    This project will provide information that can maximize hydrocarbon production, minimize formation damage and stimulate new production in Illinois. Such information includes definition of hydrocarbon resources, characterization of hydrocarbon reservoirs, and the implementation of methods that will improve hydrocarbon extractive technology. Increased understanding of reservoir heterogeneities that affect oil recovery can aid in identifying producible resources. The transfer of technology to industry and the general public is a significant component of the program. The project is designed to examine selected subsurface oil reservoirs in Illinois. Scientists use advanced scientific techniques to gain a better understanding of reservoir components and behavior and address ways of potentially increasing the amount of recoverable oil. Initial production rates for wells in the Illinois Basin commonly decline quite rapidly and as much as 60 percent of the oil in place can be unrecoverable using standard operating procedures. Heterogeneities (geological differences in reservoir make-up) affect a reservoir`s capability to release fluids. By-passed mobile and immobile oil remain in the reservoir. To learn how to get more of the oil out of reservoirs, the ISGS is studying the nature of reservoir rock heterogeneities and their control on the distribution and production of bypassed, mobile oil. Accomplishment for this period are summarized for the following tasks: mapping, cross-sections; subsurface depo-systems; outcrop studies; oil and gas development maps; engineering work; SEM/EDX; and clay minerals.

  8. Oil recovery enhancement from fractured, low permeability reservoirs. Part 2, Annual report, October 1, 1990--September 31, 1991

    SciTech Connect (OSTI)

    Poston, S.W.

    1991-12-31

    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. These 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. (VSP) Vertical-Seismic Profile data was used to use shear-wave splitting concepts to estimate fracture orientations. Several programs were to be 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) Enhanced Oil Recovery Imbibition Process -- Laboratory displacement as well as MRI and CT imaging studies have shown the carbonated water-imbibition displacement process significantly accelerates and increases recovery of an oil saturated, low permeability core material, when compared to that of a normal brine imbibition displacement process. A study of oil recovery by the application of a cyclic carbonated water imbibition process, followed by reducing the pressure below the bubble point of the CO{sub 2}-water solution, indicated the possibility of alternate and new enhanced recovery method. The installation of an artificial solution gas drive significantly increased oil recovery. The extent and arrangement of micro-fractures in Austin Chalk horizontal cores was mapped with CT scanning techniques. The degree of interconnection of the micro-fractures was easily visualized.

  9. Carbon Dioxide-Water Emulsions for Enhanced Oil Recovery and Permanent Sequestration of Carbon Dioxide

    SciTech Connect (OSTI)

    Ryan, David; Golomb, Dan; Shi, Guang; Shih, Cherry; Lewczuk, Rob; Miksch, Joshua; Manmode, Rahul; Mulagapati, Srihariraju; Malepati, Chetankurmar

    2011-09-30

    This project involves the use of an innovative new invention ? Particle Stabilized Emulsions (PSEs) of Carbon Dioxide-in-Water and Water-in-Carbon Dioxide for Enhanced Oil Recovery (EOR) and Permanent Sequestration of Carbon Dioxide. The EOR emulsion would be injected into a semi-depleted oil reservoir such as Dover 33 in Otsego County, Michigan. It is expected that the emulsion would dislocate the stranded heavy crude oil from the rock granule surfaces, reduce its viscosity, and increase its mobility. The advancing emulsion front should provide viscosity control which drives the reduced-viscosity oil toward the production wells. The make-up of the emulsion would be subsequently changed so it interacts with the surrounding rock minerals in order to enhance mineralization, thereby providing permanent sequestration of the injected CO{sub 2}. In Phase 1 of the project, the following tasks were accomplished: 1. Perform laboratory scale (mL/min) refinements on existing procedures for producing liquid carbon dioxide-in-water (C/W) and water-in-liquid carbon dioxide (W/C) emulsion stabilized by hydrophilic and hydrophobic fine particles, respectively, using a Kenics-type static mixer. 2. Design and cost evaluate scaled up (gal/min) C/W and W/C emulsification systems to be deployed in Phase 2 at the Otsego County semi-depleted oil field. 3. Design the modifications necessary to the present CO{sub 2} flooding system at Otsego County for emulsion injection. 4. Design monitoring and verification systems to be deployed in Phase 2 for measuring potential leakage of CO{sub 2} after emulsion injection. 5. Design production protocol to assess enhanced oil recovery with emulsion injection compared to present recovery with neat CO{sub 2} flooding. 6. Obtain Federal and State permits for emulsion injection. Initial research focused on creating particle stabilized emulsions with the smallest possible globule size so that the emulsion can penetrate even low-permeability crude oilcontaining formations or saline aquifers. The term ?globule? refers to the water or liquid carbon dioxide droplets sheathed with ultrafine particles dispersed in the continuous external medium, liquid CO{sub 2} or H{sub 2}O, respectively. The key to obtaining very small globules is the shear force acting on the two intermixing fluids, and the use of ultrafine stabilizing particles or nanoparticles. We found that using Kenics-type static mixers with a shear rate in the range of 2700 to 9800 s{sup -1} and nanoparticles between 100-300 nm produced globule sizes in the 10 to 20 ?m range. Particle stabilized emulsions with that kind of globule size should easily penetrate oil-bearing formations or saline aquifers where the pore and throat size can be on the order of 50 ?m or larger. Subsequent research focused on creating particle stabilized emulsions that are deemed particularly suitable for Permanent Sequestration of Carbon Dioxide. Based on a survey of the literature an emulsion consisting of 70% by volume of water, 30% by volume of liquid or supercritical carbon dioxide, and 2% by weight of finely pulverized limestone (CaCO{sub 3}) was selected as the most promising agent for permanent sequestration of CO{sub 2}. In order to assure penetration of the emulsion into tight formations of sandstone or other silicate rocks and carbonate or dolomite rock, it is necessary to use an emulsion consisting of the smallest possible globule size. In previous reports we described a high shear static mixer that can create such small globules. In addition to the high shear mixer, it is also necessary that the emulsion stabilizing particles be in the submicron size, preferably in the range of 0.1 to 0.2 ?m (100 to 200 nm) size. We found a commercial source of such pulverized limestone particles, in addition we purchased under this DOE Project a particle grinding apparatus that can provide particles in the desired size range. Additional work focused on attempts to generate particle stabilized emulsions with a flow through, static mixer based apparatus under a variety

  10. Microbial and Geochemical Characterization of Wellington Oil Field, Southcentral Kansas, and Potential Applications to Microbial Enhanced Oil Recovery

    E-Print Network [OSTI]

    Huff, Breanna

    2014-08-31

    , that belong to the families of Pseudomonas, Bacillus and Rhodococcus. Sand packed columns were used to conduct core flooding experiments. The cores were initially flooded with oil field brine to calculate pore volume. The cores were then flooded with crude... oil from the reservoir to determine initial oil saturation. The sand pack was again flooded with brine until no oil flowed from the effluent. Biosurfactant was then 9 introduced into the column and allowed to rest for one day. Lastly, a...

  11. Mineral-Surfactant Interactions for Minimum Reagents Precipitation and Adsorption for Improved Oil Recovery

    SciTech Connect (OSTI)

    P. Somasundaran

    2008-09-20

    Chemical EOR can be an effective method for increasing oil recovery and reducing the amount of produced water; however, reservoir fluids are chemically complex and may react adversely to the polymers and surfactants injected into the reservoir. While a major goal is to alter rock wettability and interfacial tension between oil and water, rock-fluid and fluid-fluid interactions must be understood and controlled to minimize reagent loss, maximize recovery and mitigate costly failures. The overall objective of this project was to elucidate the mechanisms of interactions between polymers/surfactants and the mineral surfaces responsible for determining the chemical loss due to adsorption and precipitation in EOR processes. The role of dissolved inorganic species that are dependent on the mineralogy is investigated with respect to their effects on adsorption. Adsorption, wettability and interfacial tension are studied with the aim to control chemical losses, the ultimate goal being to devise schemes to develop guidelines for surfactant and polymer selection in EOR. The adsorption behavior of mixed polymer/surfactant and surfactant/surfactant systems on typical reservoir minerals (quartz, alumina, calcite, dolomite, kaolinite, gypsum, pyrite, etc.) was correlated to their molecular structures, intermolecular interactions and the solution conditions such as pH and/or salinity. Predictive models as well as general guidelines for the use of polymer/surfactant surfactant/surfactant system in EOR have been developed The following tasks have been completed under the scope of the project: (1) Mineral characterization, in terms of SEM, BET, size, surface charge, and point zero charge. (2) Study of the interactions among typical reservoir minerals (quartz, alumina, calcite, dolomite, kaolinite, gypsum, pyrite, etc.) and surfactants and/or polymers in terms of adsorption properties that include both macroscopic (adsorption density, wettability) and microscopic (orientation/conformation of the adsorbed layers), as well as precipitation/abstraction characteristics. (3) Investigation of the role of dissolved species, especially multivalent ions, on interactions between reservoir minerals and surfactants and/or polymers leading to surfactant precipitation or activated adsorption. (4) Solution behavior tests--surface tension, interaction, ultra filtration, and other tests. (5) Surfactant-mineral interactions relative to adsorption, wettability, and electrophoresis. (6) Work on the effects of multivalent ions, pH, temperature, salinity, and mixing ratio on the adsorption. Developments of adsorption models to explain interactions between surfactants/polymers/minerals. (7) General guidelines for the use of certain surfactants, polymers and their mixtures in micelle flooding processes.

  12. CO2-driven Enhanced Oil Recovery as a Stepping Stone to What?

    SciTech Connect (OSTI)

    Dooley, James J.; Dahowski, Robert T.; Davidson, Casie L.

    2010-07-14

    This paper draws heavily on the authors’ previously published research to explore the extent to which near term carbon dioxide-driven enhanced oil recovery (CO2-EOR) can be “a stepping stone to a long term sequestration program of a scale to be material in climate change risk mitigation.” The paper examines the historical evolution of CO2-EOR in the United States and concludes that estimates of the cost of CO2-EOR production or the extent of CO2 pipeline networks based upon this energy security-driven promotion of CO2-EOR do not provide a robust platform for spurring the commercial deployment of carbon dioxide capture and storage technologies (CCS) as a means of reducing greenhouse gas emissions. The paper notes that the evolving regulatory framework for CCS makes a clear distinction between CO2-EOR and CCS and the authors examine arguments in the technical literature about the ability for CO2-EOR to generate offsetting revenue to accelerate the commercial deployment of CCS systems in the electric power and industrial sectors of the economy. The authors conclude that the past 35 years of CO2-EOR in the U.S. have been important for boosting domestic oil production and delivering proven system components for future CCS systems. However, though there is no reason to suggest that CO2-EOR will cease to deliver these benefits, there is also little to suggest that CO2-EOR is a necessary or significantly beneficial step towards the commercial deployment of CCS as a means of addressing climate change.

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

    SciTech Connect (OSTI)

    Chidsey Jr., Thomas C.

    2003-02-06

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

  14. Copyright 2000, Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2000 SPE/DOE Improved Oil Recovery

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    at the 2000 SPE/DOE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, 3­5 April 2000. This paper, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers

  15. Copyright 2000, Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2000 SPE/DOE Improved Oil Recovery Symposium

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    at the 2000 SPE/DOE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, 3­5 April 2000. This paper, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers

  16. Experimental and Simulation Studies to Evaluate the Improvement of Oil Recovery by Different Modes of CO2 Injection in Carbonate Reservoirs 

    E-Print Network [OSTI]

    Aleidan, Ahmed Abdulaziz S.

    2011-02-22

    Experimental and numerical simulation studies were conducted to investigate the improvement of light oil recovery in carbonate cores during CO2 injection. The main steps in the study are as follows. First, the minimum miscibility pressure of 31º...

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

    SciTech Connect (OSTI)

    Izequeido, Alexandor

    2001-04-01

    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.

  18. QUANTITATIVE METHODS FOR RESERVOIR CHARACTERIZATION AND IMPROVED RECOVERY: APPLICATION TO HEAVY OIL SANDS

    SciTech Connect (OSTI)

    James W. Castle; Fred J. Molz; Ronald W. Falta; Cynthia L. Dinwiddie; Scott E. Brame; Robert A. Bridges

    2002-10-30

    Improved prediction of interwell reservoir heterogeneity has the potential 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 involves application of advanced analytical property-distribution methods conditioned to continuous outcrop control for improved reservoir characterization and simulation, particularly in heavy oil sands. 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. Observations of lateral variability and vertical sequences observed in Temblor Formation outcrops has led to a better understanding of reservoir geology in West Coalinga Field. Based on the characteristics of stratigraphic bounding surfaces in the outcrops, these surfaces were identified in the subsurface using cores and logs. The bounding surfaces were mapped and then used as reference horizons in the reservoir modeling. Facies groups and facies tracts were recognized from outcrops and cores of the Temblor Formation and were applied to defining the stratigraphic framework and facies architecture for building 3D geological models. The following facies tracts were recognized: incised valley, estuarine, tide- to wave-dominated shoreline, diatomite, and subtidal. A new minipermeameter probe, which has important advantages over previous methods of measuring outcrop permeability, was developed during this project. The device, which measures permeability at the distal end of a small drillhole, avoids surface weathering effects and provides a superior seal compared with previous methods for measuring outcrop permeability. The new probe was used successfully for obtaining a high-quality permeability data set from an outcrop in southern Utah. Results obtained from analyzing the fractal structure of permeability data collected from the southern Utah outcrop and from core permeability data provided by Chevron from West Coalinga Field were used in distributing permeability values in 3D reservoir models. Spectral analyses and the Double Trace Moment method (Lavallee et al., 1991) were used to analyze the scaling and multifractality of permeability data from cores from West Coalinga Field. T2VOC, which is a numerical flow simulator capable of modeling multiphase, multi-component, nonisothermal flow, was used to model steam injection and oil production for a portion of section 36D in West Coalinga Field. The layer structure and permeability distributions of different models, including facies group, facies tract, and fractal permeability models, were incorporated into the numerical flow simulator. The injection and production histories of wells in the study area were modeled, including shutdowns and the occasional conversion of production wells to steam injection wells. The framework provided by facies groups provides a more realistic representation of the reservoir conditions than facies tracts, which is revealed by a comparison of the history-matching for the oil production. Permeability distributions obtained using the fractal results predict the high degree of heterogeneity within the reservoir sands of West Coalinga Field. The modeling results indicate that predictions of oil production are strongly influenced by the geologic framework and by the boundary conditions. The permeability data collected from the southern Utah outcrop, support a new concept for representing natural heterogeneity, which is called the fractal/facies concept. This hypothesis is one of the few potentially simplifying concepts to emerge from recent studies of geological heterogeneity. Further investigation of this concept should be done to more fully apply fractal analysis to reservoir modeling and simulation. Additional outcrop permeability data sets and further analysis of the data from distinct facies will be needed in order to fully develop

  19. Carbon Capture and Sequestration (via Enhanced Oil Recovery) from a Hydrogen Production Facility in an Oil Refinery

    SciTech Connect (OSTI)

    Stewart Mehlman

    2010-06-16

    The project proposed a commercial demonstration of advanced technologies that would capture and sequester CO2 emissions from an existing hydrogen production facility in an oil refinery into underground formations in combination with Enhanced Oil Recovery (EOR). The project is led by Praxair, Inc., with other project participants: BP Products North America Inc., Denbury Onshore, LLC (Denbury), and Gulf Coast Carbon Center (GCCC) at the Bureau of Economic Geology of The University of Texas at Austin. The project is located at the BP Refinery at Texas City, Texas. Praxair owns and operates a large hydrogen production facility within the refinery. As part of the project, Praxair would construct a CO2 capture and compression facility. The project aimed at demonstrating a novel vacuum pressure swing adsorption (VPSA) based technology to remove CO2 from the Steam Methane Reformers (SMR) process gas. The captured CO2 would be purified using refrigerated partial condensation separation (i.e., cold box). Denbury would purchase the CO2 from the project and inject the CO2 as part of its independent commercial EOR projects. The Gulf Coast Carbon Center at the Bureau of Economic Geology, a unit of University of Texas at Austin, would manage the research monitoring, verification and accounting (MVA) project for the sequestered CO2, in conjunction with Denbury. The sequestration and associated MVA activities would be carried out in the Hastings field at Brazoria County, TX. The project would exceed DOE’s target of capturing one million tons of CO2 per year (MTPY) by 2015. Phase 1 of the project (Project Definition) is being completed. The key objective of Phase 1 is to define the project in sufficient detail to enable an economic decision with regard to proceeding with Phase 2. This topical report summarizes the administrative, programmatic and technical accomplishments completed in Phase 1 of the project. It describes the work relative to project technical and design activities (associated with CO2 capture technologies and geologic sequestration MVA), and Environmental Information Volume. Specific accomplishments of this Phase include: 1. Finalization of the Project Management Plan 2. Development of engineering designs in sufficient detail for defining project performance and costs 3. Preparation of Environmental Information Volume 4. Completion of Hazard Identification Studies 5. Completion of control cost estimates and preparation of business plan During the Phase 1 detailed cost estimate, project costs increased substantially from the previous estimate. Furthermore, the detailed risk assessment identified integration risks associated with potentially impacting the steam methane reformer operation. While the Phase 1 work identified ways to mitigate these integration risks satisfactorily from an operational perspective, the associated costs and potential schedule impacts contributed to the decision not to proceed to Phase 2. We have concluded that the project costs and integration risks at Texas City are not commensurate with the potential benefits of the project at this time.

  20. CO2 Storage and Enhanced Oil Recovery: Bald Unit Test Site, Mumford Hills Oil Field, Posey County, Indiana

    SciTech Connect (OSTI)

    Frailey, Scott M.; Krapac, Ivan G.; Damico, James R.; Okwen, Roland T.; McKaskle, Ray W.

    2012-03-30

    The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO2) injection test in a sandstone within the Clore Formation (Mississippian System, Chesterian Series) in order to gauge the large-scale CO2 storage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via miscible liquid CO2 flooding. As part of the MGSC�������¢����������������s Validation Phase (Phase II) studies, the small injection pilot test was conducted at the Bald Unit site within the Mumford Hills Field in Posey County, southwestern Indiana, which was chosen for the project on the basis of site infrastructure and reservoir conditions. Geologic data on the target formation were extensive. Core analyses, porosity and permeability data, and geophysical logs from 40 wells were used to construct cross sections and structure contour and isopach maps in order to characterize and define the reservoir architecture of the target formation. A geocellular model of the reservoir was constructed to improve understanding of CO2 behavior in the subsurface. At the time of site selection, the Field was under secondary recovery through edge-water injection, but the wells selected for the pilot in the Bald Unit had been temporarily shut-in for several years. The most recently shut-in production well, which was surrounded by four nearby shut-in production wells in a five-spot pattern, was converted to CO2 injection for this pilot. Two additional wells outside the immediate five-spot pattern, one of which was an active producer, were instrumented to measure surface temperature and pressure. The CO2 injection period lasted from September 3, 2009, through December 14, 2010, with one three-month interruption caused by cessation of CO2 deliveries due to winter weather. Water was injected into the CO2 injection well during this period. A total of 6,300 tonnes (6,950 tons) of CO2 were injected into the reservoir at rates that generally ranged from 18 to 32 tonnes (20 to 35 tons) per day. The CO2 injection bottomhole pressure generally remained at 8.3 to 9.0 MPag (1,200 to 1,300 psig). The CO2 injection was followed by continued monitoring for nine months during post-CO2 water injection. A monitoring, verification, and accounting (MVA) program was designed to determine the fate of injected CO2. Extensive periodic sampling and analysis of brine, groundwater, and produced gases began before CO2 injection and continued through the monitored waterflood periods. Samples were gathered from production wells and three newly installed groundwater monitoring wells. Samples underwent geochemical and isotopic analyses to reveal any CO2-related changes. Groundwater and kinetic modeling and mineralogical analysis were also employed to better understand the long-term dynamics of CO2 in the reservoir. No CO2 leakage into groundwater was detected, and analysis of brine and gas chemistry made it possible to track the path of plume migration and infer geochemical reactions and trapping of CO2. Cased-hole logging did not detect any CO2 in the near-wellbore region. An increase in CO2 concentration was first detected in February 2010 from the gas present in the carboy during brine sampling; however, there was no appreciable gas volume associated with the detection of CO2. The first indication of elevated gas rates from the commingled gas of the pilot�������¢����������������s production wells occurred in July 2010 and reached a maximum of 0.36 tonnes/day (0.41 tons/day) in September 2010. An estimated 27 tonnes (30 tons) of CO2 were produced at the surface from the gas separator at the tank battery from September 3, 2009, through September 11, 2011, representing 0.5% of the injected CO2. Consequently, 99.5%

  1. Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 82, quarterly report, January--March 1995

    SciTech Connect (OSTI)

    1996-06-01

    This document consists of a list of projects supporting work on oil recovery programs. A publications list and index of companies and institutions is provided. The remaining portion of the document provides brief descriptions on projects in chemical flooding, gas displacement, thermal recovery, geoscience, resource assessment, and reservoir class field demonstrations.

  2. Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins

    SciTech Connect (OSTI)

    Olsen, D.K.; Rawn-Schatzinger, V.; Ramzel, E.B.

    1992-07-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins' heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas' liquid fuels needs.

  3. Feasibility study of heavy oil recovery in the Appalachian, Black Warrior, Illinois, and Michigan basins

    SciTech Connect (OSTI)

    Olsen, D.K.; Rawn-Schatzinger, V.; Ramzel, E.B.

    1992-07-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Appalachian, Black Warrior, Illinois, and Michigan basins cover most of the depositional basins in the Midwest and Eastern United States. These basins produce sweet, paraffinic light oil and are considered minor heavy oil (10{degrees} to 20{degrees} API gravity or 100 to 100,000 cP viscosity) producers. Heavy oil occurs in both carbonate and sandstone reservoirs of Paleozoic Age along the perimeters of the basins in the same sediments where light oil occurs. The oil is heavy because escape of light ends, water washing of the oil, and biodegradation of the oil have occurred over million of years. The Appalachian, Black Warrior, Illinois, and Michigan basins` heavy oil fields have produced some 450,000 bbl of heavy oil of an estimated 14,000,000 bbl originally in place. The basins have been long-term, major light-oil-producing areas and are served by an extensive pipeline network connected to refineries designed to process light sweet and with few exceptions limited volumes of sour or heavy crude oils. Since the light oil is principally paraffinic, it commands a higher price than the asphaltic heavy crude oils of California. The heavy oil that is refined in the Midwest and Eastern US is imported and refined at select refineries. Imports of crude of all grades accounts for 37 to >95% of the oil refined in these areas. Because of the nature of the resource, the Appalachian, Black Warrior, Illinois and Michigan basins are not expected to become major heavy oil producing areas. The crude oil collection system will continue to degrade as light oil production declines. The demand for crude oil will increase pipeline and tanker transport of imported crude to select large refineries to meet the areas` liquid fuels needs.

  4. Copyright 2000, Society of Petroleum Engineers Inc. This paper was prepared for presentation at the 2000 SPE/DOE Improved Oil Recovery

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    at the 2000 SPE/DOE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, 3­5 April 2000. This paper, does not necessarily reflect any position of the Society of Petroleum Engineers, its officers could be modified? Does water injection help to recover sufficiently more oil or is it just for pressure

  5. European Conference on the Mathematics of Oil Recovery --Cannes, France, 30 August -2 September 2004 The determination of optimal well locations is a challenging problem in oil production since it

    E-Print Network [OSTI]

    Bangerth, Wolfgang

    1 9 th European Conference on the Mathematics of Oil Recovery -- Cannes, France, 30 August - 2 September 2004 Abstract The determination of optimal well locations is a challenging problem in oil production since it depends on geological and fluid properties as well as on economic parameters. This work

  6. Waterflood and Enhanced Oil Recovery Studies using Saline Water and Dilute Surfactants in Carbonate Reservoirs 

    E-Print Network [OSTI]

    Alotaibi, Mohammed

    2012-02-14

    . In addition to seawater and dilute seawater (50, 20, 10, and 1 vol%), formation brine, shallow aquifer water, deionized water and different crude oil samples were used throughout this study. The crude oil/water/carbonates interactions were also investigated...

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

    E-Print Network [OSTI]

    Tinss, Judicael Christopher

    2001-01-01

    in accelerating oil production and to compare the performance of steam-propane injection versus steam injection alone on an intermediate crude oil of 21 ?API gravity. Eight experimental runs were performed: three pure steam injection runs, three steam...

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

    E-Print Network [OSTI]

    Sunnatov, Dinmukhamed

    2010-07-14

    Steam injection with added surface active chemicals is one of general EOR processes aimed to recover residual oil after primary production processes. It has been demonstrated that, after waterflooding, an oil swept area ...

  9. Geochemical engineering design tools for uranium in situ recovery : the HYDROGEOCHEM codes.

    SciTech Connect (OSTI)

    Siegel, Malcolm Dean; Li, Ming-Hsu; Yeh, Gour-Tsyh

    2010-11-01

    Geochemical Engineering Design (GED) is based on applications of the principles and various computer models that describe the biogeochemistry and physics of removal of contaminants from water by adsorption, precipitation and filtration. It can be used to optimize or evaluate the efficiency of all phases of in situ recovery (ISR). The primary tools of GED are reactive transport models; this talk describes the potential application of the HYDROGEOCHEM family of codes to ISR. The codes can describe a complete suite of equilibrium or kinetic aqueous complexation, adsorption-desorption, precipitation-dissolution, redox, and acid-base reactions in variably saturated media with density-dependent fluid flow. Applications to ISR are illustrated with simulations of (1) the effectiveness of a reactive barrier to prevent off-site uranium migration and (2) evaluation of the effect of sorption hysteresis on natural attenuation. In the first example, it can be seen that the apparent effectiveness of the barrier depends on monitoring location and that it changes over time. This is due to changes in pH, saturation of sorption sites, as well as the geometry of the flow field. The second simulation shows how sorption hysteresis leads to observable attenuation of a uranium contamination plume. Different sorption mechanisms including fast (or reversible), slow, and irreversible sorption were simulated. The migration of the dissolved and total uranium plumes for the different cases are compared and the simulations show that when 50-100% of the sites have slow desorption rates, the center of mass of the dissolved uranium plume begins to move upstream. This would correspond to the case in which the plume boundaries begin to shrink as required for demonstration of natural attenuation.

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

    SciTech Connect (OSTI)

    Thomas C. Chidsey, Jr.

    2002-11-01

    The Paradox Basin of Utah, Colorado, and Arizona contains nearly 100 small oil fields producing from shallow-shelf carbonate buildups or mounds within the Desert Creek zone of the Pennsylvanian (Desmoinesian) Paradox Formation. These fields typically have one to four wells with primary production ranging from 700,000 to 2,000,000 barrels (111,300-318,000 m{sup 3}) of oil per field at a 15 to 20 percent recovery rate. Five fields in southeastern Utah were evaluated for waterflood or carbon-dioxide (CO{sub 2})-miscible flood projects based upon geological characterization and reservoir modeling. Geological characterization on a local scale focused on reservoir heterogeneity, quality, and lateral continuity as well as possible compartmentalization within each of the five project fields. The Desert Creek zone includes three generalized facies belts: (1) open-marine, (2) shallow-shelf and shelf-margin, and (3) intra-shelf, salinity-restricted facies. These deposits have modern analogs near the coasts of the Bahamas, Florida, and Australia, respectively, and outcrop analogs along the San Juan River of southeastern Utah. The analogs display reservoir heterogeneity, flow barriers and baffles, and lithofacies geometry observed in the fields; thus, these properties were incorporated in the reservoir simulation models. Productive carbonate buildups consist of three types: (1) phylloid algal, (2) coralline algal, and (3) bryozoan. Phylloid-algal buildups have a mound-core interval and a supra-mound interval. Hydrocarbons are stratigraphically trapped in porous and permeable lithotypes within the mound-core intervals of the lower part of the buildups and the more heterogeneous supramound intervals. To adequately represent the observed spatial heterogeneities in reservoir properties, the phylloid-algal bafflestones of the mound-core interval and the dolomites of the overlying supra-mound interval were subdivided into ten architecturally distinct lithotypes, each of which exhibits a characteristic set of reservoir properties obtained from outcrop analogs, cores, and geophysical logs. The Anasazi and Runway fields were selected for geostatistical modeling and reservoir compositional simulations. Models and simulations incorporated variations in carbonate lithotypes, porosity, and permeability to accurately predict reservoir responses. History matches tied previous production and reservoir pressure histories so that future reservoir performances could be confidently predicted. The simulation studies showed that despite most of the production being from the mound-core intervals, there were no corresponding decreases in the oil in place in these intervals. This behavior indicates gravity drainage of oil from the supra-mound intervals into the lower mound-core intervals from which the producing wells' major share of production arises. The key to increasing ultimate recovery from these fields (and similar fields in the basin) is to design either waterflood or CO{sub 2}-miscible flood projects capable of forcing oil from high-storage-capacity but low-recovery supra-mound units into the high-recovery mound-core units. Simulation of Anasazi field shows that a CO{sub 2} flood is technically superior to a waterflood and economically feasible. For Anasazi field, an optimized CO{sub 2} flood is predicted to recover a total 4.21 million barrels (0.67 million m3) of oil representing in excess of 89 percent of the original oil in place. For Runway field, the best CO{sub 2} flood is predicted to recover a total of 2.4 million barrels (0.38 million m3) of oil representing 71 percent of the original oil in place. If the CO{sub 2} flood performed as predicted, it is a financially robust process for increasing the reserves in the many small fields in the Paradox Basin. The results can be applied to other fields in the Rocky Mountain region, the Michigan and Illinois Basins, and the Midcontinent.

  11. Phase Behavior, Solid Organic Precipitation, and Mobility Characterization Studies in Support of Enhanced Heavy Oil Recovery on the Alaska North Slope

    SciTech Connect (OSTI)

    Shirish Patil; Abhijit Dandekar; Santanu Khataniar

    2008-12-31

    The medium-heavy oil (viscous oil) resources in the Alaska North Slope are estimated at 20 to 25 billion barrels. These oils are viscous, flow sluggishly in the formations, and are difficult to recover. Recovery of this viscous oil requires carefully designed enhanced oil recovery processes. Success of these recovery processes is critically dependent on accurate knowledge of the phase behavior and fluid properties, especially viscosity, of these oils under variety of pressure and temperature conditions. This project focused on predicting phase behavior and viscosity of viscous oils using equations of state and semi-empirical correlations. An experimental study was conducted to quantify the phase behavior and physical properties of viscous oils from the Alaska North Slope oil field. The oil samples were compositionally characterized by the simulated distillation technique. Constant composition expansion and differential liberation tests were conducted on viscous oil samples. Experiment results for phase behavior and reservoir fluid properties were used to tune the Peng-Robinson equation of state and predict the phase behavior accurately. A comprehensive literature search was carried out to compile available compositional viscosity models and their modifications, for application to heavy or viscous oils. With the help of meticulously amassed new medium-heavy oil viscosity data from experiments, a comparative study was conducted to evaluate the potential of various models. The widely used corresponding state viscosity model predictions deteriorate when applied to heavy oil systems. Hence, a semi-empirical approach (the Lindeloff model) was adopted for modeling the viscosity behavior. Based on the analysis, appropriate adjustments have been suggested: the major one is the division of the pressure-viscosity profile into three distinct regions. New modifications have improved the overall fit, including the saturated viscosities at low pressures. However, with the limited amount of geographically diverse data, it is not possible to develop a comprehensive predictive model. Based on the comprehensive phase behavior analysis of Alaska North Slope crude oil, a reservoir simulation study was carried out to evaluate the performance of a gas injection enhanced oil recovery technique for the West Sak reservoir. It was found that a definite increase in viscous oil production can be obtained by selecting the proper injectant gas and by optimizing reservoir operating parameters. A comparative analysis is provided, which helps in the decision-making process.

  12. 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)

    Schamel, S.

    2001-01-09

    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.

  13. 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)

    Schamel, Steven; Deo, Milind; Deets, Mike

    2002-02-21

    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.

  14. Support of enhanced oil recovery to independent producers in Texas. Quarterly report, July 1, 1996--September 30, 1996

    SciTech Connect (OSTI)

    Fotouh, K.H.

    1996-10-01

    To establish a Technology Transfer Resource Center (TRC) at Prairie View A&M University (PVAMU) to assist the Independent Oil Producers, in the state of Texas, (TIP) obtain and apply oil recovery technology to their operation. The University will conduct a field pilot project in cooperation with an Independent Producer to demonstrate how technology application improves the economic performance of a project. Experience gained from the project will be disseminated to other Independents. These activities will be coordinated with neighboring state Universities and private research entities active in technology transfer programs. The University`s goal is to stimulate Petroleum Engineering education and research at the university as a result of participating in these activities. The long term goal is to establish the first Petroleum Engineering Department at a Historically Black University.

  15. Economic Recovery of Oil Trapped at Fan Margins Using Hig Angle Wells Multiple Hydraulic Fractures

    SciTech Connect (OSTI)

    Laue, M.L.

    1997-11-21

    The Yowlumne field is a giant field in the southern San Joaquin basin, Kern County, California. It is a deep (13,000 ft) waterflood operation that produces from the Miocene- aged Stevens Sand. The reservoir is interpreted as a layered, fan-shaped, prograding turbidite complex containing several lobe-shaped sand bodies that represent distinct flow units. A high ultimate recovery factor is expected, yet significant quantities of undrained oil remain at the fan margins. The fan margins are not economic to develop using vertical wells because of thinning pay, deteriorating rock quality, and depth. This project attempts to demonstrate the effectiveness of exploiting the northeast distal fan margin through the use of a high- angle well completed with multiple hydraulic- fracture treatments. A high-angle well offers greater pay exposure than can be achieved with a vertical well. Hydraulic-fracture treatments will establish vertical communication between thin interbedded layers and the wellbore. The equivalent production rate and reserves of three vertical wells are anticipated at a cost of approximately two vertical wells. The near-horizontal well penetrated the Yowlumne sand; a Stevens sand equivalent, in the distal fan margin in the northeast area of the field. The well was drilled in a predominately westerly direction towards the interior of the field, in the direction of improving rock quality. Drilling and completion operations proved to be very challenging, leading to a number of adjustments to original plans. Hole conditions resulted in obtaining less core material than desired and setting intermediate casing 1200 ft too high. The 7 in. production liner stuck 1000 ft off bottom, requiring a 5 in. liner to be run the rest of the way. The cement job on the 5 in. liner resulted in a very poor bond, which precluded one of three hydraulic fracture treatments originally planned for the well. Openhole logs confirmed most expectations going into the project about basic rock properties: the formation was shaly with low porosities, and water saturations were in line with expectations, including the presence of some intervals swept out by the waterflood. High water saturations at the bottom of the well eliminated one of the originally planned hydraulic fracture treatments. Although porosities proved to be low, they were more uniform across the formation than expected. Permeabilities of the various intervals continue to be evaluated, but appear to be better than expected from the porosity log model derived in Budget Period One. The well was perforated in all pay sections behind the 5 in. liner. Production rates and phases agree nicely with log calculations, fractional flow calculations, and an analytical technique used to predict the rate performance of the well.

  16. WETTABILITY AND PREDICTION OF OIL RECOVERY FROM RESERVOIRS DEVELOPED WITH MODERN DRILLING AND COMPLETION FLUIDS

    SciTech Connect (OSTI)

    Jill S. Buckley; Norman R. Morrow

    2004-11-01

    Contamination of crude oils by surface-active agents from drilling fluids or other oil-field chemicals is more difficult to detect and quantify than bulk contamination with, for example, base fluids from oil-based muds. Bulk contamination can be detected by gas chromatography or other common analytical techniques, but surface-active contaminants can be influential at much lower concentrations that are more difficult to detect analytically, especially in the context of a mixture as complex as a crude oil. In this report we present a baseline study of interfacial tensions of 39 well-characterized crude oil samples with aqueous phases that vary in pH and ionic composition. This extensive study will provide the basis for assessing the effects of surface-active contaminant on interfacial tension and other surface properties of crude oil/brine/rock ensembles.

  17. Application of the Recovery Potential Screening Tool in the Matagorda Bay Watershed 

    E-Print Network [OSTI]

    Gregory, L.; Brown, M.; Skow, K.; Engling, A.; Wagner, K.; Berthold, A.

    2014-01-01

    intensive, thus prioritizing future water quality restoration efforts is a means to efficiently allocate available resources and achieve timely restoration results. The U.S. Environmental Protection Agency (EPA) developed the Recovery Potential Screening...

  18. Feasibility study of heavy oil recovery in the Permian Basin (Texas and New Mexico)

    SciTech Connect (OSTI)

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

    1993-05-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Permian Basin of West Texas and Southeastern New Mexico is made up of the Midland, Delaware, Val Verde, and Kerr Basins; the Northwestern, Eastern, and Southern shelves; the Central Basin Platform, and the Sheffield Channel. The present day Permian Basin was one sedimentary basin until uplift and subsidence occurred during Pennsylvanian and early Permian Age to create the configuration of the basins, shelves, and platform of today. The basin has been a major light oil producing area served by an extensive pipeline network connected to refineries designed to process light sweet and limited sour crude oil. Limited resources of heavy oil (10`` to 20`` API gravity) occurs in both carbonate and sandstone reservoirs of Permian and Cretaceous Age. The largest cumulative heavy oil production comes from fluvial sandstones of the Cretaceous Trinity Group. Permian heavy oil is principally paraffinic and thus commands a higher price than asphaltic California heavy oil. Heavy oil in deeper reservoirs has solution gas and low viscosity and thus can be produced by primary and by waterflooding. Because of the nature of the resource, the Permian Basin should not be considered a major heavy oil producing area.

  19. Feasibility study of heavy oil recovery in the Permian Basin (Texas and New Mexico)

    SciTech Connect (OSTI)

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

    1993-05-01

    This report is one of a series of publications assessing the feasibility of increasing domestic heavy oil production. Each report covers select areas of the United States. The Permian Basin of West Texas and Southeastern New Mexico is made up of the Midland, Delaware, Val Verde, and Kerr Basins; the Northwestern, Eastern, and Southern shelves; the Central Basin Platform, and the Sheffield Channel. The present day Permian Basin was one sedimentary basin until uplift and subsidence occurred during Pennsylvanian and early Permian Age to create the configuration of the basins, shelves, and platform of today. The basin has been a major light oil producing area served by an extensive pipeline network connected to refineries designed to process light sweet and limited sour crude oil. Limited resources of heavy oil (10'' to 20'' API gravity) occurs in both carbonate and sandstone reservoirs of Permian and Cretaceous Age. The largest cumulative heavy oil production comes from fluvial sandstones of the Cretaceous Trinity Group. Permian heavy oil is principally paraffinic and thus commands a higher price than asphaltic California heavy oil. Heavy oil in deeper reservoirs has solution gas and low viscosity and thus can be produced by primary and by waterflooding. Because of the nature of the resource, the Permian Basin should not be considered a major heavy oil producing area.

  20. Uncovering the Microbial Diversity of the Alberta Oil Sands through Metagenomics: A Stepping Stone for Enhanced Oil Recovery and

    E-Print Network [OSTI]

    Voordouw, Gerrit

    1 Uncovering the Microbial Diversity of the Alberta Oil Sands through Metagenomics: A Stepping Voordouw3 1 Department of Biological Sciences, University of Alberta; 2 Genome Science Center, B.C. Cancer Genome Alberta, Calgary, AB. Team and deliverables The multidisciplinary R&D team will include

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

    E-Print Network [OSTI]

    Huseynzade, Samir

    2009-05-15

    In-situ upgrading of oil using hydrogen donors is a new process. In particular, very little research has been conducted with respect to in-situ oil upgrading using hydrogen donor under in-situ combustion. Several papers describe the use of metal...

  2. WETTABILITY AND PREDICTION OF OIL RECOVERY FROM RESERVOIRS DEVELOPED WITH MODERN DRILLING AND COMPLETION FLUIDS

    SciTech Connect (OSTI)

    Jill S. Buckley; Norman R. Morrow

    2002-12-01

    We report on a preliminary study of wetting effects of synthetic oil-based mud components on the wetting of mica surfaces using drilling mud fractions obtained from two wells drilled with synthetic oil-based muds (SBM). We have used these SBM fractions, one a filtrate and the other a centrifugate, to develop testing protocols for studies on smooth mica surfaces. Both SBM fractions changed the wetting of clean, dry mica surfaces, making them preferentially oil-wet. Solvents were tested to clean the mica with varying degrees of success. In tests designed to simulate contact between SBM fractions and reservoir pore surface, changes of wetting of mica that had previously been exposed to brine and crude oil were examined using six different crude oils in combination with several different brine formulations. Four of the six oils produced preferentially water-wet surfaces whereas two produced fairly oil-wet conditions on mica. Exposure to the SBM fractions tended to increase decane/water advancing contact angles on the more water-wet surfaces and to decrease those on the more oil-wet surfaces. Cleaning solvents were compared for their efficacy and the possibility of wettability restoration was examined for some of the cleaned surfaces.

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

    SciTech Connect (OSTI)

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

    1995-03-01

    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.

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

    SciTech Connect (OSTI)

    Wood, J.R.

    1997-05-01

    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.

  5. WETTABILITY AND PREDICTION OF OIL RECOVERY FROM RESERVOIRS DEVELOPED WITH MODERN DRILLING AND COMPLETION FLUIDS

    SciTech Connect (OSTI)

    Jill S. Buckley; Norman R. Morrow

    2004-05-01

    We report on progress in three areas. In part one, the wetting effects of synthetic base oils are reported. Part two reports progress in understanding the effects of surfactants of known chemical structures, and part three integrates the results from surface and core tests that show the wetting effects of commercial surfactant products used in synthetic and traditional oil-based drilling fluids. An important difference between synthetic and traditional oil-based muds (SBM and OBM, respectively) is the elimination of aromatics from the base oil to meet environmental regulations. The base oils used include dearomatized mineral oils, linear alpha-olefins, internal olefins, and esters. We show in part one that all of these materials except the esters can, at sufficiently high concentrations, destabilize asphaltenes. The effects of asphaltenes on wetting are in part related to their stability. Although asphaltenes have some tendency to adsorb on solid surfaces from a good solvent, that tendency can be much increased near the onset of asphaltene instability. Tests in Berea sandstone cores demonstrate wetting alteration toward less water-wet conditions that occurs when a crude oil is displaced by paraffinic and olefinic SBM base oils, whereas exposure to the ester products has little effect on wetting properties of the cores. Microscopic observations with atomic forces microscopy (AFM) and macroscopic contact angle measurements have been used in part 2 to explore the effects on wetting of mica surfaces using oil-soluble polyethoxylated amine surfactants with varying hydrocarbon chain lengths and extent of ethoxylation. In the absence of water, only weak adsorption occurs. Much stronger, pH-dependent adsorption was observed when water was present. Varying hydrocarbon chain length had little or no effect on adsorption, whereas varying extent of ethoxylation had a much more significant impact, reducing contact angles at nearly all conditions tested. Preequilibration of aqueous and oleic phases appeared to have little influence over surfactant interactions with the mica surface; the solubility in water of all three structures appeared to be very limited. Commercial emulsifiers for both SBM and OBM formulations are blends of tall oil fatty acids and their polyaminated derivatives. In part three of this report, we integrate observations on smooth surfaces with those in Berea sandstone cores to show the effects of low concentrations of these products with and without the added complexity of adsorbed material from crude oils. Unlike the polyethoxylated amines studied in part two, there are significant non-equilibrium effects that can occur when water first contacts oil with dissolved surfactant. Very oil-wet conditions can be produced on first contact. Surfactant dissolved in oil had less effect on wetting alteration for one combination of crude oil and surfactant, although the generality of this observation can only be assessed by additional tests with crude oils of different composition. The wettability-altering effect of surfactants on both mica and Berea sandstone was most significant when they contacted surfaces after adsorption of crude oil components. Tests without crude oil might underestimate the extent of wetting change possible with these SBM and OBM emulsifiers.

  6. Zebra processes of oil recovery using fireflood and waterflood in alternate sands in a multi-sand environment

    SciTech Connect (OSTI)

    Chu, C.

    1995-12-31

    This paper presents a new process of oil recovery, namely, the zebra process, which is specifically advantageous to use in heavy oil reservoirs that exist in multiple sands. This process uses firefloods and waterfloods in alternate sands. The firefloods serve as formation preheaters which reduce the oil viscosities in the neighboring sands so that these sands, normally not amenable to waterfloods because of high viscosity, can be waterflooded with ease. The exciting news is that the air compression cost in firefloods can be reduced by a factor of three with a proper application of the zebra process. This great savings in air compression cost is possible because the heat that is normally lost to the overburden and underburden in firefloods is now being put to good use, by preheating the neighboring sands. Examples are given on zebraing several idealized sand-shale sequences involving three-, five-, six-, and seven-sand reservoirs, and also zebraing two actual sand-shale sequences, both involving five-sand reservoirs.

  7. Oil recovery by carbon dioxide injection into consolidated and unconsolidated sandstone 

    E-Print Network [OSTI]

    Lin, Fwu-Jin Frank

    1975-01-01

    a displacement effic1ency approaching 100 percent. (3) Carbon Dioxide neither achieves direct miscible displacement at practical reservoir pressures, like LPG, nor depend upon the presence of light hydrocarbons in the reservoir oil. A f1eld... strong function of pore size dis- tribution, probably contributed a great effect on the oil displacement effic1enc1es between the consolidated sandstone core and the unconsolidated sand pack. 4. No significant over-riding effect of carbon dioxide...

  8. Recovery Act: Develop a Modular Curriculum for Training University Students in Industry Standard CO{sub 2} Sequestration and Enhanced Oil Recovery Methodologies

    SciTech Connect (OSTI)

    Trentham, R. C.; Stoudt, E. L.

    2013-05-31

    CO{sub 2} Enhanced Oil Recovery, Sequestration, & Monitoring Measuring & Verification are topics that are not typically covered in Geoscience, Land Management, and Petroleum Engineering curriculum. Students are not typically exposed to the level of training that would prepare them for CO{sub 2} reservoir and aquifer sequestration related projects when they begin assignments in industry. As a result, industry training, schools & conferences are essential training venues for new & experienced personnel working on CO{sub 2} projects for the first time. This project collected and/or generated industry level CO{sub 2} training to create modules which faculties can utilize as presentations, projects, field trips and site visits for undergrad and grad students and prepare them to "hit the ground running" & be contributing participants in CO{sub 2} projects with minimal additional training. In order to create the modules, UTPB/CEED utilized a variety of sources. Data & presentations from industry CO{sub 2} Flooding Schools & Conferences, Carbon Management Workshops, UTPB Classes, and other venues was tailored to provide introductory reservoir & aquifer training, state-of-the-art methodologies, field seminars and road logs, site visits, and case studies for students. After discussions with faculty at UTPB, Sul Ross, Midland College, other universities, and petroleum industry professionals, it was decided to base the module sets on a series of road logs from Midland to, and through, a number of Permian Basin CO{sub 2} Enhanced Oil Recovery (EOR) projects, CO{sub 2} Carbon Capture and Storage (CCUS) projects and outcrop equivalents of the formations where CO{sub 2} is being utilized or will be utilized, in EOR projects in the Permian Basin. Although road logs to and through these projects exist, none of them included CO{sub 2} specific information. Over 1400 miles of road logs were created, or revised specifically to highlight CO{sub 2} EOR projects. After testing a number of different entry points into the data set with students and faculty form a number of different universities, it was clear that a standard website presentation with a list of available power point presentations, excel spreadsheets, word documents and pdf's would not entice faculty, staff, and students at universities to delve deeper into the website http://www.utpb.edu/ceed/student modules.

  9. Applications of advanced petroleum production technology and water alternating gas injection for enhanced oil recovery -- Mattoon Oil Field, Illinois. First quarterly technical progress report, 1993

    SciTech Connect (OSTI)

    Baroni, M.R.

    1993-05-24

    For work during the first quarter of 1993, American Oil Recovery, Inc. targeted completion of the following specific objectives: Convene meetings of Mattoon Project subcontractors in order to plan and coordinate Project activities. Confirm organizational arrangements and plans for implementation of Mattoon Project. Complete most work on detailed analysis of reservoir geology of productive leases in the Mattoon Project. Identify first Facies Defined Subunit for initial injectivity testing to be commenced near the beginning of the second quarter. Identify additional Facies Defined Subunits for injectivity testing and characterization during the second and third quarters. Award subcontract to the Illinois State Geological Survey and commence work on preparation of a geostatistical model (STRATAMODEL) of more than 100 wells on 1,000 acres within the Mattoon Project Area. Obtain oil samples from wells in the identified Facies Subunit for reservoir rock, fluid, and CO{sub 2} compatibility testing by the Illinois State Geological Survey. Design CO{sub 2} injection pumps and injection monitoring equipment configuration. Obtain bids for required pumps and diesel motor. Accomplishments for this quarter are reported.

  10. Improved oil recovery in Mississippian carbonate reservoirs of Kansas near term Class 2. Annual report, September 18, 1994--March 15, 1997

    SciTech Connect (OSTI)

    Carr, T.R.; Green, D.W.; Willhite, G.P.

    1998-04-01

    This annual report describes progress during the second year of the project entitled {open_quotes}Improved Oil Recovery in Mississippian Carbonate Reservoirs in Kansas{close_quotes}. 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. As part of the project, several tools and techniques for reservoir description and management were developed, modified and demonstrated. These include: (1) a new approach to subsurface visualization using electric logs ({open_quotes}Pseudoseismic{open_quotes}); (2) a low-cost easy-to-use spreadsheet log analysis software (PfEFFER); and (3) an extension of the BOAST-3 computer program for full field reservoir simulation. The world-wide-web was used to provide rapid and flexible dissemination of the project results through the Internet. Included in this report is a summary of significant project results at the demonstration site (Schaben Field, Ness County, Kansas). These results include an outline of the reservoir description based on available and newly acquired data and reservoir simulation results. Detailed information is available on-line through the Internet. Based on the reservoir simulation, three infill wells will be drilled to validate the reservoir description and demonstrate the effectiveness of the proposed reservoir management strategies. The demonstration phase of the project has just begun and will be presented in the next annual report.

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

    SciTech Connect (OSTI)

    1998-04-01

    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.

  12. 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)

    Ernest A. Mancini

    2003-12-31

    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 proposed a three-phase, focused, comprehensive, integrated and multidisciplinary study of Upper Jurassic Smackover carbonates (Class II Reservoir), involving reservoir characterization and 3-D modeling (Phase I) and a field demonstration project (Phases II and III) at Womack Hill Field Unit, Choctaw and Clarke Counties, Alabama, eastern Gulf Coastal Plain. Phase I of the project has been completed. 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 major tasks of the project included reservoir characterization, recovery technology analysis, recovery technology evaluation, and the decision to implement a demonstration project. Reservoir characterization consisted of geoscientific reservoir characterization, petrophysical and engineering property characterization, microbial characterization, and integration of the characterization data. Recovery technology analysis included 3-D geologic modeling, reservoir simulation, and microbial core experiments. Recovery technology evaluation consisted of acquiring and evaluating new high quality 2-D seismic data, evaluating the existing pressure maintenance project in the Womack Hill Field Unit, and evaluating the concept of an immobilized enzyme technology project for the Womack Hill Field Unit. The decision to implement a demonstration project essentially resulted in the decision on whether to conduct an infill drilling project in Womack Hill Field. Reservoir performance, multiwell productivity analysis, and reservoir simulation studies indicate that water injection continues to provide stable support to maintain production from wells in the western unitized area of the field and that the strong water drive present in the eastern area of the field is adequate to sustain production from this part of the field. Although the results from the microbial characterization and microbial core experiments are very promising, it is recommended that an immobilized enzyme technology project not be implemented in the Womack Hill Field Unit until live (freshly taken and properly preserved) cores from the Smackover reservoir in the field are acquired to confirm the microbial core experiments to date. From 3-D geologic modeling, reservoir performance analysis, and reservoir simulation, four areas in the Womack Hill Field were identified as prospective infill drilling sites to recover undrained oil from the field. It was determined that the two areas in the unit area probably can be effectively drained by perforating higher zones in the Smackover reservoir in currently producing wells. The two areas in the eastern (non-unitized) part of the field require the drilling of new wells. The successful drilling and testing of a well in 2003 by J. R. Pounds, Inc. has proven the oil potential of the easternmost site in the non-unitized part of the field. Pruet Production Co. acquired new 2-D seismic data to evaluate the oil potential of the westernmost site. Because of the effects of a fault shadow from the major fault bounding the southern border of the Womack Hill Field, it is difficult to evaluate conclusively this potential drill site. Pruet Production Co. has decided not to drill this new well at this time and to further evaluate the new 2-D seismic profiles after these data have been processed using a pre-stack migration technique. Pruet Production Co. has elected not to continue into Phase II of this project because they are not prepared to make a proposal to the other mineral interest owners regarding the drilling of new wells as part of an infil

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

    SciTech Connect (OSTI)

    Ernest A. Mancini

    2006-05-31

    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 proposed a three-phase, focused, comprehensive, integrated and multidisciplinary study of Upper Jurassic Smackover carbonates (Class II Reservoir), involving reservoir characterization and 3-D modeling (Phase I) and a field demonstration project (Phases II and III) at Womack Hill Field Unit, Choctaw and Clarke Counties, Alabama, eastern Gulf Coastal Plain. Phase I of the project has been completed. 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 major tasks of the project included reservoir characterization, recovery technology analysis, recovery technology evaluation, and the decision to implement a demonstration project. Reservoir characterization consisted of geoscientific reservoir characterization, petrophysical and engineering property characterization, microbial characterization, and integration of the characterization data. Recovery technology analysis included 3-D geologic modeling, reservoir simulation, and microbial core experiments. Recovery technology evaluation consisted of acquiring and evaluating new high quality 2-D seismic data, evaluating the existing pressure maintenance project in the Womack Hill Field Unit, and evaluating the concept of an immobilized enzyme technology project for the Womack Hill Field Unit. The decision to implement a demonstration project essentially resulted in the decision on whether to conduct an infill drilling project in Womack Hill Field. Reservoir performance, multiwell productivity analysis, and reservoir simulation studies indicate that water injection continues to provide stable support to maintain production from wells in the western unitized area of the field and that the strong water drive present in the eastern area of the field is adequate to sustain production from this part of the field. Although the results from the microbial characterization and microbial core experiments are very promising, it is recommended that an immobilized enzyme technology project not be implemented in the Womack Hill Field Unit until live (freshly taken and properly preserved) cores from the Smackover reservoir in the field are acquired to confirm the microbial core experiments to date. From 3-D geologic modeling, reservoir performance analysis, and reservoir simulation, four areas in the Womack Hill Field were identified as prospective infill drilling sites to recover undrained oil from the field. It was determined that the two areas in the unit area probably can be effectively drained by perforating higher zones in the Smackover reservoir in currently producing wells. The two areas in the eastern (non-unitized) part of the field require the drilling of new wells. The successful drilling and testing of a well in 2003 by J. R. Pounds, Inc. has proven the oil potential of the easternmost site in the non-unitized part of the field. Pruet Production Co. acquired new 2-D seismic data to evaluate the oil potential of the westernmost site. Because of the effects of a fault shadow from the major fault bounding the southern border of the Womack Hill Field, it is difficult to evaluate conclusively this potential drill site. Pruet Production Co. has decided not to drill this new well at this time and to further evaluate the new 2-D seismic profiles after these data have been processed using a pre-stack migration technique. Pruet Production Co. has elected not to continue into Phase II of this project because they are not prepared to make a proposal to the other mineral interest owners regarding the drilling of new wells as part of an infil

  14. Application of Time-Lapse Seismic Monitoring for the Control and Optimization of CO2 Enhanced Oil Recovery Operations

    SciTech Connect (OSTI)

    Brian Toelle

    2008-11-30

    This project, 'Application of Time-Lapse Seismic Monitoring for the Control and Optimization of CO{sub 2} Enhanced Oil Recovery Operations', investigated the potential for monitoring CO{sub 2} floods in carbonate reservoirs through the use of standard p-wave seismic data. This primarily involved the use of 4D seismic (time lapse seismic) in an attempt to observe and map the movement of the injected CO{sub 2} through a carbonate reservoir. The differences between certain seismic attributes, such as amplitude, were used for this purpose. This technique has recently been shown to be effective in CO{sub 2} monitoring in Enhanced Oil Recovery (EOR) projects, such as Weyborne. This study was conducted in the Charlton 30/31 field in the northern Michigan Basin, which is a Silurian pinnacle reef that completed its primary production in 1997 and was scheduled for enhanced oil recovery using injected CO{sub 2}. Prior to injection an initial 'Base' 3D survey was obtained over the field and was then processed and interpreted. CO{sub 2} injection within the main portion of the reef was conducted intermittently during 13 months starting in August 2005. During this time, 29,000 tons of CO{sub 2} was injected into the Guelph formation, historically known as the Niagaran Brown formation. By September 2006, the reservoir pressure within the reef had risen to approximately 2000 lbs and oil and water production from the one producing well within the field had increased significantly. The determination of the reservoir's porosity distribution, a critical aspect of reservoir characterization and simulation, proved to be a significant portion of this project. In order to relate the differences observed between the seismic attributes seen on the multiple 3D seismic surveys and the actual location of the CO{sub 2}, a predictive reservoir simulation model was developed based on seismic attributes obtained from the base 3D seismic survey and available well data. This simulation predicted that the CO{sub 2} injected into the reef would remain in the northern portion of the field. Two new wells, the State Charlton 4-30 and the Larsen 3-31, were drilled into the field in 2006 and 2008 respectively and supported this assessment. A second (or 'Monitor') 3D seismic survey was acquired during September 2007 over most of the field and duplicated the first (Base) survey, as much as possible. However, as the simulation and new well data available at that time indicated that the CO{sub 2} was concentrated in the northern portion of the field, the second seismic survey was not acquired over the extreme southern end of the area covered by the original (or Base) 3D survey. Basic processing was performed on the second 3D seismic survey and, finally, 4D processing methods were applied to both the Base and the Monitor surveys. In addition to this 3D data, a shear wave seismic data set was obtained at the same time. Interpretation of the 4D seismic data indicated that a significant amplitude change, not attributable to differences in acquisition or processing, existed at the locations within the reef predicted by the reservoir simulation. The reservoir simulation was based on the porosity distribution obtained from seismic attributes from the Base 3D survey. Using this validated reservoir simulation the location of oil within the reef at the time the Monitor survey was obtained and recommendations made for the drilling of additional EOR wells. The economic impact of this project has been estimated in terms of both enhanced oil recovery and CO{sub 2} sequestration potential. In the northern Michigan Basin alone, the Niagaran reef play is comprised of over 700 Niagaran reefs with reservoirs already depleted by primary production. Potentially there is over 1 billion bbls of oil (original oil in place minus primary recovery) remains in the reefs in Michigan, much of which could be more efficiently mobilized utilizing techniques similar to those employed in this study.

  15. Copyright 1998, Society of Petroleum Engineers, Inc. This paper was prepared for presentation at the 1998 SPE/DOE Improved Oil Recovery

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    at the 1998 SPE/DOE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, 19­22 April 1998. This paper-972-952-9435. Abstract This paper deals with growth of injection hydrofractures in transient linear flow in a low flow. In other words, at constant injection pressure, injection rate is remarkably constant. Therefore

  16. 3-D Reservoir and Stochastic Fracture Network Modeling for Enhanced Oil Recovery, Circle Ridge Phosphoria/Tensleep Reservoir, and River Reservation, Arapaho and Shoshone Tribes, Wyoming

    SciTech Connect (OSTI)

    La Pointe, Paul R.; Hermanson, Jan

    2002-09-09

    The goal of this project is to improve the recovery of oil from the Circle Ridge Oilfield, located on the Wind River Reservation in Wyoming, through an innovative integration of matrix characterization, structural reconstruction, and the characterization of the fracturing in the reservoir through the use of discrete fracture network models.

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

    E-Print Network [OSTI]

    Richardson, James Malone

    1958-01-01

    , diethylamine, or normal butylamine in an air drive prior to waterflooding re- duces the amount of oil recovered by the waterflood. 5. although more than 95 percent of the ammonia is absorbed on the sand or in the fluids, this process does not prevent dis...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...

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

    SciTech Connect (OSTI)

    Yortsos, Yanis C.

    2002-10-08

    In this report, the thrust areas 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.

  19. On a three-layer Hele-Shaw model of enhanced oil recovery with a linear viscous profile

    E-Print Network [OSTI]

    Daripa, Prabir; Meneses, Rodrigo

    2015-01-01

    We present a non-standard eigenvalue problem that arises in the linear stability of a three-layer Hele-Shaw model of enhanced oil recovery. A nonlinear transformation is introduced which allows reformulation of the non-standard eigenvalue problem as a boundary value problem for Kummer's equation when the viscous profile of the middle layer is linear. Using the existing body of works on Kummer's equation, we construct an exact solution of the eigenvalue problem and provide the dispersion relation implicitly through the existence criterion for the non-trivial solution. We also discuss the convergence of the series solution. It is shown that this solution reduces to the physically relevant solutions in two asymptotic limits: (i) when the linear viscous profile approaches a constant viscous profile; or (ii) when the length of the middle layer approaches zero.

  20. Improved oil recovery in Mississippian carbonate reservoirs of Kansas -- near term -- Class 2. Quarterly report, April 1--June 30, 1995

    SciTech Connect (OSTI)

    Carr, T.; Green, D.W.; Willhite, G.P.; Schoeling, L.; Reynolds, R.

    1995-07-01

    The objective of this project is to demonstrate incremental reserves from Osagian and Meramecian (Mississippian) dolomite reservoirs in western Kansas through application of reservoir characterization to identify areas of unrecovered mobile oil. The project addresses producibility problems in two fields: specific reservoirs target the Schaben Field in Ness County, Kansas, and the Bindley Field in Hodgeman County, Kansas. The producibility problems to be addressed include inadequate reservoir characterization, drilling and completion design problems, non-optimum recovery efficiency. The results of this project will be disseminated through various technology transfer activities. General overview--progress is reported for the period from 1 April 1995 to 30 June 1995. Work in this quarter has concentrated on reservoir characterization with the initiation of technology transfer. Difficulties still remain in the drilling of the final two wells. Some preliminary work on reservoir characterization has been completed, and related technology transfer has been initiated.

  1. A mixed formulation for a modification to Darcy equation with applications to enhanced oil recovery and carbon-dioxide sequestration

    E-Print Network [OSTI]

    Nakshatrala, K B

    2011-01-01

    In this paper we consider a modification to Darcy equation by taking into account the dependence of viscosity on the pressure. We present a stabilized mixed formulation for the resulting governing equations. Equal-order interpolation for the velocity and pressure is considered, and shown to be stable (which is not the case under the classical mixed formulation). The proposed mixed formulation is tested using a wide variety of numerical examples. The proposed formulation is also implemented in a parallel setting, and the performance of the formulation for large-scale problems is illustrated using a representative problem. Two practical and technologically important problems, one each on enhanced oil recovery and carbon-dioxide sequestration, are solved using the proposed formulation. The numerical results clearly indicate the importance of considering the role of dependence of viscosity on the pressure.

  2. Report of the workshop on Arctic oil and gas recovery. [Offshore

    SciTech Connect (OSTI)

    Sackinger, W. M.

    1980-09-01

    Mission of the workshop was to identify research priorities for the technology related to Arctic offshore oil and gas production. Two working groups were formed on ice-related subjects and soil-related subjects. Instrumentation needed to accomplish some of the research objectives was also discussed. Results of a research priority allocation survey are summarized. (DLC)

  3. A correlation between wettability and the recovery of oil by water flooding 

    E-Print Network [OSTI]

    Miller, Robert Thomas

    1956-01-01

    formed by placing a second fluid in contact with a solid that has already been in contact with the other fluido Consequently~ the terms advancing and receding angles, as used in this work~ merely serve to denote whether oil or brine was originally...

  4. A top-injection bottom-production cyclic steam stimulation method for enhanced heavy oil recovery 

    E-Print Network [OSTI]

    Matus, Eric Robert

    2006-10-30

    A novel method to enhance oil production during cyclic steam injection has been developed. In the Top-Injection and Bottom-Production (TINBOP) method, the well contains two strings separated by two packers (a dual and a single packer): the short...

  5. ECMOR XIII 13th European Conference on the Mathematics of Oil Recovery

    E-Print Network [OSTI]

    Vallette, Bruno

    . Eymard (University Paris East), C. Guichard* (University of Nice Sophia Antipolis), R. Herbin (University and optimize the production of a reservoir. In sedimentary basin modelling, such models are used to simulate the migration of the oil and gas phases in a basin saturated with water at geological space and time scales

  6. Understanding the Rate of Clean Up for Oil Zones after a Gel Treatment R.S. Seright, SPE, New Mexico Petroleum Recovery Research Center, W. Brent Lindquist, SPE, and Rong Cai,

    E-Print Network [OSTI]

    New York at Stoney Brook, State University of

    SPE 112976 Understanding the Rate of Clean Up for Oil Zones after a Gel Treatment R.S. Seright, SPE at the 2008 SPE Improved Oil Recovery Symposium held in Tulsa, Oklahoma, U.S.A., 19­23 April 2008. This paper to establish why pore-filling Cr(III)-acetate- HPAM gels reduced permeability to water much more than to oil

  7. Recovery of bypassed oil in the Dundee Formation using horizontal drains. Annual report, April 1994--June 1995

    SciTech Connect (OSTI)

    Wood, J.

    1995-08-01

    Crystal Field in Montcalm County, MI, was selected as a field trial site for this project. Analysis of production data for Crystal Field suggests that an additional 200,000 bbls of oil can be produced using one strategically located horizontal well. Total addition production from the Crystal Field could be as much as 6--8 MMBO. Application of the technology developed in this project to other Dundee fields in the area has the potential to increase Dundee production in Michigan by 35%, adding 80--100 MMBO to ultimate recovery. This project will demonstrate through a field trial that horizontal wells can be substantially increase oil production in older reservoirs that are at or near their economic limit. To maximize the potential of the horizontal well and to ensure that a comprehensive evaluation can be made, extensive reservoir characterization will be performed. In addition to the proposed field trial at Crystal Field, 29 additional Dundee fields in a seven-county area have been selected for study in the reservoir characterization portion of this project.

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

    SciTech Connect (OSTI)

    David B. Burnett; Mustafa Siddiqui

    2006-12-29

    Management and disposal of produced water is one of the most important problems associated with oil and gas (O&G) production. O&G production operations generate large volumes of brine water along with the petroleum resource. Currently, produced water is treated as a waste and is not available for any beneficial purposes for the communities where oil and gas is produced. Produced water contains different contaminants that must be removed before it can be used for any beneficial surface applications. Arid areas like west Texas produce large amount of oil, but, at the same time, have a shortage of potable water. A multidisciplinary team headed by researchers from Texas A&M University has spent more than six years is developing advanced membrane filtration processes for treating oil field produced brines The government-industry cooperative joint venture has been managed by the Global Petroleum Research Institute (GPRI). The goal of the project has been to demonstrate that treatment of oil field waste water for re-use will reduce water handling costs by 50% or greater. Our work has included (1) integrating advanced materials into existing prototype units and (2) operating short and long-term field testing with full size process trains. Testing at A&M has allowed us to upgrade our existing units with improved pre-treatment oil removal techniques and new oil tolerant RO membranes. We have also been able to perform extended testing in 'field laboratories' to gather much needed extended run time data on filter salt rejection efficiency and plugging characteristics of the process train. The Program Report describes work to evaluate the technical and economical feasibility of treating produced water with a combination of different separation processes to obtain water of agricultural water quality standards. Experiments were done for the pretreatment of produced water using a new liquid-liquid centrifuge, organoclay and microfiltration and ultrafiltration membranes for the removal of hydrocarbons from produced water. The results of these experiments show that hydrocarbons from produced water can be reduced from 200 ppm to below 29 ppm level. Experiments were also done to remove the dissolved solids (salts) from the pretreated produced water using desalination membranes. Produced water with up to 45,000 ppm total dissolved solids (TDS) can be treated to agricultural water quality water standards having less than 500 ppm TDS. The Report also discusses the results of field testing of various process trains to measure performance of the desalination process. Economic analysis based on field testing, including capital and operational costs, was done to predict the water treatment costs. Cost of treating produced water containing 15,000 ppm total dissolved solids and 200 ppm hydrocarbons to obtain agricultural water quality with less than 200 ppm TDS and 2 ppm hydrocarbons range between $0.5-1.5 /bbl. The contribution of fresh water resource from produced water will contribute enormously to the sustainable development of the communities where oil and gas is produced and fresh water is a scarce resource. This water can be used for many beneficial purposes such as agriculture, horticulture, rangeland and ecological restorations, and other environmental and industrial application.

  9. Potential use of California lignite and other alternate fuel for enhanced oil recovery. Phase I and II. Final report. [As alternative fuels for steam generation in thermal EOR

    SciTech Connect (OSTI)

    Shelton, R.; Shimizu, A.; Briggs, A.

    1980-02-01

    The Nation's continued reliance on liquid fossil fuels and decreasing reserves of light oils gives increased impetus to improving the recovery of heavy oil. Thermal enhanced oil recovery EOR techniques, such as steam injection, have generally been the most effective for increasing heavy oil production. However, conventional steam generation consumes a large fraction of the produced oil. The substitution of alternate (solid) fuels would release much of this consumed oil to market. This two-part report focuses on two solid fuels available in California, the site of most thermal EOR - petroleum coke and lignite. Phase I, entitled Economic Analysis, shows detailed cost comparisons between the two candidate fuels and also with Western coal. The analysis includes fuels characterizations, process designs for several combustion systems, and a thorough evaluation of the technical and economic uncertainties. In Phase II, many technical parameters of petroleum coke combustion were measured in a pilot-plant fluidized bed. The results of the study showed that petroleum coke combustion for EOR is feasible and cost effective in a fluidized bed combustor.

  10. Review of technology for Arctic offshore oil and gas recovery. Appendices

    SciTech Connect (OSTI)

    Sackinger, W. M.

    1980-06-06

    This volume contains appendices of the following: US Geological Survey Arctic operating orders, 1979; Det Noske Vertas', rules for the design, construction and inspection of offshore technology, 1977; Alaska Oil and Gas Association, industry research projects, March 1980; Arctic Petroleum Operator's Association, industry research projects, January 1980; selected additional Arctic offshore bibliography on sea ice, icebreakers, Arctic seafloor conditions, ice-structures, frost heave and structure icing.

  11. Water-related Issues Affecting Conventional Oil and Gas Recovery and Potential Oil-Shale Development in the Uinta Basin, Utah

    SciTech Connect (OSTI)

    Michael Vanden Berg; Paul Anderson; Janae Wallace; Craig Morgan; Stephanie Carney

    2012-04-30

    Saline water disposal is one of the most pressing issues with regard to increasing petroleum and natural gas production in the Uinta Basin of northeastern Utah. Conventional oil fields in the basin provide 69 percent of Utah?s total crude oil production and 71 percent of Utah?s total natural gas, the latter of which has increased 208% in the past 10 years. Along with hydrocarbons, wells in the Uinta Basin produce significant quantities of saline water ? nearly 4 million barrels of saline water per month in Uintah County and nearly 2 million barrels per month in Duchesne County. As hydrocarbon production increases, so does saline water production, creating an increased need for economic and environmentally responsible disposal plans. Current water disposal wells are near capacity, and permitting for new wells is being delayed because of a lack of technical data regarding potential disposal aquifers and questions concerning contamination of freshwater sources. Many companies are reluctantly resorting to evaporation ponds as a short-term solution, but these ponds have limited capacity, are prone to leakage, and pose potential risks to birds and other wildlife. Many Uinta Basin operators claim that oil and natural gas production cannot reach its full potential until a suitable, long-term saline water disposal solution is determined. The enclosed project was divided into three parts: 1) re-mapping the base of the moderately saline aquifer in the Uinta Basin, 2) creating a detailed geologic characterization of the Birds Nest aquifer, a potential reservoir for large-scale saline water disposal, and 3) collecting and analyzing water samples from the eastern Uinta Basin to establish baseline water quality. Part 1: Regulators currently stipulate that produced saline water must be disposed of into aquifers that already contain moderately saline water (water that averages at least 10,000 mg/L total dissolved solids). The UGS has re-mapped the moderately saline water boundary in the subsurface of the Uinta Basin using a combination of water chemistry data collected from various sources and by analyzing geophysical well logs. By re-mapping the base of the moderately saline aquifer using more robust data and more sophisticated computer-based mapping techniques, regulators now have the information needed to more expeditiously grant water disposal permits while still protecting freshwater resources. Part 2: Eastern Uinta Basin gas producers have identified the Birds Nest aquifer, located in the Parachute Creek Member of the Green River Formation, as the most promising reservoir suitable for large-volume saline water disposal. This aquifer formed from the dissolution of saline minerals that left behind large open cavities and fractured rock. This new and complete understanding the aquifer?s areal extent, thickness, water chemistry, and relationship to Utah?s vast oil shale resource will help operators and regulators determine safe saline water disposal practices, directly impacting the success of increased hydrocarbon production in the region, while protecting potential future oil shale production. Part 3: In order to establish a baseline of water quality on lands identified by the U.S. Bureau of Land Management as having oil shale development potential in the southeastern Uinta Basin, the UGS collected biannual water samples over a three-year period from near-surface aquifers and surface sites. The near-surface and relatively shallow groundwater quality information will help in the development of environmentally sound water-management solutions for a possible future oil shale and oil sands industry and help assess the sensitivity of the alluvial and near-surface bedrock aquifers. This multifaceted study will provide a better understanding of the aquifers in Utah?s Uinta Basin, giving regulators the tools needed to protect precious freshwater resources while still allowing for increased hydrocarbon production.

  12. The effect of carbon dioxide-oxygen mixtures on oil recovery by in-situ combustion 

    E-Print Network [OSTI]

    Broussard, Neal Joseph

    1970-01-01

    into the combustion reaction but will move through the burning front. It will carry a greater amount of heat to the unburned portion of the O. l 50 IOO ISO TEMPERATURE ( F) FIGURE I: CHANGE OF VISCOSITY WITH TEMPERATURE reservoir. Second, carbon dioxide has...=tively. The higher recovery from Run 1 as compared to Run 3 was attributed to two properties of carbon dioxide, First, the higher heat capacity of carbon dioxide, as compared to nitrogen, made it possible to carry more heat forward to the unburned portion...

  13. Modification of chemical and physical factors in steamflood to increase heavy oil recovery. Annual report, October 1, 1992--September 30, 1993

    SciTech Connect (OSTI)

    Yortsos, Y.C.

    1994-10-01

    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. Objectives of this work contract are to carry out new studies in the following areas: displacement and flow properties of fluids involving phase change in porous media; flow properties of mobility control fluids (such as foam); and the effect of reservoir heterogeneity on thermal recovery. Specific projects address the need to improve heavy oil recovery from typical reservoirs as well as less conventional fractured reservoirs producing from vertical or horizontal wells. In the area of vapor-liquid flow, we present the continuation of work on the pore network modeling of bubble growth in porous media driven by the application of a prescribed heat flux or superheat. The scaling of bubble growth in porous media is also discussed. In another study we study the problem of steam injection in fractured systems using visualization in micromodels. The interplay of drainage, imbibition and bubble growth problems is discussed.

  14. WETTABILITY AND PREDICTION OF OIL RECOVERY FROM RESERVOIRS DEVELOPED WITH MODERN DRILLING AND COMPLETION FLUIDS

    SciTech Connect (OSTI)

    Jill S. Buckley; Norman R. Morrow

    2006-01-01

    The objectives of this project are: (1) to improve understanding of the wettability alteration of mixed-wet rocks that results from contact with the components of synthetic oil-based drilling and completion fluids formulated to meet the needs of arctic drilling; (2) to investigate cleaning methods to reverse the wettability alteration of mixed-wet cores caused by contact with these SBM components; and (3) to develop new approaches to restoration of wetting that will permit the use of cores drilled with SBM formulations for valid studies of reservoir properties.

  15. Water-related Issues Affecting Conventional Oil and Gas Recovery and

    Office of Scientific and Technical Information (OSTI)

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of NaturalDukeWakefieldSulfateSciTechtail.Theory of rare Kaonfor DirectSciTech Connect Wall-touchingPotential Oil-Shale

  16. The Utilization of the Microflora Indignous to and Present in Oil-Bearing Formations to Selectively Plug the more Porous Zones Thereby Increasing Oil Recovery During Waterflooding

    SciTech Connect (OSTI)

    Brown, L.R.; Vadie, A.A.

    1997-04-20

    The objective of this work is to demonstrate the use of indigenous microbes as a method of profile control in waterfloods. It is expected that as the microbial population is induced to increase, that the expanded biomass will selectively block the more permeable zones of the reservoir thereby forcing injection water to flow through the less permeable zones which will result in improved sweep efficiency. This increase in microbial population will be accomplished by injecting a nutrient solution into four injectors. Four other injectors will act as control wells. During Phase 1, two wells will be cored through the zone of interest. The core will be subjected to special core analyses in order to arrive at the optimum nutrient formulation. During Phase 11, nutrient injection will begin, the results monitored, and adjustments to the nutrient composition made, if necessary. Phase 11 also will include the drilling of three wells for postmortem core analysis. Phase III will focus on technology transfer of the results. It should be pointed out that one expected outcome of this new technology will be a prolongation of economical waterflooding operations, i.e. economical oil recovery should continue for much longer periods in the producing wells subjected to this selective plugging technique. Results from work under DOE Contract No. DE-AC22-90BC14665 will be incorporated as appropriate.

  17. Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas - Near-term, Class I

    SciTech Connect (OSTI)

    Green, D.W.; Willhite, G.P.; Reynolds, Rodney R.; McCune, A. Dwayne; Michnick, Michael J.; Walton, Anthony W.; Watney, W. Lynn

    2000-06-08

    This project involved two demonstration projects, one in a Marrow reservoir located in the southwestern part of the state and the second in the Cherokee Group in eastern Kansas. Morrow reservoirs of western Kansas are still actively being explored and constitute an important resource in Kansas. Cumulative oil production from the Morrow in Kansas is over 400,000,000 bbls. Much of the production from the Morrow is still in the primary stage and has not reached the mature declining state of that in the Cherokee. The Cherokee Group has produced about 1 billion bbls of oil since the first commercial production began over a century ago. It is a billion-barrel plus resource that is distributed over a large number of fields and small production units. Many of the reservoirs are operated close to the economic limit, although the small units and low production per well are offset by low costs associated with the shallow nature of the reservoirs (less than 1000 ft. deep).

  18. Oil recovery improvement through profile modification by thermal precipitation. Final report, October 1, 1991--August 27, 1993

    SciTech Connect (OSTI)

    Reis, J.C.

    1994-04-01

    The objective of this research project has been to investigate the potential for using temperature-dependent (thermal) precipitation of chemicals to reduce the porosity and permeability of porous rocks. The method consists of injecting hot water that is saturated in a chemical that will precipitate upon cooling. Through this process, the permeability of thief zones in oil reservoirs could be reduced, allowing improved recovery by secondary and tertiary recovery processes. The chemical literature was reviewed for environmentally safe chemicals that have a suitable temperature-dependent solubility for the thermal precipitation process. Four suitable chemicals were identified: boron oxide, potassium carbonate, sodium borate, and potassium chloride. An experimental apparatus was constructed to test the thermal precipitation process at high temperatures and pressures. Data was collected with clastic Berea sandstone cores using two chemicals: potassium carbonate and sodium borate. Data was also collected with limestone cores using potassium carbonate. The porosities and permeabilities were measured before and after being treated by the thermal precipitation process. A theoretical study of the process was also conducted. A model for predicting the fractional reduction in porosity was developed that is based on the temperature-dependent solubility of the chemical used. An empirical model that predicts the fractional reduction in permeability in terms of the fractional reduction in porosity was then developed for Berea sandstone. Existing theoretical models for estimating the permeability of porous media were tested against the measured data. The existing models, including the widely-used Carman-Kozeny equation, underpredicted the reduction in permeability for the thermal precipitation process. This study has shown that the thermal precipitation process has considerable potential for the controlled reduction in porosity and permeability in geologic formations.

  19. Molecular modeling in support of CO2 sequestration and enhanced oil recovery.

    SciTech Connect (OSTI)

    Criscenti, Louise Jacqueline; Bracco, Jacquelyn

    2011-01-01

    Classical molecular dynamics simulations were used to investigate the formation of water droplets on two kaolinite surfaces: the gibbsite-like surface which is hydrophilic and the silica surface which is hydrophobic. Two methods for calculating contact angles were investigated in detail. The method of Giovambattista et al. was successful in calculating contact angles on both surfaces that compare well to the experimental data available. This is the first time that contact angles have been calculated for kaolinite surfaces from molecular simulations. This preliminary study provides the groundwork for investigating contact angles for more complex systems involving multiple fluids (water, CO{sub 2}, oil) in contact with different minerals in the subsurface environment.

  20. Research on improved and enhanced oil recovery in Illinois through reservoir characterization. [Quarterly technical report], December 28, 1991--March 28, 1992

    SciTech Connect (OSTI)

    Oltz, D.F.

    1992-04-01

    This project will provide information that can maximize hydrocarbon production minimize formation damage and stimulate new production in Illinois. Such information includes definition of hydrocarbon resources, characterization of hydrocarbon reservoirs, and the implementation of methods that will improve hydrocarbon extractive technology. Increased understanding of reservoir heterogeneities that affect oil recovery can aid in identifying producible resources. The transfer of technology to industry and the general public is a significant component of the program. The project is designed to examine selected subsurface oil reservoirs in Illinois. Scientists use advanced scientific techniques to gain a better understanding of reservoir components and behavior and address ways of potentially increasing the amount of recoverable oil. Initial production rates for wells in the Illinois Basin commonly decline quite rapidly and as much as 60 percent of the oil in place can be unrecoverable using standard operating procedures. Heterogeneities (geological differences in reservoir make-up) affect a reservoir`s capability to release fluids. By-passed mobile and immobile oil remain in the reservoir. To learn how to get more of the oil out of reservoirs, the ISGS is studying the nature of reservoir rock heterogeneities and their control on the distribution and production of by-passed, mobile oil.

  1. Supplying Synthetic Crude Oil from Canadian Oil Sands: A Comparative Study of the Costs and CO2 Emissions of Mining and In-Situ Recovery

    E-Print Network [OSTI]

    Méjean, A.; Hope, Chris

    Aurélie Méjean and Chris Hope High crude oil prices and the eventual decline of conventional oil production raise the issue of alternative fuels such as non-conventional oil. The paper describes a simple probabilistic model of the costs of synthetic... and production constraints on the costs of supplying synthetic crude oil from Canadian bitumen deposits. The results show the uncertainties associated with the future costs of synthetic crude oil. Carbon costs have a large impact of the total costs...

  2. Increased oil production and reserves utilizing secondary/tertiary recovery techniques on small reservoirs in the Paradox Basin, Utah, Class II

    SciTech Connect (OSTI)

    Chidsey, Thomas C.

    2000-07-28

    The primary objective of this project is to enhance domestic petroleum production by field demonstration and technology transfer of an advanced-oil-recovery technology in the Paradox basin, southeastern Utah. If this project can demonstrate technical and economic feasibility, the technique can be applied to approximately 100 additional small fields in the Paradox basin alone, and result in increased recovery of 150 to 200 million barrels (23,850,000-31,800,000 m{sup 3}) of oil. This project is designed to characterize five shallow-shelf carbonate reservoirs in the Pennsylvanian (Desmoinesian) Paradox Formation and choose the best candidate for a pilot demonstration project for either a waterflood or carbon-dioxide-miscible flood project. The field demonstration, monitoring of field performance, and associated validation activities will take place within the Navajo Nation, San Juan County, Utah.

  3. Venezuela-MEM/USA-DOE Fossil Energy Report IV-11: Supporting technology for enhanced oil recovery - EOR thermal processes

    SciTech Connect (OSTI)

    Venezuela

    2000-04-06

    This report contains the results of efforts under the six tasks of the Tenth Amendment anti Extension of Annex IV, Enhanced Oil Recovery Thermal Processes of the Venezuela/USA Energy Agreement. This report is presented in sections (for each of the six Tasks) and each section contains one or more reports that were prepared to describe the results of the effort under each of the Tasks. A statement of each Task, taken from the Agreement Between Project Managers, is presented on the first page of each section. The Tasks are numbered 68 through 73. The first through tenth report on research performed under Annex IV Venezuela MEM/USA-DOE Fossil Energy Report Number IV-1, IV-2, IV-3, IV-4, IV-5, IV-6, IV-7, IV-8, IV-9, IV-10 contain the results of the first 67 Tasks. These reports are dated April 1983, August 1984, March 1986, July 1987, November 1988, December 1989, October 1991, February 1993, March 1995, and December 1997, respectively.

  4. Visual display of reservoir parameters affecting enhanced oil recovery. Annual report, October 1, 1994--September 30, 1995

    SciTech Connect (OSTI)

    Wood, J.R.

    1996-03-01

    The purpose of this project is to provide a detailed example, based on a field trial, of how to evaluate a field for enhanced oil recovery (EOR) operations utilizing data typically available in a field that has undergone primary development. The approach will utilize readily available, affordable computer software and analytical services. For example, the GeoGraphix Exploration System software package was acquired, installed on a PC in the Subsurface Laboratory at Michigan Technological University, and is currently in use. The USGS Digital Land Grid and National Geophysical Data Center`s Gravity Data CDROM were acquired and installed on GeoGraphix. Microsoft Access databases are being developed to archive analytical data and digitized log traces. Data tables for geochemical and petrographic data, well logs, well header information, well production data, formation tops, and fault trace data have been completed. A new effort was initiated during the last quarter of 1995. The surface geological maps of the southern San Joaquin Valley were digitized and loaded into the computer drafting program Canvas where they were edited combined into one large map and colored. When completed, the integrated map will be printed in large format on the HP650C color plotter.

  5. Jumpstarting commercial-scale CO2 capture and storage with ethylene production and enhanced oil recovery in the US Gulf

    DOE Public Access Gateway for Energy & Science Beta (PAGES Beta)

    Middleton, Richard S.; Levine, Jonathan S.; Bielicki, Jeffrey M.; Viswanathan, Hari S.; Carey, J. William; Stauffer, Philip H.

    2015-04-27

    CO2 capture, utilization, and storage (CCUS) technology has yet to be widely deployed at a commercial scale despite multiple high-profile demonstration projects. We suggest that developing a large-scale, visible, and financially viable CCUS network could potentially overcome many barriers to deployment and jumpstart commercial-scale CCUS. To date, substantial effort has focused on technology development to reduce the costs of CO2 capture from coal-fired power plants. Here, we propose that near-term investment could focus on implementing CO2 capture on facilities that produce high-value chemicals/products. These facilities can absorb the expected impact of the marginal increase in the cost of production onmore »the price of their product, due to the addition of CO2 capture, more than coal-fired power plants. A financially viable demonstration of a large-scale CCUS network requires offsetting the costs of CO2 capture by using the CO2 as an input to the production of market-viable products. As a result, we demonstrate this alternative development path with the example of an integrated CCUS system where CO2 is captured from ethylene producers and used for enhanced oil recovery in the U.S. Gulf Coast region.« less

  6. Improved Mobility Control for Carbon Dioxide (CO{sub 2}) Enhanced Oil Recovery Using Silica-Polymer-Initiator (SPI) Gels

    SciTech Connect (OSTI)

    Oglesby, Kenneth

    2014-01-31

    SPI gels are multi-component silicate based gels for improving (areal and vertical) conformance in oilfield enhanced recovery operations, including water-floods and carbon dioxide (CO{sub 2}) floods, as well as other applications. SPI mixtures are like-water when pumped, but form light up to very thick, paste-like gels in contact with CO{sub 2}. When formed they are 3 to 10 times stronger than any gelled polyacrylamide gel now available, however, they are not as strong as cement or epoxy, allowing them to be washed / jetted out of the wellbore without drilling. This DOE funded project allowed 8 SPI field treatments to be performed in 6 wells (5 injection wells and 1 production well) in 2 different fields with different operators, in 2 different basins (Gulf Coast and Permian) and in 2 different rock types (sandstone and dolomite). Field A was in a central Mississippi sandstone that injected CO{sub 2} as an immiscible process. Field B was in the west Texas San Andres dolomite formation with a mature water-alternating-gas miscible CO{sub 2} flood. Field A treatments are now over 1 year old while Field B treatments have only 4 months data available under variable WAG conditions. Both fields had other operational events and well work occurring before/ during / after the treatments making definitive evaluation difficult. Laboratory static beaker and dynamic sand pack tests were performed with Ottawa sand and both fields’ core material, brines and crude oils to improve SPI chemistry, optimize SPI formulations, ensure SPI mix compatibility with field rocks and fluids, optimize SPI treatment field treatment volumes and methods, and ensure that strong gels set in the reservoir. Field quality control procedures were designed and utilized. Pre-treatment well (surface) injectivities ranged from 0.39 to 7.9 MMCF/psi. The SPI treatment volumes ranged from 20.7 cubic meters (m{sup 3}, 5460 gallons/ 130 bbls) to 691 m{sup 3} (182,658 gallons/ 4349 bbls). Various size and types of chemical/ water buffers before and after the SPI mix ensured that pre-gelled SPI mix got out into the formation before setting into a gel. SPI gels were found to be 3 to 10 times stronger than any commercially available cross-linked polyacrylamide gels based on Penetrometer and Bulk Gel Shear Testing. Because of SPI’s unique chemistry with CO{sub 2}, both laboratory and later field tests demonstrated that multiple, smaller volume SPI treatments maybe more effective than one single large SPI treatment. CO{sub 2} injectivities in injection well in both fields were reduced by 33 to 70% indicating that injected CO{sub 2} is now going into new zones. This reduction has lasted 1+ year in Field A. Oil production increased and CO{sub 2} production decreased in 5 Field A production wells, offsets to Well #1 injector, for a total of about 2,250 m{sup 3} (600,000 gallons/ 14,250 bbls) of incremental oil production- a $140 / SPI bbl return. Treated marginal production well, Field A Well #2, immediately began showing increased oil production totaling 238 m{sup 3} (63,000 gallons/ 1500 BBLs) over 1 year and an immediate 81% reduced gas-oil ratio.

  7. 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)

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

    2000-02-02

    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.

  8. In situ recovery of oil from Utah tar sand: a summary of tar sand research at the Laramie Energy Technology Center

    SciTech Connect (OSTI)

    Marchant, L.C.; Westhoff, J.D.

    1985-10-01

    This report describes work done by the United States Department of Energy's Laramie Energy Technology Center from 1971 through 1982 to develop technology for future recovery of oil from US tar sands. Work was concentrated on major US tar sand deposits that are found in Utah. Major objectives of the program were as follows: determine the feasibility of in situ recovery methods applied to tar sand deposits; and establish a system for classifying tar sand deposits relative to those characteristics that would affect the design and operation of various in situ recovery processes. Contents of this report include: (1) characterization of Utah tar sand; (2) laboratory extraction studies relative to Utah tar sand in situ methods; (3) geological site evaluation; (4) environmental assessments and water availability; (5) reverse combustion field experiment, TS-1C; (6) a reverse combustion followed by forward combustion field experiment, TS-2C; (7) tar sand permeability enhancement studies; (8) two-well steam injection experiment; (9) in situ steam-flood experiment, TS-1S; (10) design of a tar sand field experiment for air-stream co-injection, TS-4; (11) wastewater treatment and oil analyses; (12) economic evaluation of an in situ tar sand recovery process; and (13) appendix I (extraction studies involving Utah tar sands, surface methods). 70 figs., 68 tabs.

  9. Improved techniques for fluid diversion in oil recovery. First annual report

    SciTech Connect (OSTI)

    Seright, R.S.

    1993-12-01

    This three-year project has two general objectives. The first objective is to compare the effectiveness of gels in fluid diversion with those of other types of processes. Several different types of fluid-diversion processes are being compared, including those using gels, foams, emulsions, and particulates. The ultimate goals of these comparisons are 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 are being performed to verify which materials are the most effective in entering and blocking high-permeability zones. Another objective of the project is to identify the mechanisms by which materials (particularly gels) selectively reduce permeability to water more than to oil. This report describes work performed during the first year of the project. Following the introduction, Chapters 2 through 5 present several surveys concerning field applications of gel treatments. Based on the results of the surveys, guidelines are proposed in Chapter 5 for the selection of candidates for gel treatments (both injection wells and production wells). Chapters 6, 7, 8, and 11 discuss theoretical work that was performed during the project. Chapter 6 examines whether Hall plots indicated selectivity during gelant placement. Chapter 7 discusses several important theoretical aspects of gel treatments in production wells with water-coning problems. Chapter 8 considers exploitation of density differences during gelant placement. Chapter 11 presents a preliminary consideration of the use of precipitates as blocking agents. Chapters 9 and 10 detail the experimental work for the project. Chapter 9 describes an experimental investigation of gelant placement in fractured systems. Chapter 10 describes experiments that probe the mechanisms for disproportionate permeability reduction by gels.

  10. Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action, and Oil Recovery from Fractured Reservoirs by Spontaneous Imbibition

    SciTech Connect (OSTI)

    Norman Morrow; Herbert Fischer; Yu Li; Geoffrey Mason; Douglas Ruth; Siddhartha Seth; Zhengxin Tong; Evren Unsal; Siluni Wickramathilaka; Shaochang Wo; Peigui Yin

    2008-06-30

    The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the non-wetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.

  11. Real option analysis as a decision tool in oil field developments

    E-Print Network [OSTI]

    Babajide, Abisoye (Abisoye E.)

    2007-01-01

    This thesis shows the applicability and value of real options analysis in developing an oil field, and how its use along with decision analysis can maximize the returns on a given project and minimize the losses. It focuses ...

  12. WASTEWATER TREATMENT IN THE OIL SHALE INDUSTRY

    E-Print Network [OSTI]

    Fox, J.P.

    2010-01-01

    H. H. Peters, Shale Oil Waste Water Recovery by Evaporation,treatment of oil shale waste products. Consequently, bothmost difficult and costly oil shale waste stream requiring

  13. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of C02 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

    SciTech Connect (OSTI)

    Michael F. Morea

    1997-04-25

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and CO2 Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the West Dome of the Buena Vista Hills Field.

  14. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of CO2 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

    SciTech Connect (OSTI)

    Morea, Michael F.

    1999-11-01

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: (1) Reservoir Matrix and Fluid Characterization; (2) Fracture characterization; (3) reservoir Modeling and Simulation; and (4) CO2 Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

  15. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of C02 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

    SciTech Connect (OSTI)

    Michael F. Morea.

    1998-04-23

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and CO2 Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

  16. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of CO2 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

    SciTech Connect (OSTI)

    Morea, Michael F.

    1999-11-08

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO2 enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO2 project will demonstrate the economic viability and widespread applicability of CO2 flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: (1) Reservoir Matrix and Fluid Characterization; (2) Fracture characterization; (3) reservoir Modeling and Simulation; and (4) CO2 Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

  17. Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama. Annual report, March 1996--March 1997

    SciTech Connect (OSTI)

    Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Groshong, R.H.

    1997-08-01

    Gilbertown Field is the oldest oil field in Alabama and produces oil from chalk of the Upper Cretaceous Selma Group and from sandstone of the Eutaw Formation along the southern margin of the Gilbertown fault system. Most of the field has been in primary recovery since establishment, but production has declined to marginally economic levels. This investigation applies advanced geologic concepts designed to aid implementation of improved recovery programs. The Gilbertown fault system is detached at the base of Jurassic salt. The fault system began forming as a half graben and evolved in to a full graben by the Late Cretaceous. Conventional trapping mechanisms are effective in Eutaw sandstone, whereas oil in Selma chalk is trapped in faults and fault-related fractures. Burial modeling establishes that the subsidence history of the Gilbertown area is typical of extensional basins and includes a major component of sediment loading and compaction. Surface mapping and fracture analysis indicate that faults offset strata as young as Miocene and that joints may be related to regional uplift postdating fault movement. Preliminary balanced structural models of the Gilbertown fault system indicate that synsedimentary growth factors need to be incorporated into the basic equations of area balance to model strain and predict fractures in Selma and Eutaw reservoirs.

  18. Report of the workshop on Arctic oil and gas recovery held at Sandia National Laboratories, Albuquerque, New Mexico, June 30-July 2, 1980

    SciTech Connect (OSTI)

    Sackinger, W. M.

    1980-09-01

    This report is the result of a workshop on Arctic offshore oil and gas recovery, held at Sandia National Laboratories Albuquerque, New Mexico, on June 30-July 2, 1980. Research priorities for the technology related to Arctic offshore oil and gas production were defined. The workshop was preceded by a report entitled, A Review of Technology for Arctic Offshore Oil and Gas Recovery, authored by Dr. W. M. Sackinger. The mission of the workshop was to identify research priorities without considering whether the research should be conducted by government or by industry. Nevertheless, at the end of the meeting the general discussion did consider this, and the concensus was that environmental properties should certainly be of concern to the government, that implementation of petroleum operations was the province of industry, and that overlapping, coordinated areas of interest include both environment and interactions of the environment with structures, transport systems, and operations. An attempt to establish relative importance and a time frame was made after the workshop through the use of a survey form. The form and a summary of its results, and a discussion of its implications, are given.

  19. Increased oil production and reserves utilizing secondary/tertiary recovery techniques on small reservoirs in the Paradox basin, Utah. Annual report

    SciTech Connect (OSTI)

    Chidsey, T.C. Jr.

    1997-02-01

    The Paradox basin of Utah, Colorado, and Arizona contains nearly 100 small oil fields producing from carbonate buildups or mounds within the Pennsylvanian (Desmoinesian) Paradox Formation. These fields typically have one to four wells with primary production ranging from 700,000 to 2,000,000 barrels of oil per field at a 15 to 20% recovery rate. At least 200 million barrels of oil is at risk of being unrecovered in these small fields because of inefficient recovery practices and undrained heterogeneous reservoirs. Five fields (Anasazi, mule, Blue Hogan, heron North, and Runway) within the Navajo Nation of southeastern utah are being evaluated for waterflood or carbon-dioxide-miscible flood projects based upon geological characterization and reservoir modeling. The results can be applied to other fields in the Paradox basin and the Rocky Mountain region, the Michigan and Illinois basins, and the Midcontinent. The reservoir engineering component of the work completed to date included analysis of production data and well tests, comprehensive laboratory programs, and preliminary mechanistic reservoir simulation studies. A comprehensive fluid property characterization program was completed. Mechanistic reservoir production performance simulation studies were also completed.

  20. Modification of chemical and physical factors in steamflood in increase heavy oil recovery. Annual report, October 1, 1994--September 30, 1995

    SciTech Connect (OSTI)

    Yortsos, Y.C

    1996-10-01

    The objectives of this contract is to carry our fundamental research in heavy oil recovery in the following areas: 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 oil 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. This report covers the work performed in these three areas in the past year. In the area of vapor-liquid flow we present a theoretical and numerical study of steam injection in a pore network. We characterize the displacement in terms of an effective mobility ratio and heat transfer parameters. Displacement patterns axe identified in the parameter space. In another study we discuss the problem of steam injection in fractured systems using visualization with micromodels. The interplay of drainage, imbibition and bubble growth is visualized. Conclusions are reached regarding the potential for steamflooding fractured systems. A third study focuses on the development of a pore-network model for foam formation and propagation in porous media. This model, for the first time, accounts for the fundamental mechanisms of foam propagation at the microscale and leads to the determination of various parameters that are currently treated empirically. The effect of viscous forces in displacements in heterogeneous media is described in two separate studies, one involving an extension of percolation theory to account for viscous effects, and another discussing the effect of geometry in general displacement processes.

  1. Improved oil recovery in Mississippian carbonate reservoirs of Kansas, near term, Class 2. Quarterly report, October 1, 1996--December 31, 1996

    SciTech Connect (OSTI)

    Carr, T.R.; Green, D.W.; Willhite, G.P.

    1997-02-04

    The objective of this project is to demonstrate incremental reserves from Osagian and Meramecian (Mississippian) dolomite reservoirs in western Kansas through application of reservoir characterization to identify areas of unrecovered mobile oil. The project addresses producibility problems in two fields: Specific reservoirs target the Schaben Field in Ness County, Kansas, and the Bindley Field in Hodgeman County, Kansas. The producibility problems to be addressed include inadequate reservoir characterization, drilling and completion design problems, non-optimum recovery efficiency. The results of this project will be disseminated through various technology transfer activities. Work in this quarter has continued to concentrate on Task 1.2 reservoir characterization and Task 1.3 technology transfer.

  2. Chemical Method to Improve CO{sub 2} Flooding Sweep Efficiency for Oil Recovery Using SPI-CO{sub 2} Gels

    SciTech Connect (OSTI)

    Burns, Lyle D.

    2009-04-14

    The problem in CO{sub 2} flooding lies with its higher mobility causing low conformance or sweep efficiency. This is an issue in oilfield applications where an injected fluid or gas used to mobilize and produce the oil in a marginal field has substantially higher mobility (function of viscosity and density and relative permeability) relative to the crude oil promoting fingering and early breakthrough. Conformance is particularly critical in CO{sub 2} oilfield floods where the end result is less oil recovered and substantially higher costs related to the CO{sub 2}. The SPI-CO{sub 2} (here after called “SPI”) gel system is a unique silicate based gel system that offers a technically effective solution to the conformance problem with CO{sub 2} floods. This SPI gel system remains a low viscosity fluid until an external initiator (CO{sub 2}) triggers gelation. This is a clear improvement over current technologies where the gels set up as a function of time, regardless of where it is placed in the reservoir. In those current systems, the internal initiator is included in the injected fluid for water shut off applications. In this new research effort, the CO{sub 2} is an external initiator contacted after SPI gel solution placement. This concept ensures in the proper water wet reservoir environment that the SPI gel sets up in the precise high permeability path followed by the CO{sub 2}, therefore improving sweep efficiency to a greater degree than conventional systems. In addition, the final SPI product in commercial quantities is expected to be low cost over the competing systems. This Phase I research effort provided “proof of concept” that SPI gels possess strength and may be formed in a sand pack reducing the permeability to brine and CO{sub 2} flow. This SPI technology is a natural extension of prior R & D and the Phase I effort that together show a high potential for success in a Phase II follow-on project. Carbon dioxide (CO{sub 2}) is a major by-product of hydrocarbon combustion for energy, chemical and fertilizer plants. For example, coal fired power plants emit large amounts of CO{sub 2} in order to produce electrical energy. Carbon dioxide sequestration is gaining attention as concerns mount over possible global climate change caused by rising emissions of greenhouse gases. Removing the CO{sub 2} from the energy generation process would make these plants more environmentally friendly. In addition, CO{sub 2} flooding is an attractive means to enhance oil and natural gas recovery. Capture and use of the CO{sub 2} from these plants for recycling into CO{sub 2} flooding of marginal reservoirs provides a “dual use” opportunity prior to final CO{sub 2} sequestration in the depleted reservoir. Under the right pressure, temperature and oil composition conditions, CO{sub 2} can act as a solvent, cleaning oil trapped in the microscopic pores of the reservoir rock. This miscible process greatly increases the recovery of crude oil from a reservoir compared to recovery normally seen by waterflooding. An Enhanced Oil Recovery (EOR) project that uses an industrial source of CO{sub 2} that otherwise would be vented to the atmosphere has the added environmental benefit of sequestering the greenhouse gas.

  3. Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama. Final report, March 1996--September 1998

    SciTech Connect (OSTI)

    Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Carroll, R.E.; Groshong, R.H.; Jin, G.

    1998-12-01

    This project was designed to analyze the structure of Mesozoic and Tertiary strata in Gilbertown Field and adjacent areas to suggest ways in which oil recovery can be improved. The Eutaw Formation comprises 7 major flow units and is dominated by low-resistivity, low-contrast play that is difficult to characterize quantitatively. Selma chalk produces strictly from fault-related fractures that were mineralized as warm fluid migrated from deep sources. Resistivity, dipmeter, and fracture identification logs corroborate that deformation is concentrated in the hanging-wall drag zones. New area balancing techniques were developed to characterize growth strata and confirm that strain is concentrated in hanging-wall drag zones. Curvature analysis indicates that the faults contain numerous fault bends that influence fracture distribution. Eutaw oil is produced strictly from footwall uplifts, whereas Selma oil is produced from fault-related fractures. Clay smear and mineralization may be significant trapping mechanisms in the Eutaw Formation. The critical seal for Selma reservoirs, by contrast, is where Tertiary clay in the hanging wall is juxtaposed with poorly fractured Selma chalk in the footwall. Gilbertown Field can be revitalized by infill drilling and recompletion of existing wells. Directional drilling may be a viable technique for recovering untapped oil from Selma chalk. Revitalization is now underway, and the first new production wells since 1985 are being drilled in the western part of the field.

  4. Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas - Near-term. Annual report, June 18, 1993--June 18, 1994

    SciTech Connect (OSTI)

    Green, D.W.; Willhite, G.P.

    1995-10-01

    Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep and lack of reservoir management. The poor waterflood sweep efficiency is due to (1) reservoir heterogeneity, (2) channeling of injected water through high permeability zones or fractures, and (3) clogging of water injection wells with solids as a result of poor water quality. In many instances the lack of reservoir management is due to lack of (1) data collection and organization, (2) integrated analysis of existing data by geological and engineering personnel, and (3) identification of optimum recovery techniques. 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 the latter stage of primary production) is located in Finney County, Kansas and is operated by Sharon Resources, Inc. The objective is to increase recovery efficiency and economics in these type of reservoirs. The technologies being applied to increase waterflood sweep efficiency are (1) in situ permeability modification treatments, (2) infill drilling, (3) pattern changes, and (4) air flotation to improve water quality. The technologies being applied to improve reservoir management are (1) database development, (2) reservoir simulation, (3) transient testing, (4) database management, and (5) integrated geological and engineering analysis.

  5. Improved oil recovery in fluvial dominated deltaic reservoirs of Kansas - near - term. Technical progress report, June 17, 1994--June 17, 1995

    SciTech Connect (OSTI)

    1996-07-01

    Common oil field problems exist in fluvial dominated deltaic reservoirs in Kansas. The problems are poor waterflood sweep and lack of reservoir management. The poor waterflood sweep efficiency is due to (1) reservoir heterogeneity, (2) channeling of injected water through high permeability zones or fractures, and (3) clogging of water injection wells with solids as a result of poor water quality. In many instances the lack of reservoir management is due to lack of (1) data collection and organization, (2) integrated analysis of existing data by geological and engineering personnel, and (3) identification of optimum recovery techniques. Two demonstration sites operated by different independent oil operators are involved in the project. The Stewart Field (on the latter stage of primary production) is located in Finney County, Kansas, and was operated by Sharon Resources, Inc. and is now operated by North American Resources Company. 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 objective is to increase recovery efficiency and economics in these type of reservoirs. The technologies being applied to increase waterflood sweep efficiency are (1) in situ permeability modification treatments, (2) infill drilling, (3) pattern changes, and (4) air flotation to improve water quality. The technologies being applied to improve reservoir management are (1) database development, (2) reservoir simulation, (3) transient testing, (4) database management, and (5) integrated geological and engineering analysis.

  6. 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)

    Murphy, Mark B.

    2000-10-25

    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.

  7. Reuse of Produced Water from CO2 Enhanced Oil Recovery, Coal-Bed Methane, and Mine Pool Water by Coal-Based Power Plants

    SciTech Connect (OSTI)

    Chad Knutson; Seyed Dastgheib; Yaning Yang; Ali Ashraf; Cole Duckworth; Priscilla Sinata; Ivan Sugiyono; Mark Shannon; Charles Werth

    2012-04-30

    Power generation in the Illinois Basin is expected to increase by as much as 30% by the year 2030, and this would increase the cooling water consumption in the region by approximately 40%. This project investigated the potential use of produced water from CO{sub 2} enhanced oil recovery (CO{sub 2}-EOR) operations; coal-bed methane (CBM) recovery; and active and abandoned underground coal mines for power plant cooling in the Illinois Basin. Specific objectives of this project were: (1) to characterize the quantity, quality, and geographic distribution of produced water in the Illinois Basin; (2) to evaluate treatment options so that produced water may be used beneficially at power plants; and (3) to perform a techno-economic analysis of the treatment and transportation of produced water to thermoelectric power plants in the Illinois Basin. Current produced water availability within the basin is not large, but potential flow rates up to 257 million liters per day (68 million gallons per day (MGD)) are possible if CO{sub 2}-enhanced oil recovery and coal bed methane recovery are implemented on a large scale. Produced water samples taken during the project tend to have dissolved solids concentrations between 10 and 100 g/L, and water from coal beds tends to have lower TDS values than water from oil fields. Current pretreatment and desalination technologies including filtration, adsorption, reverse osmosis (RO), and distillation can be used to treat produced water to a high quality level, with estimated costs ranging from $2.6 to $10.5 per cubic meter ($10 to $40 per 1000 gallons). Because of the distances between produced water sources and power plants, transportation costs tend to be greater than treatment costs. An optimization algorithm was developed to determine the lowest cost pipe network connecting sources and sinks. Total water costs increased with flow rate up to 26 million liters per day (7 MGD), and the range was from $4 to $16 per cubic meter ($15 to $60 per 1000 gallons), with treatment costs accounting for 13 â?? 23% of the overall cost. Results from this project suggest that produced water is a potential large source of cooling water, but treatment and transportation costs for this water are large.

  8. 3-D RESERVOIR AND STOCHASTIC FRACTURE NETWORK MODELING FOR ENHANCED OIL RECOVERY, CIRCLE RIDGE PHOSPHORIA/TENSLEEP RESERVOIR, WIND RIVER RESERVATION, ARAPAHO AND SHOSHONE TRIBES, WYOMING

    SciTech Connect (OSTI)

    Paul La Pointe; Jan Hermanson; Robert Parney; Thorsten Eiben; Mike Dunleavy; Ken Steele; John Whitney; Darrell Eubanks; Roger Straub

    2002-11-18

    This report describes the results made in fulfillment of contract DE-FG26-00BC15190, ''3-D Reservoir and Stochastic Fracture Network Modeling for Enhanced Oil Recovery, Circle Ridge Phosphoria/Tensleep Reservoir, Wind River Reservation, Arapaho and Shoshone Tribes, Wyoming''. The goal of this project is to improve the recovery of oil from the Tensleep and Phosphoria Formations in Circle Ridge Oilfield, located on the Wind River Reservation in Wyoming, through an innovative integration of matrix characterization, structural reconstruction, and the characterization of the fracturing in the reservoir through the use of discrete fracture network models. Fields in which natural fractures dominate reservoir permeability, such as the Circle Ridge Field, often experience sub-optimal recovery when recovery processes are designed and implemented that do not take advantage of the fracture systems. For example, a conventional waterflood in a main structural block of the Field was implemented and later suspended due to unattractive results. It is estimated that somewhere less than 20% of the OOIP in the Circle Ridge Field have been recovered after more than 50 years' production. Marathon Oil Company identified the Circle Ridge Field as an attractive candidate for several advanced IOR processes that explicitly take advantage of the natural fracture system. These processes require knowledge of the distribution of matrix porosity, permeability and oil saturations; and understanding of where fracturing is likely to be well-developed or poorly developed; how the fracturing may compartmentalize the reservoir; and how smaller, relatively untested subthrust fault blocks may be connected to the main overthrust block. For this reason, the project focused on improving knowledge of the matrix properties, the fault block architecture and to develop a model that could be used to predict fracture intensity, orientation and fluid flow/connectivity properties. Knowledge of matrix properties was greatly extended by calibrating wireline logs from 113 wells with incomplete or older-vintage logging suites to wells with a full suite of modern logs. The model for the fault block architecture was derived by 3D palinspastic reconstruction. This involved field work to construct three new cross-sections at key areas in the Field; creation of horizon and fault surface maps from well penetrations and tops; and numerical modeling to derive the geometry, chronology, fault movement and folding history of the Field through a 3D restoration of the reservoir units to their original undeformed state. The methodology for predicting fracture intensity and orientation variations throughout the Field was accomplished by gathering outcrop and subsurface image log fracture data, and comparing it to the strain field produced by the various folding and faulting events determined through the 3D palinspastic reconstruction. It was found that the strains produced during the initial folding of the Tensleep and Phosphoria Formations corresponded well without both the orientations and relative fracture intensity measured in outcrop and in the subsurface. The results have led to a 15% to 20% increase in estimated matrix pore volume, and to the plan to drill two horizontal drain holes located and oriented based on the modeling results. Marathon Oil is also evaluating alternative tertiary recovery processes based on the quantitative 3D integrated reservoir model.

  9. Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 78, quarter ending March 31, 1994

    SciTech Connect (OSTI)

    1995-05-01

    This report presents descriptions of various research projects and field projects concerned with the enhanced recovery of petroleum. Contract numbers, principal investigators, company names, and project management information is included.

  10. Contracts for field projects and supporting research on enhanced oil recovery. Progress review number 83, quarter ending June 30, 1995

    SciTech Connect (OSTI)

    1996-08-01

    Summaries of 41 research projects on enhanced recovery are presented under the following sections: (1) chemical flooding; (2) gas displacement; (3) thermal recovery; (4) geoscience technology; (5) resource assessment technology; and (6) reservoir classes. Each presentation gives the title of the project, contract number, research facility, contract date, expected completion data, amount of the award, principal investigator, and DOE program manager, and describes the objectives of the project and a summary of the technical progress.

  11. Area balance and strain in an extensional fault system: Strategies for improved oil recovery in fractured chalk, Gilbertown Field, southwestern Alabama -- Year 2. Annual report, March 1997--March 1998

    SciTech Connect (OSTI)

    Pashin, J.C.; Raymond, D.E.; Rindsberg, A.K.; Alabi, G.G.; Carroll, R.E.

    1998-09-01

    Gilbertown Field is the oldest oil field in Alabama and has produced oil from fractured chalk of the Cretaceous Selma Group and glauconitic sandstone of the Eutaw Formation. Nearly all of Gilbertown Field is still in primary recovery, although waterflooding has been attempted locally. The objective of this project is to analyze the geologic structure and burial history of Mesozoic and Tertiary strata in Gilbertown Field and adjacent areas in order to suggest ways in which oil recovery can be improved. Indeed, the decline of oil production to marginally economic levels in recent years has made this type of analysis timely and practical. Key technical advancements being sought include understanding the relationship of requisite strain to production in Gilbertown reservoirs, incorporation of synsedimentary growth factors into models of area balance, quantification of the relationship between requisite strain and bed curvature, determination of the timing of hydrocarbon generation, and identification of the avenues and mechanisms of fluid transport.

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

    E-Print Network [OSTI]

    Seyidov, Murad

    2011-08-08

    Many attempts have been made to control water conformance. It is very costly to produce, treat and dispose of water, and produced water represents the largest waste stream associated with oil and gas production. The production of large amounts...

  13. Contracts for field projects and supporting research on enhanced oil recovery. Progress review quarter ending September 30, 1993

    SciTech Connect (OSTI)

    Not Available

    1994-08-01

    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; and field demonstrations in high-priority reservoir classes. A list of available publications is also included.

  14. Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 71, quarter ending June 30, 1992

    SciTech Connect (OSTI)

    Not Available

    1993-06-01

    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.

  15. Contracts for field projects and supporting research on enhanced oil recovery: Progress review No. 74, Quarter ending March 31, 1993

    SciTech Connect (OSTI)

    Not Available

    1994-03-01

    Accomplishments for the past quarter 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; field demonstrations in high-priority reservoir classes; and novel technology. A list of available publication is also provided.

  16. Recovery of bypassed oil in the Dundee Formation using horizontal drains. Quarterly report, October 1 - December 31, 1996

    SciTech Connect (OSTI)

    Wood, J.R.

    1997-01-01

    The principal objective of this project is to demonstrate the feasibility and economic success of producing oil from abandoned or nearly abandoned fields in the Dundee Formation of Central Michigan using horizontal drilling technology. A site for a horizontal well was selected in Crystal Field, a nearly-abandoned Dundee oil field in Michigan. This field had produced over 8 million barrels of oil, mostly in the 1930`s and 1940`s. At the height of development, Crystal Field produced from 193 wells, but by 1995, only seven producing wells remained, each producing less than 10 bbls/day. A horizontal well was drilled as a field demonstration pilot, funded through this DOE project, and was successful. It has produced over 37,000 bbls of oil as of December 31, 1996 at sustained rate of {approximately}100 bbls/day. At a nominal wellhead price of $20/bbl, this well has made about $750,000 and is still going strong. Two additional horizontal wells have just been completed and are on test. Core and logs from the Dundee interval were recovered from a vertical borehole at the same surface location. The horizontal well was brought on production at a rate of 100 bbls/day and is probably capable of producing at a higher rate. The addition of several horizontal wells, similar to the demonstration well, will likely add another 2 million bbls (or more) to the cumulative production of the field over the next few years. The presence of untapped oil in this Dundee field was dramatically demonstrated and the favorable economics were made clearly evident. If other abandoned Dundee fields are re-developed in a similar manner, the additional oil produced could exceed 80 million barrels. Horizontal drilling will likely revolutionize the development of old carbonate fields such as those in the Dundee of Michigan.

  17. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of CO2 Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales, Class III

    SciTech Connect (OSTI)

    Perri, Pasquale R.; Cooney, John; Fong, Bill; Julander, Dale; Marasigan, Aleks; Morea, Mike; Piceno, Deborah; Stone, Bill; Emanuele, Mark; Sheffield, Jon; Wells, Jeff; Westbrook, Bill; Karnes, Karl; Pearson, Matt; Heisler, Stuart

    2000-04-24

    The primary objective of this project was to conduct advanced reservoir characterization and modeling studies in the Antelope Shale of the Bureau Vista Hills Field. Work was subdivided into two phases or budget periods. The first phase of the project focused on a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work would then be used to evaluate how the reservoir would respond to enhanced oil recovery (EOR) processes such as of CO2 flooding. The second phase of the project would be to implement and evaluate a CO2 in the Buena Vista Hills Field. A successful project would demonstrate the economic viability and widespread applicability of CO2 flooding in siliceous shale reservoirs of the San Joaquin Valley.

  18. Improved oil recovery in Mississippian carbonate reservoirs of Kansas: Near term -- Class 2. 1st Quarterly report, September 18--December 31, 1994

    SciTech Connect (OSTI)

    Carr, T.; Green, D.W.; Willhite, G.P.; Schoeling, L.; Reynolds, R.

    1995-01-01

    The objective of this project is to demonstrate incremental reserves from Osagian and Meramecian (Mississippian) dolomite reservoirs in western Kansas through application of reservoir characterization to identify areas of unrecovered mobile oil. The project addresses producibility problems in two fields: Specific reservoirs target the Schaben Field in Ness County, Kansas, and the Bindley Field in Hodgeman County, Kansas. The producibility problems to be addressed include inadequate reservoir characterization, drilling and completion design problems, non-optimum recovery efficiency. The results of this project will be disseminated through various technology transfer activities. The bulk of work to date has concentrated on Task 1.1, acquisition and consolidation of available data. Some preliminary work on reservoir characterization (Task 1.2) is underway.

  19. 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)

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

    1999-02-01

    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.

  20. 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)

    Steven Schamel

    1997-07-29

    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.

  1. 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)

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

    1997-10-21

    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.

  2. Experimental and analytical modeling studies of steam injection with hydrocarbon additives to enhance recovery of San Ardo heavy oil 

    E-Print Network [OSTI]

    Simangunsong, Roly

    2006-10-30

    :steam mass ratio. We develop a simplified analytical model that describes steam front advancement and oil production for the 1D displacement experiments. The model incorporates heat and material balance, fillup time and Darcy�s law pertaining...

  3. Recovery of bypassed oil in the Dundee Formation using horizontal drains. Annual report, March 1996--March 1997

    SciTech Connect (OSTI)

    1998-04-01

    This Class II field project has demonstrated that economic quantities of hydrocarbons can be produced from abandoned or nearly abandoned fields in the Dundee Formation of Central Michigan using horizontal drilling technology. The site selected for the demonstration horizontal well was Crystal Field, a nearly abandoned Dundee oil field in Montcalm County, Michigan. This field had produced over 8 million barrels of oil, mostly in the 1930`s and 1940`s. At the height of development, Crystal Field produced from 193 wells, but by 1995, only seven producing wells remained, each producing less than 10 bbls/day. A horizontal well, the TOW 1-3, drilled as a field demonstration pilot was successful, producing at rate of 100 bbls of oil per day with a zero water cut. Although the well is capable of producing at a of 500+ bbls/day, the production rate is being kept low deliberately to try to prevent premature water coning. Cumulative production exceeded 50,000 bbls of oil by the end of April, 1997 and lead to the permitting and licensing of several dozen Dundee wells by project end. Twelve of these permits were for continued development of Crystal Field. Two long horizontal wells were drilled successfully in Crystal after the TOW 1-3, but were disappointing economically. Core and logs from the Dundee interval were recovered from a vertical borehole at the same surface location. The addition of several horizontal wells will likely add another 2 million bbls (or more) to the cumulative production of the field over the next few years. If other abandoned Dundee fields are re-developed in a similar manner, the additional oil produced could exceed 80 million barrels.

  4. Buckley, J.S. 02 PETROLEUM; PETROLEUM; ENHANCED RECOVERY; ASPHALTENES...

    Office of Scientific and Technical Information (OSTI)

    Reservoir Wettability and its Effect on Oil Recovery. Buckley, J.S. 02 PETROLEUM; PETROLEUM; ENHANCED RECOVERY; ASPHALTENES; MINERALS; SURFACES; MICA; WETTABILITY We report on the...

  5. New CO2 Enhanced Recovery Technology Could Greatly Boost U.S...

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

    enhanced recovery in discovered fields - 90 billion in light oil, 20 billion in heavy oil; up to 179 billion barrels from undiscovered oil - 119 billion from conventional...

  6. Evaluating the End-of-Life Phase of Consumer Electronics:Methods and Tools to Improve Product Design and Material Recovery

    E-Print Network [OSTI]

    Mangold, Jennifer Ann

    2013-01-01

    plastics and therefore more e?cient material recovery, than current technology.technology is mature enough to implement in material recovery facilities. The processes to recover plastic

  7. Assessment of environmental problems associated with increased enhanced oil recovery in the United States: 1980-2000

    SciTech Connect (OSTI)

    Kaplan, E.; Garrell, M.; Royce, B.; Riedel, E.F.; Sathaye, J.

    1983-01-01

    Water requirements and uncontrolled air emissions from well vents and steam generators were estimated for each technology based upon available literature. Estimates of best air emission control technologies were made using data for EOR steam generators actually in use, as well as control technologies presently available but used by other industries. Amounts of solid wastes were calculated for each air emission control technology. Estimates were also made of the heavy metal content of these solid wastes. The study also included environmental residuals which may be expected should coal be used instead of lean crude to produce steam for thermal EOR. It was concluded that from an environmental prospective tertiary oil is preferable in many respects to shale oil, coal and synfuels. Alternative sources of oil such as syncrude, new exploration, and primary production could cause far more environmental damage than incremental EOR. Future EOR in specific regions may be constrained because of environmental issues: air emissions, solid waste disposal, water availability, and aquifer contaminators. Competition for water and the scarcity of surface water or groundwater which are low in total diminutive solids will impede some EOR projects. Risks of groundwater contamination should be minimized particularly because of requirements of the Environmental Protection Agency's new underground injection control program. A quantitative environmental assessment will require a complete and consistent data base for all fields for which EOR is planned out in which tertiary production is taking place. This is particularly true for EOR which will occur in Alaska or in offshore areas, where environments are fragile and where operating conditions are severe. 147 references, 29 figures, 46 tables.

  8. Commercial scale demonstration enhanced oil recovery by micellar-polymer flood. Annual report, October 1979-September 1980

    SciTech Connect (OSTI)

    Howell, J.C.; Snyder, W.O.

    1981-04-01

    This commercial scale test, known as the M-1 Project, is located in Crawford County, Illinois. It encompasses 407 acres of Robinson sand reservoir and covers portions of several waterflood projects that were approaching economic limit. The project includes 248 acres developed on a 2.4-acre five-spot pattern and 159 acres developed on a 5.0-acre five-spot pattern. Development work commenced in late 1974 and has previously been reported. Micellar solution (slug) injection was initiated on February 10, 1977, and is now completed. After 10% of a pore volume of micellar slug was injected, injection of 11% pore volume of Dow 700 Pusher polymer was conducted at a concentration of 1156 ppM. At the end of this reporting period, 625 ppM polymer was being injected into the 2.5-acre pattern and 800 ppM polymer was being injected into the 5.0-acre pattern. The oil cut of the 2.5 and 5.0-acre patterns increased from 8.6% and 5.2%, respectively in September 1979, to 11.0% and 5.9% in September 1980. The oil cut performance has consistently exceeded that predicted for the project. This Fourth Annual Report is organized under the following three Work Breakdown Structures: fluid injection; production; and performance monitoring.

  9. Jumpstarting commercial-scale CO2 capture and storage with ethylene production and enhanced oil recovery in the US Gulf

    SciTech Connect (OSTI)

    Middleton, Richard S.; Levine, Jonathan S.; Bielicki, Jeffrey M.; Viswanathan, Hari S.; Carey, J. William; Stauffer, Philip H.

    2015-04-27

    CO2 capture, utilization, and storage (CCUS) technology has yet to be widely deployed at a commercial scale despite multiple high-profile demonstration projects. We suggest that developing a large-scale, visible, and financially viable CCUS network could potentially overcome many barriers to deployment and jumpstart commercial-scale CCUS. To date, substantial effort has focused on technology development to reduce the costs of CO2 capture from coal-fired power plants. Here, we propose that near-term investment could focus on implementing CO2 capture on facilities that produce high-value chemicals/products. These facilities can absorb the expected impact of the marginal increase in the cost of production on the price of their product, due to the addition of CO2 capture, more than coal-fired power plants. A financially viable demonstration of a large-scale CCUS network requires offsetting the costs of CO2 capture by using the CO2 as an input to the production of market-viable products. As a result, we demonstrate this alternative development path with the example of an integrated CCUS system where CO2 is captured from ethylene producers and used for enhanced oil recovery in the U.S. Gulf Coast region.

  10. Visual display of reservoir parameters affecting enhanced oil recovery. Annual report, October 1, 1995--September 30, 1996

    SciTech Connect (OSTI)

    Wood, J.R.

    1997-04-01

    The Multimedia Database Management System (MDMS) has been developed in the commercial software package Toolbook. Design and implementation, which was carried out by C. Asiala, is now essentially complete. Regional location maps of southern San Joaquin Valley oil fields, structure contour maps of the Pioneer area, core photos, core data, thin-section and SEM photomicrographs of core materials, structural cross sections through Pioneer Anticline, an atlas of photomicrographs; illustrating typical diagenetic features observed in San Joaquin Valley petroleum reservoirs, elemental and spectral data collected on Fourier Transform Infrared Spectroscopy (FTIR) standards, and all quarterly and annual reports submitted to DOE for this project were scanned into the MDMS. All data and information are accessible through dropdown menus and hotlinks in a Table of Contents. A tutorial is presented up front to guide users through the MDMS and instruct them on the various ways in which data can be viewed and retrieved. Version 1.0 of the MDMS was written to CD ROM and distributed to participants in a Technology Transfer Workshop in Bakersfield, CA, in September, 1996. Version 1.1, which contains additional information and has been reorganized for easier use, is nearing completion. All measured and computed log curves (computed curves represent parameters such as porosity, water saturation, and clay content, which were calculated from the measured log traces using specially developed algorithms) for the 45+ project wells on Pioneer Anticline are now in the MDMS in LAS (log ASCII) format, and can be exported to any commercial log evaluation program for manipulation and analysis. All log curves were written to the CD ROM in digital format.

  11. Contracts for field projects and supporting research on enhanced oil recovery. Quarterly technical progress report, October 1994--December 1994. Progress review No. 81

    SciTech Connect (OSTI)

    1996-03-01

    This document consists of a publications list for field projects and brief descriptions of research projects on enhanced petroleum recovery.

  12. Wyoming Recovery Act State Memo

    Broader source: Energy.gov [DOE]

    Wyoming has substantial natural resources including coal, natural gas, oil, and wind power. The American Recovery & Reinvestment Act (ARRA) is making a meaningful down payment on the nation’s...

  13. Asymmetric growth in micelles containing oil Peter H. Nelson,a)

    E-Print Network [OSTI]

    Nelson, Peter Hugo

    to transcontinental geological systems.1 Industrial applications range from enhanced oil recovery and cleanup

  14. The Oil Security Metrics Model: A Tool for Evaluating the Prospective Oil Security Benefits of DOE's Energy Efficiency and Renewable Energy R&D Programs

    SciTech Connect (OSTI)

    Greene, David L [ORNL; Leiby, Paul Newsome [ORNL

    2006-05-01

    Energy technology R&D is a cornerstone of U.S. energy policy. Understanding the potential for energy technology R&D to solve the nation's energy problems is critical to formulating a successful R&D program. In light of this, the U.S. Congress requested the National Research Council (NRC) to undertake both retrospective and prospective assessments of the Department of Energy's (DOE's) Energy Efficiency and Fossil Energy Research programs (NRC, 2001; NRC, 2005). ("The Congress continued to express its interest in R&D benefits assessment by providing funds for the NRC to build on the retrospective methodology to develop a methodology for assessing prospective benefits." NRC, 2005, p. ES-2) In 2004, the NRC Committee on Prospective Benefits of DOE's Energy Efficiency and Fossil Energy R&D Programs published a report recommending a new framework and principles for prospective benefits assessment. The Committee explicitly deferred the issue of estimating security benefits to future work. Recognizing the need for a rigorous framework for assessing the energy security benefits of its R&D programs, the DOE's Office of Energy Efficiency and Renewable Energy (EERE) developed a framework and approach for defining energy security metrics for R&D programs to use in gauging the energy security benefits of their programs (Lee, 2005). This report describes methods for estimating the prospective oil security benefits of EERE's R&D programs that are consistent with the methodologies of the NRC (2005) Committee and that build on Lee's (2005) framework. Its objective is to define and implement a method that makes use of the NRC's typology of prospective benefits and methodological framework, satisfies the NRC's criteria for prospective benefits evaluation, and permits measurement of that portion of the prospective energy security benefits of EERE's R&D portfolio related to oil. While the Oil Security Metrics (OSM) methodology described in this report has been specifically developed to estimate the prospective oil security benefits of DOE's R&D programs, it is also applicable to other strategies and policies aimed at changing U.S. petroleum demand.

  15. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of CO(2) Enhanced Oil Recovery in California`s Monterey formation Siliceous Shales. Progress report, April 1-June 30, 1997

    SciTech Connect (OSTI)

    Morea, M.F.

    1997-07-25

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a C0{sub 2} enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills Pilot C0{sub 2} project will demonstrate the economic viability and widespread applicability of C0{sub 2} flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and C0{sub 2} Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

  16. Advanced reservoir characterization in the Antelope Shale to establish the viability of CO{sub 2} enhanced oil recovery in California`s Monterey Formation siliceous shales. Quarterly report, October 1, 1996--December 31, 1996

    SciTech Connect (OSTI)

    Toronyi, R.M.

    1996-12-31

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO{sub 2} enhanced oil recovery project in the Antelope Shale in Buena Vista Hills field. The Buena Vista Hills pilot CO{sub 2} project will demonstrate the economic viability and widespread applicability of CO{sub 2} flooding in fractured siliceous shales reservoirs of the San Joaquin Valley. The research consists of four primary work processes: reservoir matrix and fluid characterization: fracture characterization; reservoir modeling and simulation; and, CO{sub 2} pilot flood and evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery pilot in the West Dome of the Buena Vista Hills field. In this report, accomplishments for this period are presented for: reservoir matrix and fluid characterization; fracture characterization; reservoir modeling and simulation; and technology transfer.

  17. Advanced reservoir characterization in the Antelope Shale to establish the viability of CO{sub 2} enhanced oil recovery in California`s Monterey formation siliceous shales. Quarterly report, April 1, 1997--June 30, 1997

    SciTech Connect (OSTI)

    Morea, M.F.

    1997-07-25

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO{sub 2} enhanced oil recovery project in the Antelope Shale in Buena Vista Hills Field. The Buena Vista Hills pilot CO{sub 2} project will demonstrate the economic viability and widespread applicability of CO{sub 2} flooding in fractured siliceous shale reservoirs of the San Joaquin Valley. The research consists of four primary work processes: Reservoir Matrix and Fluid Characterization; Fracture Characterization; Reservoir Modeling and Simulation; and CO{sub 2} Pilot Flood and Evaluation. Work done in these areas is subdivided into two phases or budget periods. The first phase of the project will focus on the application of a variety of advanced reservoir characterization techniques to determine the production characteristics of the Antelope Shale reservoir. Reservoir models based on the results of the characterization work will be used to evaluate how the reservoir will respond to secondary recovery and EOR processes. The second phase of the project will include the implementation and evaluation of an advanced enhanced oil recovery (EOR) pilot in the United Anticline (West Dome) of the Buena Vista Hills Field.

  18. Simulation of Oil Displacement from Oil-Wet Cores by Interfacial Tension Reduction and Wettability Alteration

    E-Print Network [OSTI]

    Kalaei, Mohammad Hosein

    2010-01-29

    Waterflooding in oil-wet naturally fractured reservoirs is not successful because the ability of matrix blocks to imbibe the injected water and displace the oil into the fracture system is poor. Chemical enhanced oil recovery methods...

  19. DATA MINING AT THE NEBRASKA OIL & GAS COMMISSION

    SciTech Connect (OSTI)

    James R. Weber

    2001-05-01

    The purpose of this study of the hearing records is to identify factors that are likely to impact the performance of a waterflood in the Nebraska panhandle. The records consisted of 140 cases. Most of the hearings were held prior to 1980. Many of the records were incomplete, and data believed to be key to estimating waterflood performance such as Dykstra-Parson permeability distribution or relative permeability were absent. New techniques were applied to analyze the sparse, incomplete dataset. When information is available, but not clearly understood, new computational intelligence tools can decipher correlations in the dataset. Fuzzy ranking and neural networks were the tools used to estimate secondary recovery from the Cliff Farms Unit. The hearing records include 30 descriptive entries that could influence the success or failure of a waterflood. Success or failure is defined by the ratio of secondary to primary oil recovery (S/P). Primary recovery is defined as cumulative oil produced at the time of the hearing and secondary recovery is defined as the oil produced since the hearing date. Fuzzy ranking was used to prioritize the relevance of 6 parameters on the outcome of the proposed waterflood. The 6 parameters were universally available in 44 of the case hearings. These 44 cases serve as the database used to correlate the following 6 inputs with the respective S/P. (1) Cumulative Water oil ratio, bbl/bbl; (2) Cumulative Gas oil ratio, mcf/bbl; (3) Unit area, acres; (4) Average Porosity, %; (5) Average Permeability, md; (6) Initial bottom hole pressure, psi. A 6-3-1 architecture describes the neural network used to develop a correlation between the 6 input parameters and their respective S/P. The network trained to a 85% correlation coefficient. The predicted Cliff Farms Unit S/P is 0.315 or secondary recovery is expected to be 102,700 bbl.

  20. Contracts for field projects and supporting research on enhanced oil recovery. Progress review No. 80. Quarterly report, July--September, 1994

    SciTech Connect (OSTI)

    1995-11-01

    This report contains information on petroleum enhanced recovery projects. In addition to project descriptions, contract numbers, principal investigators and project management information is included.

  1. Thermally Induced Wettability Change During SAGD for Oil Sand Extraction 

    E-Print Network [OSTI]

    Unal, Yasin

    2014-08-20

    and field pilot efforts are in progress to enhance oil recovery by using less energy and water for steam generation. These efforts are simplified with the contribution of numerical simulations to optimize the oil recovery of SAGD projects. Several critical...

  2. Experimental investigation of caustic steam injection for heavy oils 

    E-Print Network [OSTI]

    Madhavan, Rajiv

    2010-01-16

    ) showed the applicability of caustic flooding for enhancing oil recovery in North Gujarat oil fields. They found that the optimum concentration of caustic that was used for the improvement of recovery was 0.25 wt %. The injection rate affected...

  3. The twentieth oil shale symposium proceedings

    SciTech Connect (OSTI)

    Gary, J.H.

    1987-01-01

    This book contains 20 selections. Some of the titles are: The technical contributions of John Ward Smith in oil shale research; Oil shale rubble fires: ignition and extinguishment; Fragmentation of eastern oil shale for in situ recovery; A study of thermal properties of Chinese oil shale; and Natural invasion of native plants on retorted oil shale.

  4. Improved recovery demonstration for Williston basin carbonates. Annual report, June 10, 1994--June 9, 1995

    SciTech Connect (OSTI)

    Sippel, M.; Zinke, S.; Magruder, G.; Eby, D.

    1995-09-01

    The purpose of this project is to demonstrate targeted infill and extension drilling opportunities, better determinations of oil-in-place, methods for improved completion efficiency and the suitability of waterflooding in Red River and Ratcliffe shallow-shelf carbonate reservoirs in the Williston Basin, Montana, North Dakota and South Dakota. Improved reservoir characterization utilizing three-dimensional and multi-component seismic are being investigated for identification of structural and stratigraphic reservoir compartments. These seismic characterization tools are integrated with geological and engineering studies. Improved completion efficiency is being tested with extended-reach jetting lance and other ultra-short-radius lateral technologies. Improved completion efficiency, additional wells at closer spacing and better estimates of oil in place will result in additional oil recovery by primary and enhanced recovery processes.

  5. 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)

    Schamel, S.

    1996-11-01

    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.

  6. An evaluation of known remaining oil resources in the United States: Appendix. Volume 10

    SciTech Connect (OSTI)

    1993-11-01

    Volume ten contains the following appendices: overview of improved oil recovery methods which covers enhanced oil recovery methods and advanced secondary recovery methods; the benefits of improved oil recovery, selected data for the analyzed states; and list of TORIS fields and reservoirs.

  7. This paper was prepared for presentation at the SPE/DOE Thirteenth Symposium on Improved Oil Recovery held in Tulsa, Oklahoma, 1317 April 2002.

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    This paper was prepared for presentation at the SPE/DOE Thirteenth Symposium on Improved Oil and are subject to correction by the author(s). The material, as presented, does not necessarily reflect any

  8. CONTROL STRATEGIES FOR ABANDONED IN-SITU OIL SHALE RETORTS

    E-Print Network [OSTI]

    Persoff, P.

    2011-01-01

    the carbon, oil, and gas from the shale are combusted; andceases •t II Burner gas and shale heat shale ll>" ~Air AirFigure 2. Oil recovery Vent gas '\\Raw shale oil Recycled gas

  9. California Recovery Act State Memo | Department of Energy

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

    Act State Memo California Recovery Act State Memo California has substantial natural resources, including oil, gas, solar, wind, geothermal, and hydroelectric power. The...

  10. Application of geostatistical reservoir description for maximizing waterflood infill drilling recovery from La Cira Field, Colombia 

    E-Print Network [OSTI]

    Cubillos Gutierrez, Helber

    1995-01-01

    One of the prospective ways to increase the oil production is to maximize the oil recovery from mature oil fields. In this study we apply an integrated approach that combines geostatistical reservoir description and reservoir ...

  11. Contracts for field projects and supporting research on enhanced oil recovery, October--December 1992. Progress review No. 73, quarter ending December 31, 1992

    SciTech Connect (OSTI)

    Not Available

    1993-12-01

    Accomplishments for this quarter ending December 31, 1992 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; reservoir classes; and novel technology.

  12. Contracts for field projects and supporting research on enhanced oil recovery, July--September 1992. Progress review No. 72, quarter ending September 30, 1992

    SciTech Connect (OSTI)

    Not Available

    1993-09-01

    Accomplishments for the past quarter 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.

  13. 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)

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

    1998-09-01

    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.

  14. Nineteenth oil shale symposium proceedings

    SciTech Connect (OSTI)

    Gary, J.H.

    1986-01-01

    This book contains 23 selections. Some of the titles are: Effects of maturation on hydrocarbon recoveries from Canadian oil shale deposits; Dust and pressure generated during commercial oil shale mine blasting: Part II; The petrosix project in Brazil - An update; Pathway of some trace elements during fluidized-bed combustion of Israeli Oil Shale; and Decommissioning of the U.S. Department of Energy Anvil Points Oil Shale Research Facility.

  15. Advanced reservoir characterization in the Antelope Shale to establish the viability of CO2 enhanced oil recovery in California`s Monterey Formation siliceous shales. Annual report, February 7, 1997--February 6, 1998

    SciTech Connect (OSTI)

    Morea, M.F.

    1998-06-01

    The primary objective of this research is to conduct advanced reservoir characterization and modeling studies in the Antelope Shale reservoir. Characterization studies will be used to determine the technical feasibility of implementing a CO{sub 2} enhanced oil recovery project in the antelope Shale in Buena Vista Hills Field. The proposed pilot consists of four existing producers on 20 acre spacing with a new 10 acre infill well drilled as the pilot CO{sub 2} injector. Most of the reservoir characterization during Phase 1 of the project will be performed using data collected in the pilot pattern wells. During this period the following tasks have been completed: laboratory wettability; specific permeability; mercury porosimetry; acoustic anisotropy; rock mechanics analysis; core description; fracture analysis; digital image analysis; mineralogical analysis; hydraulic flow unit analysis; petrographic and confocal thin section analysis; oil geochemical fingerprinting; production logging; carbon/oxygen logging; complex lithologic log analysis; NMR T2 processing; dipole shear wave anisotropy logging; shear wave vertical seismic profile processing; structural mapping; and regional tectonic synthesis. Noteworthy technological successes for this reporting period include: (1) first (ever) high resolution, crosswell reflection images of SJV sediments; (2) first successful application of the TomoSeis acquisition system in siliceous shales; (3) first detailed reservoir characterization of SJV siliceous shales; (4) first mineral based saturation algorithm for SJV siliceous shales, and (5) first CO{sub 2} coreflood experiments for siliceous shale. Preliminary results from the CO{sub 2} coreflood experiments (2,500 psi) suggest that significant oil is being produced from the siliceous shale.

  16. Oil/gas collector/separator for underwater oil leaks

    DOE Patents [OSTI]

    Henning, Carl D. (Livermore, CA)

    1993-01-01

    An oil/gas collector/separator for recovery of oil leaking, for example, from an offshore or underwater oil well. The separator is floated over the point of the leak and tethered in place so as to receive oil/gas floating, or forced under pressure, toward the water surface from either a broken or leaking oil well casing, line, or sunken ship. The separator is provided with a downwardly extending skirt to contain the oil/gas which floats or is forced upward into a dome wherein the gas is separated from the oil/water, with the gas being flared (burned) at the top of the dome, and the oil is separated from water and pumped to a point of use. Since the density of oil is less than that of water it can be easily separated from any water entering the dome.

  17. An Evaluation of the Feasibility of Combining Carbon Dioxide Flooding Technologies with Microbial Enhanced Oil Recovery Technologies in Order To Sequester Carbon Dioxide

    SciTech Connect (OSTI)

    Todd French; Lew Brown; Rafael Hernandez; Magan Green; Lynn Prewitt; Terry Coggins

    2009-08-19

    The need for more energy as our population grows results in an increase in the amount of CO2 introduced into the atmosphere. The effect of this introduction is currently debated intensely as to the severity of the effect of this. The bjective of this investigation was to determine if the production of more energy (i.e. petroleum) and the sequestration of CO2 could be coupled into one process. Carbon dioxide flooding is a well-established technique that introduces Compressed CO2 into a subsurface oil-bearing formation to aide in liquefying harder to extract petroleum and enhancing its mobility towards the production wells.

  18. Quantifying the Uncertainty in Estimates of World Conventional Oil Resources 

    E-Print Network [OSTI]

    Tien, Chih-Ming

    2010-07-14

    Since Hubbert proposed the "peak oil" concept to forecast ultimate recovery of crude oil for the U.S. and the world, there have been countless debates over the timing of peak world conventional oil production rate and ultimate recovery. From review...

  19. Recovery of bypassed oil in the Dundee Formation using horizontal drains, Quarterly technical report, 1/1/97--3/31/97

    SciTech Connect (OSTI)

    1997-03-30

    This Class 11 field project has demonstrated that economic quantities of hydrocarbons can be produced from abandoned or nearly abandoned fields in the Dundee Formation of Central Michigan using horizontal drilling technology. The site selected for the demonstration horizontal well was Crystal Field, a nearly abandoned Dundee oil field in Montcalm County, Michigan. This field had produced over 8 million barrels of oil, mostly in the 1930`s and 1940`s. At the height of development, Crystal Field produced from 193 wells, but by 1995, only seven producing wells remained, each producing less than 10 bbls/day. A horizontal well, the TOW 1-3, drilled as a field demonstration pilot was successful, producing at rate of 100 bbls of oil per day with a zero water cut. Although the well is capable of producing at a rate of 500+ bbls/day, the production rate is being kept low deliberately to try to prevent premature water coning. Cumulative production exceeded 50,000 bbls of oil by the end of April, 1997 and lead to the permitting and licensing of several dozen Dundee wells by project end. Twelve of these permits were for continued development of Crystal Field. Two subsequent wells, the Frost 5-3 and the Happy Holidays 6-3, have not been as successful. Both are currently producing 10 BOPD with 90% water cut. Efforts are underway to determine why these wells are performing so poorly and to see if the situation can be remedied. The reasons for these poor performances of the new wells are not clear at this time. It is possible that the wells entered the Dundee too low and missed pay higher in the section. When the TOW 1-3 was drilled, a vertical probe well was also drilled and cored. That probe well penetrated the pay zone and helped guide the horizontal well. The important lesson may be that vertical probe wells are a crucial step in producing these old fields and should not be eliminated simply to save what amounts to a small incremental cost. Core and logs from the Dundee interval were recovered from a vertical borehole at the same surface location. The addition of several horizontal wells will likely add another 2 million bbls (or more) to the cumulative production of the field over the next few years. If other abandoned Dundee fields are re-developed in a similar manner, the additional oil produced could exceed 80 million barrels. Additional project work involved the characterization of 28 other Dundee fields in Michigan to aid in determining appropriate additional candidates for development through horizontal drilling. Further quantification of reservoir parameters such as importance of fracturing, fracture density, and irregularity of the dolomitized surface at the top of the reservoir will help in designing the optimal strategy for horizontal drilling. The project was a cooperative venture involving the US Department of Energy, Michigan Technological University (MTU), Western Michigan University (WMU), and Terra Energy (now Cronus Development Co.) in Traverse City, MI.

  20. Advanced Reservoir Characterization in the Antelope Shale to Establish the Viability of CO{sub 2} Enhanced Oil Recovery in California's Monterey Formation Siliceous Shales

    SciTech Connect (OSTI)

    Michael F. Morea

    1997-03-14

    The Buena Vista Hills field is located about 25 miles southwest of Bakersfield, in Kern County, California, about two miles north of the city of Taft, and five miles south of the Elk Hills field. The Antelope Shale zone was discovered at the Buena Vista Hills field in 1952, and has since been under primary production. Little research was done to improve the completion techniques during the development phase in the 1950s, so most of the wells are completed with about 1000 ft of slotted liner. The proposed pilot consists of four existing producers on 20 acre spacing with a new 10 acre infill well drilled as the pilot CO{sub 2} injector. Most of the reservoir characterization of the first phase of the project will be performed using data collected in the pilot pattern wells. This is the first annual report of the project. It covers the period February 12, 1996 to February 11, 1997. During this period the Chevron Murvale 653Z-26B well was drilled in Section 26-T31S/R23E in the Buena Vista Hills field, Kern County, California. The Monterey Formation equivalent Brown and Antelope Shales were continuously cored, the zone was logged with several different kinds of wireline logs, and the well was cased to a total depth of 4907 ft. Core recovery was 99.5%. Core analyses that have been performed include Dean Stark porosity, permeability and fluid saturations, field wettability, anelastic strain recovery, spectral core gamma, profile permeametry, and photographic imaging. Wireline log analysis includes mineral-based error minimization (ELAN), NMR T2 processing, and dipole shear wave anisotropy. A shear wave vertical seismic profile was acquired after casing was set and processing is nearly complete.

  1. Improved Hydrogen Utilization and Carbon Recovery for Higher Efficiency Thermochemical Bio-oil Pathways Presentation for BETO 2015 Project Peer Review

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE:FinancingPetroleum12,ExecutiveFinancingREnergy ToolsCoordination

  2. 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. Annual report, January 1, 1996--December 30, 1996

    SciTech Connect (OSTI)

    Brown, L.R.; Vadie, A.A.

    1997-08-01

    This project is a field demonstration of the ability of in-situ indigenous microorganisms in the North Blowhorn Creek Oil Field to reduce the flow of injection water in the more permeable zones thereby diverting flow to other areas of the reservoir and thus increase the efficiency of the waterflooding operation. This effect is to be accomplished by adding microbial nutrients to the injection water. Work on the project is divided into three phases, Planning and Analysis (9 months), Implementation (45 months), and Technology Transfer (12 months). This report covers the third year of work on the project. During Phase I, two wells were drilled in an area of the field where approximately twenty feet of Carter sand were found and appeared to contain oil bypassed by the existing waterflood. Cores from one well were obtained and used in laboratory core flood experiments. The schedule and amounts of nutrients to be employed in the field were formulated on the basis of the results from laboratory core flood experiments.

  3. Recovery Act

    Broader source: Energy.gov [DOE]

    Recovery Act and Energy Department programs were designed to stimulate the economy while creating new power sources, conserving resources and aligning the nation to once again lead the global energy economy.

  4. The Wicked Problem of Oil & Gas Development in the Beaufort and Chukchi Seas: Current Permitting and Evaluation of Marine Spatial Planning as a Potential Management Tool 

    E-Print Network [OSTI]

    Johannes, Emilie Ann

    2014-06-02

    Changing climatic conditions and shifting global economics have thrust the Arctic into the spotlight for many scientists, academics, and policymakers as well as those in offshore industries, particularly in shipping and oil and gas. This research...

  5. Development of Next Generation Multiphase Pipe Flow Prediction Tools

    SciTech Connect (OSTI)

    Cem Sarica; Holden Zhang

    2006-05-31

    The developments of oil and gas fields in deep waters (5000 ft and more) will become more common in the future. It is inevitable that production systems will operate under multiphase flow conditions (simultaneous flow of gas, oil and water possibly along with sand, hydrates, and waxes). Multiphase flow prediction tools are essential for every phase of hydrocarbon recovery from design to operation. Recovery from deep-waters poses special challenges and requires accurate multiphase flow predictive tools for several applications, including the design and diagnostics of the production systems, separation of phases in horizontal wells, and multiphase separation (topside, seabed or bottom-hole). It is crucial for any multiphase separation technique, either at topside, seabed or bottom-hole, to know inlet conditions such as flow rates, flow patterns, and volume fractions of gas, oil and water coming into the separation devices. Therefore, the development of a new generation of multiphase flow predictive tools is needed. The overall objective of the proposed study is to develop a unified model for gas-oil-water three-phase flow in wells, flow lines, and pipelines to predict flow characteristics such as flow patterns, phase distributions, and pressure gradient encountered during petroleum production at different flow conditions (pipe diameter and inclination, fluid properties and flow rates). In the current multiphase modeling approach, flow pattern and flow behavior (pressure gradient and phase fractions) prediction modeling are separated. Thus, different models based on different physics are employed, causing inaccuracies and discontinuities. Moreover, oil and water are treated as a pseudo single phase, ignoring the distinct characteristics of both oil and water, and often resulting in inaccurate design that leads to operational problems. In this study, a new model is being developed through a theoretical and experimental study employing a revolutionary approach. The basic continuity and momentum equations is established for each phase, and used for both flow pattern and flow behavior predictions. The required closure relationships are being developed, and will be verified with experimental results. Gas-oil-water experimental studies are currently underway for the horizontal pipes. Industry-driven consortia provide a cost-efficient vehicle for developing, transferring, and deploying new technologies into the private sector. The Tulsa University Fluid Flow Projects (TUFFP) is one of the earliest cooperative industry-university research consortia. TUFFP's mission is to conduct basic and applied multiphase flow research addressing the current and future needs of hydrocarbon production and transportation. TUFFP participants and The University of Tulsa are supporting this study through 55% cost sharing.

  6. ADVANCED RESERVOIR CHARACTERIZATION IN THE ANTELOPE SHALE TO ESTABLISH THE VIABILITY OF CO2 ENHANCED OIL RECOVERY IN CALIFORNIA'S MONTEREY FORMATION SILICEOUS SHALES

    SciTech Connect (OSTI)

    Pasquale R. Perri

    2003-05-15

    This report describes the evaluation, design, and implementation of a DOE funded CO{sub 2} pilot project in the Lost Hills Field, Kern County, California. The pilot consists of four inverted (injector-centered) 5-spot patterns covering approximately 10 acres, and is located in a portion of the field, which has been under waterflood since early 1992. The target reservoir for the CO{sub 2} pilot is the Belridge Diatomite. The pilot location was selected based on geologic considerations, reservoir quality and reservoir performance during the waterflood. A CO{sub 2} pilot was chosen, rather than full-field implementation, to investigate uncertainties associated with CO{sub 2} utilization rate and premature CO{sub 2} breakthrough, and overall uncertainty in the unproven CO{sub 2} flood process in the San Joaquin Valley. A summary of the design and objectives of the CO{sub 2} pilot are included along with an overview of the Lost Hills geology, discussion of pilot injection and production facilities, and discussion of new wells drilled and remedial work completed prior to commencing injection. Actual CO{sub 2} injection began on August 31, 2000 and a comprehensive pilot monitoring and surveillance program has been implemented. Since the initiation of CO{sub 2} injection, the pilot has been hampered by excessive sand production in the pilot producers due to casing damage related to subsidence and exacerbated by the injected CO{sub 2}. Therefore CO{sub 2} injection was very sporadic in 2001 and 2002 and we experienced long periods of time with no CO{sub 2} injection. As a result of the continued mechanical problems, the pilot project was terminated on January 30, 2003. This report summarizes the injection and production performance and the monitoring results through December 31, 2002 including oil geochemistry, CO{sub 2} injection tracers, crosswell electromagnetic surveys, crosswell seismic, CO{sub 2} injection profiling, cased hole resistivity, tiltmetering results, and corrosion monitoring results. Although the Lost Hills CO{sub 2} pilot was not successful, the results and lessons learned presented in this report may be applicable to evaluate and design other potential San Joaquin Valley CO{sub 2} floods.

  7. Shale Oil Production Performance from a Stimulated Reservoir Volume 

    E-Print Network [OSTI]

    Chaudhary, Anish Singh

    2011-10-21

    RF Recovery factor at 30 years, percent So Oil saturation, fraction Sorg Residual oil saturation at connate gas saturation, fraction Sgc Critical gas saturation, fraction Sw Water saturation, fraction viii SRV Stimulated reservoir volume PVT.................... 24 Table 3: PVT properties of oil used for Eagle Ford oil window well setup .................... 24 Table 4: Relative permeability end points for fracture and matrix.................................. 25...

  8. Economic recovery of oil trapped at fan margins using high angle wells and multiple hydraulic fractures. Quarterly report, October 1--December 31, 1996

    SciTech Connect (OSTI)

    Laue, M.L.

    1997-02-13

    This project attempts to demonstrate the effectiveness of exploiting thin-layered, low-energy deposits at the distal margin of a prograding turbidite complex through the use of hydraulically- fractured horizontal or high-angle wells. The combination of a horizontal or high-angle well and hydraulic fracturing will allow greater pay exposure than can be achieved with conventional vertical wells while maintaining vertical communication between thin interbedded layers and the wellbore. A high-angle well will be drilled in the fan-margin portion of a slope-basin clastic reservoir and will be completed with multiple hydraulic-fracture treatments. Geologic modeling, reservoir characterization, and fine-grid reservoir simulation will be used to select the well location and orientation. Design parameters for the hydraulic-fracture treatments will be determined, in part, by fracturing an existing test well. Fracture azimuth will be predicted by passive seismic monitoring of a fracture-stimulation treatment in the test well using logging tools in an offset well. The Unites States Department of Energy granted approval of the continuation application to implement Budget Period Two effective November 21, 1996. The only Budget Period One activities for the quarter involved project administration. Budget Period Two activities were initiated with the development of a drilling program for the high-angle slant well. The well was spud on December 4, 1996 and was drilling at 10,830 ft in the vertical section of the hole as of the end of the month.

  9. Power Recovery 

    E-Print Network [OSTI]

    Murray, F.

    1986-01-01

    , will be the use of the ASTM Theoretical Steam Rate Tables. In addition, the author's experience regarding the minimum size for power recovery units that are economic in a Culf Coast plant will be presented. INTROD\\Jr.'rION When surveying an operation...)' The pressure ~ecompression term(~2) k~l, is used in the equat10n in a manner 1 which reduces the power recovery as calculated by the first term of the equation. From a practical view a decompression ra~~y ~0.3 is a good screening point. Note...

  10. Process for oil shale retorting

    DOE Patents [OSTI]

    Jones, John B. (300 Enterprise Bldg., Grand Junction, CO 80501); Kunchal, S. Kumar (300 Enterprise Bldg., Grand Junction, CO 80501)

    1981-10-27

    Particulate oil shale is subjected to a pyrolysis with a hot, non-oxygenous gas in a pyrolysis vessel, with the products of the pyrolysis of the shale contained kerogen being withdrawn as an entrained mist of shale oil droplets in a gas for a separation of the liquid from the gas. Hot retorted shale withdrawn from the pyrolysis vessel is treated in a separate container with an oxygenous gas so as to provide combustion of residual carbon retained on the shale, producing a high temperature gas for the production of some steam and for heating the non-oxygenous gas used in the oil shale retorting process in the first vessel. The net energy recovery includes essentially complete recovery of the organic hydrocarbon material in the oil shale as a liquid shale oil, a high BTU gas, and high temperature steam.

  11. Economic recovery of oil trapped at fan margins using high angle wells and multiple hydraulic fractures. Quarterly report, Apr 1--June 30, 1997

    SciTech Connect (OSTI)

    Laue, M.L.

    1997-08-31

    This project attempts to demonstrate the effectiveness of exploiting thin-layered, low-energy deposits at the distal margin of a prograding turbidite complex through the use of hydraulically-fractured horizontal or high-angle wells. The combination of a horizontal or high-angle well and hydraulic fracturing will allow greater pay exposure than can be achieved with conventional vertical wells while maintaining vertical communication between thin interbedded layers and the wellbore. A high-angle well will be drilled in the fan-margin portion of a slope-basin clastic reservoir and will be completed with multiple hydraulic-fracture treatments. Geologic modeling, reservoir characterization, and fine-grid reservoir simulation will be used to select the well location and orientation. Design parameters for the hydraulic-fracture treatments will be determined, in part, by fracturing an existing test well. Fracture azimuth will be predicted by passive seismic monitoring of a fracture-stimulation treatment in the test well using logging tools in an offset well. The long radius, near-horizontal well has been drilled and completion operations are in progress. Upon initial review of log data, two hydraulic fracture treatments were planned. However, the probability of the lower frac growing into thick sands previously swept by waterflood has called for additional information to be obtained prior to proceeding with hydraulic fracture treatments. Should permeabilities prove to be as favorable as some data indicate, produced water volumes could be excessively high. Prior to pumping the first frac, the well will be perforated and produced from lower pay intervals. These perfs will not impact future frac work. Rate data and pressure transient analysis will dictate the need for the lower frac.

  12. Forced oil-water displacement and spontaneous countercurrent imbibition are the crucial mechanisms of secondary oil

    E-Print Network [OSTI]

    Patzek, Tadeusz W.

    Abstract Forced oil-water displacement and spontaneous countercurrent imbibition are the crucial mechanisms of secondary oil recovery. Classical mathematical models of both these unsteady flows are based on the fundamental assumption of local phase equilibrium. Thus, the water and oil flows are locally redistributed

  13. Shell boosts recovery at Kernridge

    SciTech Connect (OSTI)

    Moore, S.

    1984-01-01

    Since acquiring the Kernridge property in December 1979, Shell Oil Co. has drilled more than 1,800 wells and steadily increased production from 42,000 to 89,000 b/d of oil. Currently, the Kernridge Production Division of Shell California Production Inc. (SCPI), a newly formed subsidiary of Shell Oil Co., is operator for the property. The property covers approximately 35,000 mostly contiguous net acres, with production concentrated mainly on about 5,500 net acres. SCPI's four major fields in the area are the North and South Belridge, Lost Hills, and Antelope Hills. Most of the production comes from the North and South Belridge fields, which were previously held by the Belridge Oil Co. Productive horizons in the fields are the Tulare, Diatomite, Brown Shale, Antelope Shale, 64 Zone, and Agua sand. The Tulare and Diatomite are the two major reservoirs SCPI is developing. The Tulare, encountered between 400 and 1,300 ft, is made up of fine- to coarse-grained, unconsolidated sands with interbedded shales and silt stones and contains 13 /sup 0/ API oil. Using steam drive as the main recovery method, SCPI estimates an ultimate recovery from the Tulare formation of about 60% of the original 1 billion barrels in place. The Diatomite horizon, found between 800 and 3,500 ft and containing light, 28 /sup 0/ API oil, has high porosity (more than 60%), low permeability (less than 1 md), and natural fractures. Because of the Diatomite's low permeability, fracture stimulation is being used to increase well productivity. SCPI anticipates that approximately 5% of the almost 2 billion barrels of oil originally in place will be recovered by primary production.

  14. Advanced Computer Control Concepts Facilitate Energy Recovery 

    E-Print Network [OSTI]

    Cutler, C. R.

    1981-01-01

    A process computer is a powerful tool for maximizing the use of energy and raw materials. Advanced computer control techniques are evolving which facilitate the recovery of energy by predictive control techniques. One such technique is Dynamic...

  15. Robust phase sensitive inversion recovery imaging 

    E-Print Network [OSTI]

    Garach, Ravindra Mahendrakumar

    2005-11-01

    Imaging. (August 2005) Garach, Ravindra Mahendrakumar, B.E., Gujarat University Chair of Advisory Committee: Dr. Jim Ji Inversion Recovery (IR) is a powerful tool for contrast manipulation in Mag- netic Resonance Imaging (MRI). IR can provide strong...

  16. The effect on recovery of the injection of alternating slugs of gas and water at pressures above the bubble point 

    E-Print Network [OSTI]

    Givens, James Wilson

    1961-01-01

    . CONCLUSIONS, 24 6. ACKNOWLEDGEMENT. 7. APPE NDIX. 8. REFERENCES. 25 32 337530 LIST OF FIGURES AND TABLES FIGURES 1. Core Saturating and Flooding Apparatus Page 2. Physical Characteristics of Refined Oil and East Texas Crude Oil at 77'F. 3. Refined... Oil Recovery vs Pore Volumes of Injected Fluid for an Initial Gas Slug. 13 4, Refined Oil Recovery vs Pore Volumes of Injected Fluid for an Initial Water Slug. 14 5. The Effect of Slug Length on Recovery of Refined Oil. 15 6. Recovery of East...

  17. DEVELOPMENT OF SHALLOW VISCOUS OIL RESERVES IN NORTH SLOPE

    SciTech Connect (OSTI)

    Kishore K. Mohanty

    2003-07-01

    North Slope of Alaska has huge oil deposits in heavy oil reservoirs such as Ugnu, West Sak and Shrader Bluff etc. The viscosity of the last two reservoir oils vary from {approx}30 cp to {approx}3000 cp and the amount in the range of 10-20 billion barrels. High oil viscosity and low formation strength impose problems to high recovery and well productivity. Water-alternate-gas injection processes can be effective for the lower viscosity end of these deposits in West Sak and Shrader Bluff. Several gas streams are available in the North Slope containing NGL and CO{sub 2} (a greenhouse gas). The goal of this research is to develop tools to find optimum solvent, injection schedule and well-architecture for a WAG process in North Slope shallow sand viscous oil reservoirs. In the last quarter, we have developed streamline generation and convection subroutines for miscible gas injection. The WAG injection algorithms are being developed. We formulated a four-phase relative permeability model based on two-phase relative permeabilities. The new relative permeability formulations are being incorporated into the simulator. Wettabilities and relative permeabilities are being measured. Plans for the next quarter includes modeling of WAG injection in streamline based simulation, relative permeability studies with cores, incorporation of complex well-architecture.

  18. REHABILITATION AND RECOVERY Rehabillitation and Recovery Following

    E-Print Network [OSTI]

    MacDonald, Lee

    REHABILITATION AND RECOVERY Rehabillitation and Recovery Following Wildfires: A Synthesis1 Lee H rehabilitation techniques applied in the Sierra Nevada, northern California, and southwestern Oregon objectives; and {5) recommend appropriate rehabilitation and recovery measures. Wildfires traditionally have

  19. Bridging the Gap between Chemical Flooding and Independent Oil Producers

    SciTech Connect (OSTI)

    Stan McCool; Tony Walton; Paul Willhite; Mark Ballard; Miguel Rondon; Kaixu Song; Zhijun Liu; Shahab Ahmend; Peter Senior

    2012-03-31

    Ten Kanas oil reservoirs/leases were studied through geological and engineering analysis to assess the potential performance of chemical flooding to recover oil. Reservoirs/leases that have been efficiently waterflooded have the highest performance potential for chemical flooding. Laboratory work to identify efficient chemical systems and to test the oil recovery performance of the systems was the major effort of the project. Efficient chemical systems were identified for crude oils from nine of the reservoirs/leases. Oil recovery performance of the identified chemical systems in Berea sandstone rocks showed 90+ % recoveries of waterflood residual oil for seven crude oils. Oil recoveries increased with the amount of chemical injected. Recoveries were less in Indiana limestone cores. One formulation recovered 80% of the tertiary oil in the limestone rock. Geological studies for nine of the oil reservoirs are presented. Pleasant Prairie, Trembley, Vinland and Stewart Oilfields in Kansas were the most favorable of the studied reservoirs for a pilot chemical flood from geological considerations. Computer simulations of the performance of a laboratory coreflood were used to predict a field application of chemical flooding for the Trembley Oilfield. Estimates of field applications indicated chemical flooding is an economically viable technology for oil recovery.

  20. Models and Tools | Argonne National Laboratory

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

    need tools that can help them assess potential energy use, oil use and carbon emission impacts of advanced light- and heavy-duty transportation technologies and alternative...

  1. Oil & Gas Research | netl.doe.gov

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

    Oil & Gas Research Unconventional Resources NETL's onsite research in unconventional resources is focused on developing the data and modeling tools needed to predict and quantify...

  2. Sixty-sixth annual report of the state oil and gas supervisor

    SciTech Connect (OSTI)

    Not Available

    1981-01-01

    This report contains tabulated oil and gas statistics compiled during 1980 in California. On-shore and off-shore oil production, gas production, reserves, drilling activity, enhanced recovery activity, unconventional heavy oil recovery, geothermal operations and financial data are reported. (DMC)

  3. Optimize carbon dioxide sequestration, enhance oil recovery

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

    Rod Borup Borup wins Electrochemical Society Award January, 26 2015 - Rod Borup has won the 2015 Research Award presented annually by the Energy Technology Division of the...

  4. Seismic stimulation for enhanced oil recovery

    E-Print Network [OSTI]

    Pride, S.R.

    2008-01-01

    M. , and Z. Wang, 1992, Seismic properties of pore ?uids:2005, Relationships between seismic and hydrological proper-by d/dt ? ? / ? t ? u · ?. Seismic stimulation Biot, M. A. ,

  5. Optimize carbon dioxide sequestration, enhance oil recovery

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantityBonneville Power Administration wouldMass mapSpeeding access toOctober 1996TechnologiesDistribution, andSpectroscopy of

  6. Enhanced Oil Recovery | Department of Energy

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE:FinancingPetroleum12, 2015 Infographiclighbulbs - high-resolution2 DOEHighEnhancedMaterialsEnhanced

  7. Optimize carbon dioxide sequestration, enhance oil recovery

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity ofkandz-cm11 Outreach Home Room NewsInformationJesseworkSURVEYI/O Streams for Large-scale Scientific Simulations |

  8. Managing Manure with Biogas Recovery Systems

    E-Print Network [OSTI]

    Mukhtar, Saqib

    such as natural gas, propane, and fuel oil. Biogas can also be flared to control odor if energy recovery source of energy with much lower environmental impacts than conventional fossil fuel. The methane States Environmental Protection Agency The AgSTAR Program #12;Office of Air and Radiation (6202J) EPA-430

  9. Development of Next Generation Multiphase Pipe Flow Prediction Tools

    SciTech Connect (OSTI)

    Tulsa Fluid Flow

    2008-08-31

    The developments of fields in deep waters (5000 ft and more) is a common occurrence. It is inevitable that production systems will operate under multiphase flow conditions (simultaneous flow of gas-oil-and water possibly along with sand, hydrates, and waxes). Multiphase flow prediction tools are essential for every phase of the hydrocarbon recovery from design to operation. The recovery from deep-waters poses special challenges and requires accurate multiphase flow predictive tools for several applications including the design and diagnostics of the production systems, separation of phases in horizontal wells, and multiphase separation (topside, seabed or bottom-hole). It is very crucial to any multiphase separation technique that is employed either at topside, seabed or bottom-hole to know inlet conditions such as the flow rates, flow patterns, and volume fractions of gas, oil and water coming into the separation devices. The overall objective was to develop a unified model for gas-oil-water three-phase flow in wells, flow lines, and pipelines to predict the flow characteristics such as flow patterns, phase distributions, and pressure gradient encountered during petroleum production at different flow conditions (pipe diameter and inclination, fluid properties and flow rates). The project was conducted in two periods. In Period 1 (four years), gas-oil-water flow in pipes were investigated to understand the fundamental physical mechanisms describing the interaction between the gas-oil-water phases under flowing conditions, and a unified model was developed utilizing a novel modeling approach. A gas-oil-water pipe flow database including field and laboratory data was formed in Period 2 (one year). The database was utilized in model performance demonstration. Period 1 primarily consisted of the development of a unified model and software to predict the gas-oil-water flow, and experimental studies of the gas-oil-water project, including flow behavior description and closure relation development for different flow conditions. Modeling studies were performed in two parts, Technology Assessment and Model Development and Enhancement. The results of the Technology assessment study indicated that the performance of the current state of the art two-phase flow models was poor especially for three-phase pipeline flow when compared with the existing data. As part of the model development and enhancement study, a new unified model for gas-oil-water three-phase pipe flow was developed. The new model is based on the dynamics of slug flow, which shares transition boundaries with all the other flow patterns. The equations of slug flow are used not only to calculate the slug characteristics, but also to predict transitions from slug flow to other flow patterns. An experimental program including three-phase gas-oil-water horizontal flow and two-phase horizontal and inclined oil-water flow testing was conducted utilizing a Tulsa University Fluid Flow Projects Three-phase Flow Facility. The experimental results were incorporated into the unified model as they became available, and model results were used to better focus and tailor the experimental study. Finally, during the Period 2, a new three-phase databank has been developed using the data generated during this project and additional data available in the literature. The unified model to predict the gas-oil-water three phase flow characteristics was tested by comparing the prediction results with the data. The results showed good agreements.

  10. Method for reclaiming waste lubricating oils

    DOE Patents [OSTI]

    Whisman, Marvin L. (Bartlesville, OK); Goetzinger, John W. (Bartlesville, OK); Cotton, Faye O. (Bartlesville, OK)

    1978-01-01

    A method for purifying and reclaiming used lubricating oils containing additives such as detergents, antioxidants, corrosion inhibitors, extreme pressure agents and the like and other solid and liquid contaminants by preferably first vacuum distilling the used oil to remove water and low-boiling contaminants, and treating the dried oil with a solvent mixture of butanol, isopropanol and methylethyl ketone which causes the separation of a layer of sludge containing contaminants, unspent additives and oxidation products. After solvent recovery, the desludged oil is then subjected to conventional lubricating oil refining steps such as distillation followed by decolorization and deodorization.

  11. Effect of wettability on light oil steamflooding

    SciTech Connect (OSTI)

    Olsen, D.K.

    1991-12-01

    This report summarizes NIPER`s research on four interrelated topics for Light Oil Steamflooding. Four interrelated topics are described: The methodology for measuring capillary pressure and wettability at elevated temperature, the use of silylating agents to convert water-wet Berea sandstones or unconsolidated quartz sands to oil-wetted surfaces, the evaluation of the thermal hydrolytic stability of these oil-wet surfaces for possible use in laboratory studies using steam and hot water to recover oil, and the effect of porous media of different wettabilities on oil recovery where the porous media is first waterflooded and then steamflooded.

  12. Effect of wettability on light oil steamflooding

    SciTech Connect (OSTI)

    Olsen, D.K.

    1991-12-01

    This report summarizes NIPER's research on four interrelated topics for Light Oil Steamflooding. Four interrelated topics are described: The methodology for measuring capillary pressure and wettability at elevated temperature, the use of silylating agents to convert water-wet Berea sandstones or unconsolidated quartz sands to oil-wetted surfaces, the evaluation of the thermal hydrolytic stability of these oil-wet surfaces for possible use in laboratory studies using steam and hot water to recover oil, and the effect of porous media of different wettabilities on oil recovery where the porous media is first waterflooded and then steamflooded.

  13. System and method for preparing near-surface heavy oil for extraction using microbial degradation

    SciTech Connect (OSTI)

    Busche, Frederick D.; Rollins, John B.; Noyes, Harold J.; Bush, James G.

    2011-04-12

    A system and method for enhancing the recovery of heavy oil in an oil extraction environment by feeding nutrients to a preferred microbial species (bacteria and/or fungi). A method is described that includes the steps of: sampling and identifying microbial species that reside in the oil extraction environment; collecting fluid property data from the oil extraction environment; collecting nutrient data from the oil extraction environment; identifying a preferred microbial species from the oil extraction environment that can transform the heavy oil into a lighter oil; identifying a nutrient from the oil extraction environment that promotes a proliferation of the preferred microbial species; and introducing the nutrient into the oil extraction environment.

  14. FINGERPRINTING INORGANIC ARSENIC AND ORGANOARSENIC COMPOUNDS IN IN SITU OIL SHALE RETORT AND PROCESS VOTERS USING A LIQUID CHROMATOGRAPH COUPLED WITH AN ATOMIC ABSORPTION SPECTROMETER AS A DETECTOR

    E-Print Network [OSTI]

    Fish, Richard H.

    2013-01-01

    Process for Recovery of Oil Shale, Nov. 1976-0ct. 1977,M. A. , Proc. 12th Oil Shale Sympos. , Colorado School ofChilingarian, G. Ve, Eds; Oil Shale, Elsevier Scientific

  15. FINGERPRINTING INORGANIC ARSENIC AND ORGANOARSENIC COMPOUNDS IN IN SITU OIL SHALE RETORT AND PROCESS VOTERS USING A LIQUID CHROMATOGRAPH COUPLED WITH AN ATOMIC ABSORPTION SPECTROMETER AS A DETECTOR

    E-Print Network [OSTI]

    Fish, Richard H.

    2013-01-01

    Process for Recovery of Oil Shale, Nov. 1976-0ct. 1977,M. A. , Proc. 12th Oil Shale Sympos. , Colorado School ofCOMPOUNDS IN IN SITU OIL SHALE RETORT ~~D PROCESS WATERS

  16. China's Global Oil Strategy

    E-Print Network [OSTI]

    Thomas, Bryan G

    2009-01-01

    growth. For data on world oil consumption and long- term oilOil Production Domestic Oil Consumption a variety of

  17. Recovery Act State Memos Tennessee

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE:Financing Tool FitsProject Developsfor UCNIEnvironmental Impact StatementRecovery Act Smart

  18. 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)

    Schamel, S.

    1996-06-28

    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.

  19. Fuel Oil",,,"Fuel Oil Consumption",,"Fuel Oil Expenditures"

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

    1. Total Fuel Oil Consumption and Expenditures, 1999" ,"All Buildings Using Fuel Oil",,,"Fuel Oil Consumption",,"Fuel Oil Expenditures" ,"Number of Buildings (thousand)","Floorspac...

  20. Oil shale, tar sands, and related materials

    SciTech Connect (OSTI)

    Stauffer, H.C.

    1981-01-01

    This sixteen-chapter book focuses on the many problems and the new methodology associated with the commercialization of the oil shale and tar sand industry. Topics discussed include: an overview of the Department of Energy's oil shale R, D, and D program; computer simulation of explosive fracture of oil shale; fracturing of oil shale by treatment with liquid sulfur dioxide; chemistry of shale oil cracking; hydrogen sulfide evolution from Colorado oil shale; a possible mechanism of alkene/alkane production in oil shale retorting; oil shale retorting kinetics; kinetics of oil shale char gasification; a comparison of asphaltenes from naturally occurring shale bitumen and retorted shale oils: the influence of temperature on asphaltene structure; beneficiation of Green River oil shale by density methods; beneficiation of Green River oil shale pelletization; shell pellet heat exchange retorting: the SPHER energy-efficient process for retorting oil shale; retorted oil shale disposal research; an investigation into the potential economics of large-scale shale oil production; commercial scale refining of Paraho crude shale oil into military specification fuels; relation between fuel properties and chemical composition; chemical characterization/physical properties of US Navy shale-II fuels; relation between fuel properties and chemical composition: stability of oil shale-derived jet fuel; pyrolysis of shale oil residual fractions; synfuel stability: degradation mechanisms and actual findings; the chemistry of shale oil and its refined products; the reactivity of Cold Lake asphaltenes; influence of thermal processing on the properties of Cold Lake asphaltenes: the effect of distillation; thermal recovery of oil from tar sands by an energy-efficient process; and hydropyrolysis: the potential for primary upgrading of tar sand bitumen.

  1. Effects of petroleum resins on asphaltene aggregation and water-in-oil emulsion formation

    E-Print Network [OSTI]

    Kilpatrick, Peter K.

    Effects of petroleum resins on asphaltene aggregation and water-in-oil emulsion formation P 1. Introduction Emulsion challenges during petroleum recovery have been attributed to colloidal

  2. WATER QUALITY EFFECTS OF LEACHATES FROM AN IN SITU OIL SHALE INDUSTRY

    E-Print Network [OSTI]

    Fox, J. P.

    2011-01-01

    on the other oil-shale related solid wastes. This tsbulationPiles Solid wastes from the shale-oil recovery process alsooil shale, and other mine spoils and solids from water and waste-

  3. Opportunities to improve oil productivity in unstructured deltaic reservoirs

    SciTech Connect (OSTI)

    Not Available

    1991-01-01

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

  4. 2. INVESTIGATION OF CRUDE OIL/BRINE/ROCK INTERACTION 2.1 STUDY OF WATERFLOODING PROCESS IN NATURALLY FRACTURED

    E-Print Network [OSTI]

    Schechter, David S.

    - 31 - 2. INVESTIGATION OF CRUDE OIL/BRINE/ROCK INTERACTION 2.1 STUDY OF WATERFLOODING PROCESS plays an important role in oil recovery from the naturally fractured Spraberry Trend Area. Therefore are important. We examined these issues by performing static and dynamic imbibition experiments. Oil recoveries

  5. 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)

    Scott Hara

    2007-03-31

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

  6. Robust Optimization of Oil Reservoir Flooding G.M. van Essen, M.J. Zandvliet,

    E-Print Network [OSTI]

    Van den Hof, Paul

    Robust Optimization of Oil Reservoir Flooding G.M. van Essen, M.J. Zandvliet, P.M.J. Van den Hof developments have been introduced within the field of oil recovery, with the aim to maximize production of oil wells", which are equipped with control valves to actively control the oil production. The optimal

  7. Dual gas and oil dispersions in water: production and stability of foamulsion Anniina Salonen,*a

    E-Print Network [OSTI]

    Paris-Sud XI, Université de

    Dual gas and oil dispersions in water: production and stability of foamulsion Anniina Salonen cosmetic and food products (such as whipped cream) or in oil recovery processes. Depending on the a of oil droplets and gas bubbles and show that the oil can have two very different roles, either

  8. Identification, Verification, and Compilation of Produced Water Management Practices for Conventional Oil and Gas Production Operations

    SciTech Connect (OSTI)

    Rachel Henderson

    2007-09-30

    The project is titled 'Identification, Verification, and Compilation of Produced Water Management Practices for Conventional Oil and Gas Production Operations'. The Interstate Oil and Gas Compact Commission (IOGCC), headquartered in Oklahoma City, Oklahoma, is the principal investigator and the IOGCC has partnered with ALL Consulting, Inc., headquartered in Tulsa, Oklahoma, in this project. State agencies that also have partnered in the project are the Wyoming Oil and Gas Conservation Commission, the Montana Board of Oil and Gas Conservation, the Kansas Oil and Gas Conservation Division, the Oklahoma Oil and Gas Conservation Division and the Alaska Oil and Gas Conservation Commission. The objective is to characterize produced water quality and management practices for the handling, treating, and disposing of produced water from conventional oil and gas operations throughout the industry nationwide. Water produced from these operations varies greatly in quality and quantity and is often the single largest barrier to the economic viability of wells. The lack of data, coupled with renewed emphasis on domestic oil and gas development, has prompted many experts to speculate that the number of wells drilled over the next 20 years will approach 3 million, or near the number of current wells. This level of exploration and development undoubtedly will draw the attention of environmental communities, focusing their concerns on produced water management based on perceived potential impacts to fresh water resources. Therefore, it is imperative that produced water management practices be performed in a manner that best minimizes environmental impacts. This is being accomplished by compiling current best management practices for produced water from conventional oil and gas operations and to develop an analysis tool based on a geographic information system (GIS) to assist in the understanding of watershed-issued permits. That would allow management costs to be kept in line with the specific projects and regions, which increases the productive life of wells and increases the ultimate recoverable reserves in the ground. A case study was conducted in Wyoming to validate the applicability of the GIS analysis tool for watershed evaluations under real world conditions. Results of the partnered research will continue to be shared utilizing proven methods, such as on the IGOCC Web site, preparing hard copies of the results, distribution of documented case studies, and development of reference and handbook components to accompany the interactive internet-based GIS watershed analysis tool. Additionally, there have been several technology transfer seminars and presentations. The goal is to maximize the recovery of our nation's energy reserves and to promote water conservation.

  9. Method for retorting oil shale

    DOE Patents [OSTI]

    Shang, Jer-Yu; Lui, A.P.

    1985-08-16

    The recovery of oil from oil shale is provided in a fluidized bed by using a fluidizing medium of a binary mixture of carbon dioxide and 5 steam. The mixture with a steam concentration in the range of about 20 to 75 volume percent steam provides an increase in oil yield over that achievable by using a fluidizing gas of carbon dioxide or steam alone when the mixture contains higher steam concentrations. The operating parameters for the fluidized bed retorted are essentially the same as those utilized with other gaseous fluidizing mediums with the significant gain being in the oil yield recovered which is attributable solely to the use of the binary mixture of carbon dioxide and steam. 2 figs.

  10. Heat recovery in building envelopes

    E-Print Network [OSTI]

    Walker, Iain S.; Sherman, Max H.

    2003-01-01

    2003). Infiltration heat recovery – ASHRAE Research ProjectModel for Infiltration Heat Recovery, Proc. 21 st AnnualN ATIONAL L ABORATORY Heat Recovery in Building Envelopes

  11. Heat Recovery in Building Envelopes

    E-Print Network [OSTI]

    Sherman, Max H.; Walker, Iain S.

    2001-01-01

    Model For Infiltration Heat Recovery. Proceedings 21st AivcLBNL 47329 HEAT RECOVERY IN BUILDING ENVELOPES Max H.contribution because of heat recovery within the building

  12. Heat recovery in building envelopes

    E-Print Network [OSTI]

    Walker, Iain S.; Sherman, Max H.

    2003-01-01

    2003). Infiltration heat recovery – ASHRAE Research ProjectModel for Infiltration Heat Recovery, Proc. 21 st AnnualWalker, I.S. (2001). "Heat Recovery in Building Envelopes".

  13. Visualizing the Surface Infrastructure Used to Move 2 MtCO2/year from the Dakota Gasification Company to the Weyburn CO2 Enhanced Oil Recovery Project: Version of July 1, 2009

    SciTech Connect (OSTI)

    Dooley, James J.

    2009-07-09

    Google Earth Pro has been employed to create an interactive flyover of the world’s largest operational carbon dioxide capture and storage project. The visualization focuses on the transport and storage of 2 MtCO2/year which is captured from the Dakota Gasification Facility (Beula, North Dakota) and transported 205 miles and injected into the Weyburn oil field in Southeastern Saskatchewan.

  14. Production of hydrogen from oil shale

    SciTech Connect (OSTI)

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

    1985-12-24

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

  15. 05663_AlaskaHeavyOil | netl.doe.gov

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

    Fluid and Rock Property Controls On Production and Seismic Monitoring Alaska Heavy Oils Last Reviewed 12202012 DE-NT0005663 Goal The goal of this project is to improve recovery...

  16. Recovery Act Milestones

    ScienceCinema (OSTI)

    Rogers, Matt

    2013-05-29

    Every 100 days, the Department of Energy is held accountable for a progress report on the American Recovery and Reinvestment Act. Update at 200 days, hosted by Matt Rogers, Senior Advisor to Secretary Steven Chu for Recovery Act Implementation.

  17. Locating Heat Recovery Opportunities 

    E-Print Network [OSTI]

    Waterland, A. F.

    1981-01-01

    Basic concepts of heat recovery are defined as they apply to the industrial community. Methods for locating, ranking, and developing heat recovery opportunities are presented and explained. The needs for useful heat 'sinks' are emphasized as equal...

  18. Adequate description of heavy oil viscosities and a method to assess optimal steam cyclic periods for thermal reservoir simulation 

    E-Print Network [OSTI]

    Mago, Alonso Luis

    2006-08-16

    exceeding 2.5 trillion barrels. Management decisions and production strategies from thermal oil recovery processes are frequently based on reservoir simulation. A proper description of the physical properties, particularly oil viscosity, is essential...

  19. Monitoring Seismic Attenuation Changes Using a 4D Relative Spectrum Method in Athabsca Heavy Oil Reservoir, Canada

    E-Print Network [OSTI]

    Shabelansky, Andrey Hanan

    2012-01-01

    Heating heavy oil reservoirs is a common method for reducing the high viscosity of heavy oil and thus increasing the recovery factor. Monitoring these changes in the reservoir is essential for delineating the heated region ...

  20. Disaster Resiliency and Recovery: Capabilities (Fact Sheet)

    SciTech Connect (OSTI)

    Not Available

    2012-11-01

    The National Renewable Energy Laboratory (NREL) is the nation's leader in energy efficient and renewable energy technologies, practices, and strategies. For the last 15 years, NREL has provided expertise, tools, and innovations to private industry; federal, state, and local governments; non-profit organizations; and communities during the planning, recovery, and rebuilding stages after disaster strikes.

  1. The stimulation of heavy oil reservoirs with electrical resistance heating 

    E-Print Network [OSTI]

    Baylor, Blake Allen

    1990-01-01

    field sample Fig. 26 ? Inflow performance relationship for the simulation with Hycal data 53 55 56 60 62 INTRODUCTION The application of heat to an oil reservoir is a process known as thermal recovery. The oldest known means of thermal...', and in 1986 for the White Wolf field in California. " More recent field tests were reported in Canada" and Brazil. Flock and Tharin ' examined possible thermal recovery techniques for heavy oils. In their discussion of resistance heating, they speculated...

  2. Constrained Optimization Technology Based on Synthesis Concepts for Solving Complex Heat Recovery Problems 

    E-Print Network [OSTI]

    Fuller, T. R.

    1979-01-01

    Simulation of complex heat recovery systems such as crude preheat trains using computer tools is now widely practiced. ChemDesign, Inc. has developed a computer tool which can perform this calculation but is also capable of synthesizing an optimum...

  3. Development of Extraction Techniques for the Detection of Signature Lipids from Oil

    SciTech Connect (OSTI)

    Borglin, Sharon; Geller, Jil; Chakraborty, Romy; Hazen, Terry; Mason, Olivia

    2010-05-17

    Pure cultures, including Desulfovibrio vulgaris and Methanococcus maripaludus, were combined with model oil samples and oil/diesel mixtures to optimize extraction techniques of signature lipids from oil in support of investigation of microbial communities in oil deposit samples targets for microbial enhanced hydrocarbon recovery. Several techniques were evaluated, including standard phospholipid extraction, ether linked lipid for Archaeal bacterial detection, and high pressure extractiontechniques. Recovery of lipids ranged from 50-80percent as compared to extraction of the pure culture. Extraction efficiency was evaluated by the use of internal standards. Field samples will also be tested for recovery of signature lipids with optimized extraction techniques.

  4. EIS-0068: Development Policy Options for the Naval Oil Shale Reserves in Colorado

    Broader source: Energy.gov [DOE]

    The U.S. Department of Energy Office of Naval Petroleum and Oil Shale Reserves prepared this programmatic statement to examine the environmental and socioeconomic impacts of development projects on the Naval Oil Shale Reserve 1, and examine select alternatives, such as encouraging production from other liquid fuel resources (coal liquefaction, biomass, offshore oil and enhanced oil recovery) or conserving petroleum in lieu of shale oil production.

  5. Waste oil reclamation. (Latest citations from the NTIS bibliographic database). Published Search

    SciTech Connect (OSTI)

    1995-03-01

    The bibliography contains citations concerning methods and equipment for reclamation and recycling of waste oils. Citations discuss recovery, disposal, and reuse of lubricating oils. Topics include economic analysis, programs assessment, re-refining techniques, chemical component analysis, and reclaimed oil evaluation. Regulations and standards for waste oil treatment and waste oil refineries are examined. (Contains 50-250 citations and includes a subject term index and title list.) (Copyright NERAC, Inc. 1995)

  6. Waste oil reclamation. (Latest citations from the NTIS bibliographic database). Published Search

    SciTech Connect (OSTI)

    1996-08-01

    The bibliography contains citations concerning methods and equipment for reclamation and recycling of waste oils. Citations discuss recovery, disposal, and reuse of lubricating oils. Topics include economic analysis, programs assessment, re-refining techniques, chemical component analysis, and reclaimed oil evaluation. Regulations and standards for waste oil treatment and waste oil refineries are examined. (Contains 50-250 citations and includes a subject term index and title list.) (Copyright NERAC, Inc. 1995)

  7. Waste oil reclamation. (Latest citations from the NTIS bibliographic database). Published Search

    SciTech Connect (OSTI)

    1997-10-01

    The bibliography contains citations concerning methods and equipment for reclamation and recycling of waste oils. Citations discuss recovery, disposal, and reuse of lubricating oils. Topics include economic analysis, programs assessment, re-refining techniques, chemical component analysis, and reclaimed oil evaluation. Regulations and standards for waste oil treatment and waste oil refineries are examined. (Contains 50-250 citations and includes a subject term index and title list.) (Copyright NERAC, Inc. 1995)

  8. Energy Recovery By Direct Contact Gas-Liquid Heat Exchange 

    E-Print Network [OSTI]

    Fair, J. R.; Bravo, J. L.

    1988-01-01

    , would be those relatively few cases where heat has been recovered from pyrolysis furnace gases (in ethylene 78712 manufacture) via a quench liquid that provides intennedia level heat for process purposes. In the present paper we shall concentrate... pyrolysis furnace are cooled in oil- and water-quench towers, and higher-boiling oils are condensed from the gases. While not always used for heat recovery, the exit process water stream is hot enough for process heat exchange. For the examples shown...

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

    SciTech Connect (OSTI)

    Hill, D.W.; Sande, J.J. [Shell Western E& P Inc., Bakersfield, CA (United States); Doe, P.H. [Shell Development Co., Houston, TX (United States)

    1995-04-01

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

  10. Socioeconomic impact of infill drilling recovery from carbonate reservoirs in the Permian Basin, West Texas 

    E-Print Network [OSTI]

    Jagoe, Bryan Keith

    1994-01-01

    This investigative study presents results on the socioeconomic impact of infill drilling recovery from carbonate reservoirs in the Permian Basin. The amount of incremental oil and gas production from infill drilling in 37 carbonate reservoir units...

  11. Battleground Energy Recovery Project

    SciTech Connect (OSTI)

    Daniel Bullock

    2011-12-31

    In October 2009, the project partners began a 36-month effort to develop an innovative, commercial-scale demonstration project incorporating state-of-the-art waste heat recovery technology at Clean Harbors, Inc., a large hazardous waste incinerator site located in Deer Park, Texas. With financial support provided by the U.S. Department of Energy, the Battleground Energy Recovery Project was launched to advance waste heat recovery solutions into the hazardous waste incineration market, an area that has seen little adoption of heat recovery in the United States. The goal of the project was to accelerate the use of energy-efficient, waste heat recovery technology as an alternative means to produce steam for industrial processes. The project had three main engineering and business objectives: Prove Feasibility of Waste Heat Recovery Technology at a Hazardous Waste Incinerator Complex; Provide Low-cost Steam to a Major Polypropylene Plant Using Waste Heat; and ï?· Create a Showcase Waste Heat Recovery Demonstration Project.

  12. ,"Fuel Oil Consumption",,,"Fuel Oil Expenditures"

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

    4. Fuel Oil Consumption and Expenditure Intensities for Non-Mall Buildings, 2003" ,"Fuel Oil Consumption",,,"Fuel Oil Expenditures" ,"per Building (gallons)","per Square Foot...

  13. ,"Fuel Oil Consumption",,,"Fuel Oil Expenditures"

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

    2. Fuel Oil Consumption and Expenditure Intensities, 1999" ,"Fuel Oil Consumption",,,"Fuel Oil Expenditures" ,"per Building (gallons)","per Square Foot (gallons)","per Worker...

  14. Gradient-based Methods for Production Optimization of Oil Reservoirs

    E-Print Network [OSTI]

    Foss, Bjarne A.

    Gradient-based Methods for Production Optimization of Oil Reservoirs Eka Suwartadi Doctoral Thesis at NTNU, 2012:104 Printed by NTNU-Trykk #12;To my wife and my parents 3 #12;4 #12;Summary Production optimization for water flooding in the secondary phase of oil recovery is the main topic in this thesis

  15. Development Practices for Optimized MEOR in Shallow Heavy Oil Reservoirs

    SciTech Connect (OSTI)

    Shari Dunn-Norman

    2006-09-30

    The goal of this project is to demonstrate an economically viable and sustainable method of producing shallow heavy oil reserves in southwest Missouri and southeast Kansas using a combination of microbial enhanced oil recovery (MEOR) and hydraulic fracturing of vertical wells.

  16. Percussion tool

    DOE Patents [OSTI]

    Reed, Teddy R.

    2006-11-28

    A percussion tool is described and which includes a housing mounting a tool bit; a reciprocally moveable hammer borne by the housing and which is operable to repeatedly strike the tool bit; and a reciprocally moveable piston enclosed within the hammer and which imparts reciprocal movement to the reciprocally moveable hammer.

  17. The Effects of Inorganic Solid Particles on Water and Crude Oil Emulsion Stability

    E-Print Network [OSTI]

    Kilpatrick, Peter K.

    The Effects of Inorganic Solid Particles on Water and Crude Oil Emulsion Stability Andrew P, Raleigh, North Carolina 27695-7905 Small inorganic particles strongly enhance water-crude oil emulsion accompanies crude oil during its recovery from a reservoir. Additional water might also be added to aid

  18. Advanced reservoir characterization in the Antelope Shale to establish the viability of CO{sub 2} enhanced oil recovery in California`s Monterey Formation siliceous shales. Annual report, February 12, 1996--February 11, 1997

    SciTech Connect (OSTI)

    Toronyi, R.M.

    1997-12-01

    The Buena Vista Hills field is located about 25 miles southwest of Bakersfield, in Kern County, California, about two miles north of the city of Taft, and five miles south of the Elk Hills field. The Antelope Shale zone was discovered at the Buena Vista Hills field in 1952, and has since been under primary production. Little research was done to improve the completion techniques during the development phase in the 1950s, so most of the wells are completed with about 1000 ft of slotted liner. The proposed pilot consists of four existing producers on 20 acre spacing with a new 10 acre infill well drilled as the pilot CO{sub 2} injector. Most of the reservoir characterization of the first phase of the project will be performed using data collected in the pilot pattern wells. This is the first annual report of the project. It covers the period February 12, 1996 to February 11, 1997. During this period the Chevron Murvale 653Z-26B well was drilled in Section 26-T31S/R23E in the Buena Vista Hills field, Kern County, California. The Monterey Formation equivalent Brown and Antelope Shales were continuously cored, the zone was logged with several different kinds of wireline logs, and the well was cased to a total depth of 4907 ft. Core recovery was 99.5%. Core analyses that have been performed include Dean Stark porosity, permeability and fluid saturations, field wettability, anelastic strain recovery, spectral core gamma, profile permeametry, and photographic imaging. Wireline log analysis includes mineral-based error minimization (ELAN), NMR T2 processing, and dipole shear wave anisotropy. A shear wave vertical seismic profile was acquired after casing was set and processing is nearly complete.

  19. Waste Heat Recovery

    Office of Environmental Management (EM)

    DRAFT - PRE-DECISIONAL - DRAFT 1 Waste Heat Recovery 1 Technology Assessment 2 Contents 3 1. Introduction to the TechnologySystem ......

  20. Oil prices spike to over barreland price

    E-Print Network [OSTI]

    Oil prices spike to over $145/ barreland price of electricity exceeds $0.50/kWh in U.S. Virgin installs waste heat recovery plant, adding19 MWofpower withoutburningasingledropof additionaloil VIEO Biomass Grid Waste-to- Energy Landfill Gas LEGEND Solar EDIN Energy Development in Island Nations EDIN

  1. Essays on Macroeconomics and Oil

    E-Print Network [OSTI]

    CAKIR, NIDA

    2013-01-01

    Oil Production . . . . . . . . . . . . . . . . . . . . . . . . . . .Oil Production in Venezuela and Mexico . . . . . . . . . .Oil Production and Productivity in Venezuela and

  2. Essays on Macroeconomics and Oil

    E-Print Network [OSTI]

    CAKIR, NIDA

    2013-01-01

    the Oil Industry . . . . . . . . . . . . . . . . . . . . . .in the Venezuelan Oil Industry . . . . . . . . . . . . .and Productivity: Evidence from the Oil Industry . .

  3. Well blowout rates and consequences in California Oil and Gas District 4 from 1991 to 2005: Implications for geological storage of carbon dioxide

    E-Print Network [OSTI]

    Jordan, Preston D.

    2008-01-01

    recovery (EOR) and natural gas storage. Keywords: geologicalsuch as natural gas storage, EOR, and deep undergroundstorage, such as natural gas storage and CO 2 -enhanced oil

  4. WIPP Recovery Information | Department of Energy

    Office of Environmental Management (EM)

    WIPP Recovery Information WIPP Recovery Information Topic: J. R. Stroble CBFO, Provided Information on Locations to Access WIPP Recovery Information. WIPP Recovery - March 26, 2014...

  5. Combustion Assisted Gravity Drainage (CAGD): An In-Situ Combustion Method to Recover Heavy Oil and Bitumen from Geologic Formations using a Horizontal Injector/Producer Pair 

    E-Print Network [OSTI]

    Rahnema, Hamid

    2012-11-21

    Combustion assisted gravity drainage (CAGD) is an integrated horizontal well air injection process for recovery and upgrading of heavy oil and bitumen from tar sands. Short-distance air injection and direct mobilized oil production are the main...

  6. Mass and Heat Recovery 

    E-Print Network [OSTI]

    Hindawai, S. M.

    2010-01-01

    In the last few years heat recovery was under spot and in air conditioning fields usually we use heat recovery by different types of heat exchangers. The heat exchanging between the exhaust air from the building with the fresh air to the building...

  7. Recovery Boiler Corrosion Chemistry

    E-Print Network [OSTI]

    Das, Suman

    11/13/2014 1 Recovery Boiler Corrosion Chemistry Sandy Sharp and Honghi Tran Symposium on Corrosion of a recovery boiler each cause their own forms of corrosion and cracking Understanding the origin of the corrosive conditions enables us to operate a boiler so as to minimize corrosion and cracking select

  8. Trends in heavy oil production and refining in California

    SciTech Connect (OSTI)

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

    1992-07-01

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

  9. Trends in heavy oil production and refining in California

    SciTech Connect (OSTI)

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

    1992-07-01

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

  10. ANALYSIS OF OIL TRAPPING IN POROUS MEDIA FLOW M. BERTSCH \\Lambda , R. DAL PASSO \\Lambda , AND C.J. VAN DUIJN y

    E-Print Network [OSTI]

    Eindhoven, Technische Universiteit

    ANALYSIS OF OIL TRAPPING IN POROUS MEDIA FLOW M. BERTSCH \\Lambda , R. DAL PASSO \\Lambda , AND C, considerably reduce the recovery factor of an oil reservoir. For instance, it is difficult to remove oil from parts of the reservoir with small scale heterogeneities. Sometimes, the oil may even remain trapped; see

  11. Recovery Act State Memos Virginia

    Energy Savers [EERE]

    * VIRGINIA RECOVERY ACT SNAPSHOT Virginia has substantial natural resources, including coal and natural gas. The American Recovery & Reinvestment Act (ARRA) is making a...

  12. Recovery Act: Demonstrating The Commercial Feasibility Of

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Home Page on Google Bookmark EERE: Alternative Fuels Data Center Home Page on Delicious Rank EERE:Financing Tool FitsProject Developsfor UCNIEnvironmental Impact StatementRecovery ActDepartment

  13. ,"Total Fuel Oil Expenditures

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

    . Fuel Oil Expenditures by Census Region for Non-Mall Buildings, 2003" ,"Total Fuel Oil Expenditures (million dollars)",,,,"Fuel Oil Expenditures (dollars)" ,,,,,"per...

  14. ,"Total Fuel Oil Consumption

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

    0. Fuel Oil Consumption (gallons) and Energy Intensities by End Use for Non-Mall Buildings, 2003" ,"Total Fuel Oil Consumption (million gallons)",,,,,"Fuel Oil Energy Intensity...

  15. ,"Total Fuel Oil Expenditures

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

    4. Fuel Oil Expenditures by Census Region, 1999" ,"Total Fuel Oil Expenditures (million dollars)",,,,"Fuel Oil Expenditures (dollars)" ,,,,,"per Gallon",,,,"per Square Foot"...

  16. Understanding Crude Oil Prices

    E-Print Network [OSTI]

    Hamilton, James Douglas

    2008-01-01

    From EIA, “World Production of Crude Oil, NGPL, and Otherfrom EIA, “World Production of Crude Oil, NGPL, and Otherfrom EIA, “World Production of Crude Oil, NGPL, and Other

  17. ,"Total Fuel Oil Expenditures

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

    A. Fuel Oil Expenditures by Census Region for All Buildings, 2003" ,"Total Fuel Oil Expenditures (million dollars)",,,,"Fuel Oil Expenditures (dollars)" ,,,,,"per Gallon",,,,"per...

  18. ,"Total Fuel Oil Consumption

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

    A. Fuel Oil Consumption (gallons) and Energy Intensities by End Use for All Buildings, 2003" ,"Total Fuel Oil Consumption (million gallons)",,,,,"Fuel Oil Energy Intensity...

  19. Development of CFD-Based Simulation Tools for In-Situ Thermal...

    Office of Scientific and Technical Information (OSTI)

    CFD-Based Simulation Tools for In-Situ Thermal Processing of Oil ShaleSands None 04 OIL SHALES AND TAR SANDS In our research, we are taking the novel approach of developing and...

  20. ARM - Recovery Act

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

    AFDC Printable Version Share this resource Send a link to EERE: Alternative Fuels Data Center Home Page to someone by E-mail Share EERE: Alternative Fuels Data Center Home Page on Facebook Tweet about EERE: Alternative Fuels Data Center Home Page on Twitter Bookmark EERE: Alternative Fuels Data Center Homesum_a_epg0_fpd_mmcf_m.xls" ,"Available from WebQuantity of NaturalDukeWakefieldSulfateSciTechtail.Theory of raregovAboutRecovery Act Recovery Act Logo Subscribe FAQs Recovery Act

  1. Waste Steam Recovery 

    E-Print Network [OSTI]

    Kleinfeld, J. M.

    1979-01-01

    An examination has been made of the recovery of waste steam by three techniques: direct heat exchange to process, mechanical compression, and thermocompression. Near atmospheric steam sources were considered, but the techniques developed are equally...

  2. Exhaust Energy Recovery

    Broader source: Energy.gov [DOE]

    Exhaust energy recovery proposed to achieve 10% fuel efficiency improvement and reduce or eliminate the need for increased heat rejectioncapacity for future heavy duty engines in Class 8 Tractors

  3. Documentation of the Oil and Gas Supply Module (OGSM)

    SciTech Connect (OSTI)

    1998-01-01

    The purpose of this report is to define the objectives of the Oil and Gas Supply Model (OGSM), to describe the model`s basic approach, and to provide detail on how the model works. This report is intended as a reference document for model analysts, users, and the public. Projected production estimates of US crude oil and natural gas are based on supply functions generated endogenously within National Energy Modeling System (NEMS) by the OGSM. OGSM encompasses domestic crude oil and natural gas supply by both conventional and nonconventional recovery techniques. Nonconventional recovery includes enhanced oil recovery (EOR), and unconventional gas recovery (UGR) from tight gas formations, Devonian/Antrim shale and coalbeds. Crude oil and natural gas projections are further disaggregated by geographic region. OGSM projects US domestic oil and gas supply for six Lower 48 onshore regions, three offshore regions, and Alaska. The general methodology relies on forecasted profitability to determine exploratory and developmental drilling levels for each region and fuel type. These projected drilling levels translate into reserve additions, as well as a modification of the production capacity for each region. OGSM also represents foreign trade in natural gas, imports and exports by entry region. Foreign gas trade may occur via either pipeline (Canada or Mexico), or via transport ships as liquefied natural gas (LNG). These import supply functions are critical elements of any market modeling effort.

  4. Queer Tools

    E-Print Network [OSTI]

    Hacker, Randi; Tsutsui, William

    2007-11-19

    Broadcast Transcript: Chindogu. Did someone say "Bless you?" No need. This is a Japanese word that means "queer tools" and it was coined to describe the Japanese penchant for unusual inventions. From toilet paper rolls that attach to the head...

  5. Workflow Tools

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

    at NERSC go here. Galaxy - Galaxy is a web based workflow tool that is use by the genomics community. It allows you to define job dependencies via a web based workflow engine....

  6. A simulation study of steam and steam-propane injection using a novel smart horizontal producer to enhance oil production 

    E-Print Network [OSTI]

    Sandoval Munoz, Jorge Eduardo

    2004-11-15

    in an increase of oil recovery to 35.4-32.6% OOIP at 150-300 BPDCWE. Fifth, with steam-propane injection, for both well systems, oil production acceleration increases with lower injection rates. Sixth, the second oil production peak in the vertical...

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

    E-Print Network [OSTI]

    Mohaghegh, Shahab

    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

  8. Use of X-Ray Computed Microtomography to Understand Why Gels Reduce Permeability to Water More Than That to Oil

    E-Print Network [OSTI]

    New York at Stoney Brook, State University of

    That to Oil R. S. Seright * , New Mexico Petroleum Recovery Research Center J. Liang, Idaho National was used to investigate why gels reduce permeability to water more than that to oil in strongly water 80 to 90 times more than that to oil. In Berea, the gel caused disproportionate permeability

  9. Chemical Methods for Ugnu Viscous Oils

    SciTech Connect (OSTI)

    Kishore Mohanty

    2012-03-31

    The North Slope of Alaska has large (about 20 billion barrels) deposits of viscous oil in Ugnu, West Sak and Shraeder Bluff reservoirs. These shallow reservoirs overlie existing productive reservoirs such as Kuparuk and Milne Point. The viscosity of the Ugnu reservoir on top of Milne Point varies from 200 cp to 10,000 cp and the depth is about 3300 ft. The same reservoir extends to the west on the top of the Kuparuk River Unit and onto the Beaufort Sea. The depth of the reservoir decreases and the viscosity increases towards the west. Currently, the operators are testing cold heavy oil production with sand (CHOPS) in Ugnu, but oil recovery is expected to be low (< 10%). Improved oil recovery techniques must be developed for these reservoirs. The proximity to the permafrost is an issue for thermal methods; thus nonthermal methods must be considered. The objective of this project is to develop chemical methods for the Ugnu reservoir on the top of Milne Point. An alkaline-surfactant-polymer (ASP) formulation was developed for a viscous oil (330 cp) where as an alkaline-surfactant formulation was developed for a heavy oil (10,000 cp). These formulations were tested in one-dimensional and quarter five-spot Ugnu sand packs. Micromodel studies were conducted to determine the mechanisms of high viscosity ratio displacements. Laboratory displacements were modeled and transport parameters (such as relative permeability) were determined that can be used in reservoir simulations. Ugnu oil is suitable for chemical flooding because it is biodegraded and contains some organic acids. The acids react with injected alkali to produce soap. This soap helps in lowering interfacial tension between water and oil which in turn helps in the formation of macro and micro emulsions. A lower amount of synthetic surfactant is needed because of the presence of organic acids in the oil. Tertiary ASP flooding is very effective for the 330 cp viscous oil in 1D sand pack. This chemical formulation includes 1.5% of an alkali, 0.4% of a nonionic surfactant, and 0.48% of a polymer. The secondary waterflood in a 1D sand pack had a cumulative recovery of 0.61 PV in about 3 PV injection. The residual oil saturation to waterflood was 0.26. Injection of tertiary alkaline-surfactant-polymer slug followed by tapered polymer slugs could recover almost 100% of the remaining oil. The tertiary alkali-surfactant-polymer flood of the 330 cp oil is stable in three-dimensions; it was verified by a flood in a transparent 5-spot model. A secondary polymer flood is also effective for the 330 cp viscous oil in 1D sand pack. The secondary polymer flood recovered about 0.78 PV of oil in about 1 PV injection. The remaining oil saturation was 0.09. The pressure drops were reasonable (<2 psi/ft) and depended mainly on the viscosity of the polymer slug injected. For the heavy crude oil (of viscosity 10,000 cp), low viscosity (10-100 cp) oil-in-water emulsions can be obtained at salinity up to 20,000 ppm by using a hydrophilic surfactant along with an alkali at a high water-to-oil ratio of 9:1. Very dilute surfactant concentrations (~0.1 wt%) of the synthetic surfactant are required to generate the emulsions. It is much easier to flow the low viscosity emulsion than the original oil of viscosity 10,000 cp. Decreasing the WOR reverses the type of emulsion to water-in-oil type. For a low salinity of 0 ppm NaCl, the emulsion remained O/W even when the WOR was decreased. Hence a low salinity injection water is preferred if an oil-in-water emulsion is to be formed. Secondary waterflood of the 10,000 cp heavy oil followed by tertiary injection of alkaline-surfactants is very effective. Waterflood has early water breakthrough, but recovers a substantial amount of oil beyond breakthrough. Waterflood recovers 20-37% PV of the oil in 1D sand pack in about 3 PV injection. Tertiary alkali-surfactant injection increases the heavy oil recovery to 50-70% PV in 1D sand packs. As the salinity increased, the oil recovery due to alkaline surfactant flood increased, but water-in-oil emulsion was p

  10. Major Oil Plays In Utah And Vicinity

    SciTech Connect (OSTI)

    Thomas Chidsey

    2007-12-31

    Utah oil fields have produced over 1.33 billion barrels (211 million m{sup 3}) of oil and hold 256 million barrels (40.7 million m{sup 3}) of proved reserves. The 13.7 million barrels (2.2 million m3) of production in 2002 was the lowest level in over 40 years and continued the steady decline that began in the mid-1980s. However, in late 2005 oil production increased, due, in part, to the discovery of Covenant field in the central Utah Navajo Sandstone thrust belt ('Hingeline') play, and to increased development drilling in the central Uinta Basin, reversing the decline that began in the mid-1980s. The Utah Geological Survey believes providing play portfolios for the major oil-producing provinces (Paradox Basin, Uinta Basin, and thrust belt) in Utah and adjacent areas in Colorado and Wyoming can continue this new upward production trend. Oil plays are geographic areas with petroleum potential caused by favorable combinations of source rock, migration paths, reservoir rock characteristics, and other factors. The play portfolios include descriptions and maps of the major oil plays by reservoir; production and reservoir data; case-study field evaluations; locations of major oil pipelines; identification and discussion of land-use constraints; descriptions of reservoir outcrop analogs; and summaries of the state-of-the-art drilling, completion, and secondary/tertiary recovery techniques for each play. The most prolific oil reservoir in the Utah/Wyoming thrust belt province is the eolian, Jurassic Nugget Sandstone, having produced over 288 million barrels (46 million m{sup 3}) of oil and 5.1 trillion cubic feet (145 billion m{sup 3}) of gas. Traps form on discrete subsidiary closures along major ramp anticlines where the depositionally heterogeneous Nugget is also extensively fractured. Hydrocarbons in Nugget reservoirs were generated from subthrust Cretaceous source rocks. The seals for the producing horizons are overlying argillaceous and gypsiferous beds in the Jurassic Twin Creek Limestone, or a low-permeability zone at the top of the Nugget. The Nugget Sandstone thrust belt play is divided into three subplays: (1) Absaroka thrust - Mesozoic-cored shallow structures, (2) Absaroka thrust - Mesozoic-cored deep structures, and (3) Absaroka thrust - Paleozoic-cored shallow structures. Both of the Mesozoic-cored structures subplays represent a linear, hanging wall, ramp anticline parallel to the leading edge of the Absaroka thrust. Fields in the shallow Mesozoic subplay produce crude oil and associated gas; fields in the deep subplay produce retrograde condensate. The Paleozoic-cored structures subplay is located immediately west of the Mesozoic-cored structures subplays. It represents a very continuous and linear, hanging wall, ramp anticline where the Nugget is truncated against a thrust splay. Fields in this subplay produce nonassociated gas and condensate. Traps in these subplays consist of long, narrow, doubly plunging anticlines. Prospective drilling targets are delineated using high-quality, two-dimensional and three-dimensional seismic data, forward modeling/visualization tools, and other state-of-the-art techniques. Future Nugget Sandstone exploration could focus on more structurally complex and subtle, thrust-related traps. Nugget structures may be present beneath the leading edge of the Hogsback thrust and North Flank fault of the Uinta uplift. The Jurassic Twin Creek Limestone play in the Utah/Wyoming thrust belt province has produced over 15 million barrels (2.4 million m{sup 3}) of oil and 93 billion cubic feet (2.6 billion m{sup 3}) of gas. Traps form on discrete subsidiary closures along major ramp anticlines where the low-porosity Twin Creek is extensively fractured. Hydrocarbons in Twin Creek reservoirs were generated from subthrust Cretaceous source rocks. The seals for the producing horizons are overlying argillaceous and clastic beds, and non-fractured units within the Twin Creek. The Twin Creek Limestone thrust belt play is divided into two subplays: (1) Absaroka thrust-Mesozoic-cored structures and (2) A

  11. Using Polymer to Maximize CO2 Flooding Performance in Light Oils 

    E-Print Network [OSTI]

    Li, Weirong

    2014-12-17

    flooding in the North Burbank Unit, five sections that best represent the characteristics of the field were selected for reservoir modeling. Based on simulation results, the conventional WAG process increased average oil recovery in the North Burbank Unit...

  12. Inversion of field-scale partitioning tracer response for characterizing oil saturation distribution: a streamline approach 

    E-Print Network [OSTI]

    Iliassov, Pavel Alexandrovich

    2000-01-01

    Identifying distribution of remaining oil in the reservoir is vital for evaluation of existing waterflood, design of tertiary recovery projects, and location of infill drilling candidates. In recent years, partitioning interwell tracer tests (PITT...

  13. Progress in waste oil to sustainable energy, with emphasis on pyrolysis techniques

    E-Print Network [OSTI]

    Lam, Su Shiung; Liew, Rock Keey; Jusoh, Ahmad; Chong, Cheng Tung; Ani, Farid Nasir; Chase, Howard A.

    2015-10-02

    This paper begins with a review on the current techniques used for the treatment and recovery of waste oil, which is then followed by an extensive review of the recent achievements in the sustainable development and utilization of pyrolysis...

  14. Plan and justification for a Proof-of-Concept oil shale facility. Final report

    SciTech Connect (OSTI)

    Not Available

    1990-12-01

    The technology being evaluated is the Modified In-Situ (MIS) retorting process for raw shale oil production, combined with a Circulating Fluidized Bed Combustor (CFBC), for the recovery of energy from the mined shale. (VC)

  15. Enhanced coalbed methane recovery

    SciTech Connect (OSTI)

    Mazzotti, M.; Pini, R.; Storti, G. [ETH, Zurich (Switzerland). Inst. of Process Engineering

    2009-01-15

    The recovery of coalbed methane can be enhanced by injecting CO{sub 2} in the coal seam at supercritical conditions. Through an in situ adsorption/desorption process the displaced methane is produced and the adsorbed CO{sub 2} is permanently stored. This is called enhanced coalbed methane recovery (ECBM) and it is a technique under investigation as a possible approach to the geological storage of CO{sub 2} in a carbon dioxide capture and storage system. This work reviews the state of the art on fundamental and practical aspects of the technology and summarizes the results of ECBM field tests. These prove the feasibility of ECBM recovery and highlight substantial opportunities for interdisciplinary research at the interface between earth sciences and chemical engineering.

  16. Solvent recovery targeting

    SciTech Connect (OSTI)

    Ahmad, B.S.; Barton, P.I.

    1999-02-01

    One of the environmental challenges faced by the pharmaceutical and specialty chemical industries is the widespread use of organic solvents. With a solvent-based chemistry, the solvent necessarily has to be separated from the product. Chemical species in waste-solvent streams typically form multicomponent azeotropic mixtures, and this often complicates separation and, hence, recovery of solvents. A design approach is presented whereby process modifications proposed by the engineer to reduce the formation of waste-solvent streams can be evaluated systematically. This approach, called solvent recovery targeting, exploits a recently developed algorithm for elucidating the separation alternatives achievable when applying batch distillation to homogeneous multicomponent mixtures. The approach places the composition of the waste-solvent mixture correctly in the relevant residue curve map and computes the maximum amount of pure material that can be recovered via batch distillation. Solvent recovery targeting is applied to two case studies derived from real industrial processes.

  17. Northeast Home Heating Oil Reserve System Heating Oil, PIA Office...

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

    Northeast Home Heating Oil Reserve System Heating Oil, PIA Office of Fossil Energy Headquaters Northeast Home Heating Oil Reserve System Heating Oil, PIA Office of Fossil Energy...

  18. 5 World Oil Trends WORLD OIL TRENDS

    E-Print Network [OSTI]

    's share of world crude oil production has rebound5 World Oil Trends Chapter 1 WORLD OIL TRENDS INTRODUCTION In considering the outlook for California's petroleum supplies, it is important to give attention to expecta- tions of what the world oil

  19. Industrial Heat Recovery - 1982 

    E-Print Network [OSTI]

    Csathy, D.

    1982-01-01

    Industrial Research HTFS Re search Programme HTFS/1S/R19, "Dryout and Flow in Horizontal and Horizontal Hairpin Tubes". 6 l\\rnerican Boiler I1anufacturers Assoc iation, "Lexicon, Boiler & Auxiliary Eauinment", 7 G:t=iffith P., book of I:eat senow N... RECOVERY - 1982 by Denis Csathy, Deltak Corn,oration, !1inneapolis, 11N Two years ago I summarized 20 years of ex perience on Industrial Heat Recovery for the Energy-source Technology Conference and Exhibition held in New Orleans, Louisiana. l...

  20. Catalytic Hydrogenation of Bio-Oil for Chemicals and Fuels

    SciTech Connect (OSTI)

    Elliott, Douglas C.

    2006-02-14

    The scope of work includes optimizing processing conditions and demonstrating catalyst lifetime for catalyst formulations that are readily scaleable to commercial operations. We use a bench-scale, continuous-flow, packed-bed, catalytic, tubular reactor, which can be operated in the range of 100-400 mL/hr., from 50-400 C and up to 20MPa (see Figure 1). With this unit we produce upgraded bio-oil from whole bio-oil or useful bio-oil fractions, specifically pyrolytic lignin. The product oils are fractionated, for example by distillation, for recovery of chemical product streams. Other products from our tests have been used in further testing in petroleum refining technology at UOP and fractionation for product recovery in our own lab. Further scale-up of the technology is envisioned and we will carry out or support process design efforts with industrial partners, such as UOP.

  1. Oil displacement through a porous medium with a temperature gradient

    E-Print Network [OSTI]

    Oliveira, C L N; Herrmann, H J

    2011-01-01

    We investigate the effect of a temperature gradient on oil recovery in a two-dimensional pore-network model. The oil viscosity depends on temperature as, $\\mu_o=exp(B/T)$, where $B$ is a physico-chemical parameter depending on the type of oil, and $T$ is the temperature. A temperature gradient is applied across the medium in the flow direction. Initially, the porous medium is saturated with oil and, then, another fluid is injected. We have considered two cases representing different injection strategies. In the first case, the invading fluid viscosity is constant (finite viscosity ratio) while in the second one, the invading fluid is inviscid (infinite viscosity ratio). Our results show that, for the case of finite viscosity ratio, recovery increases with $\\Delta T$ independently on strength or sign of the gradient. For an infinite viscosity ratio, a positive temperature gradient is necessary to enhance recovery. Moreover, we show that, for $\\Delta T>0$, the percentage of oil recovery generally decreases (inc...

  2. Recovery Act Workforce Development | Department of Energy

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

    Announces Nearly 100 Million for Smart Grid Workforce Training and Development. Congressional Testimony Recovery Act Recovery Act Interoperability Recovery Act SGIG...

  3. Distributed Generation with Heat Recovery and Storage

    E-Print Network [OSTI]

    Siddiqui, Afzal; Marnay, Chris; Firestone, Ryan M.; Zhou, Nan

    2005-01-01

    Generation with Heat Recovery and Storage ‡ Afzal Sgeneration unit with heat recovery for space and watergeneration unit with heat recovery for space and water

  4. Distributed Generation with Heat Recovery and Storage

    E-Print Network [OSTI]

    Siddiqui, Afzal S.; Marnay, Chris; Firestone, Ryan M.; Zhou, Nan

    2008-01-01

    Distributed Generation with Heat Recovery and Storage AfzalGeneration with Heat Recovery and Storage Manuscript Numberhere in order to focus on heat recovery and storage) utility

  5. A mathematical model for infiltration heat recovery

    E-Print Network [OSTI]

    Buchanan, C.R.; Sherman, M.H.

    2000-01-01

    Simulation of Infiltration Heat Recovery”, 19 th AIVC Annualfor infiltration heat recovery could easily be incorporatedSimplified Infiltration Heat Recovery Model ……………………17

  6. Managing large oil Spills in the Mediterranean

    E-Print Network [OSTI]

    Madrid, J A Jiménez; Poy, J Ballabrera; García-Ladona, E

    2015-01-01

    For the first time a statistical analysis of oil spill beaching is applied to the whole Mediterranean Sea. A series of probability maps of beaching in case of an oil spill incident are proposed as a complementary tool to vulnerability analysis and risk assessment in the whole basin. As a first approach a set of spill source points are selected along the main paths of tankers and a few points of special interest related with hot spot areas or oil platforms. Probability of beaching on coastal segments are obtained for 3 types of oil characterised by medium to highly persistence in water. The approach is based on Lagrangian simulations using particles as a proxy of oil spills evolving according the environmental conditions provided by a hincast model of the Mediterranean circulation.

  7. One "Cool Tool" That's Helping Repair Your DNA | Department of...

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

    them to examine everything from the structure of proteins to the chemistry of the ozone layer. While these cool tools from the Office of Science won't help you change the oil...

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

    SciTech Connect (OSTI)

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

    1993-09-01

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

  9. Fluid and Rock Property Controls On Production And Seismic Monitoring Alaska Heavy Oils

    SciTech Connect (OSTI)

    Matthew Liberatore; Andy Herring; Manika Prasad; John Dorgan; Mike Batzle

    2012-06-30

    The goal of this project is to improve recovery of Alaskan North Slope (ANS) heavy oil resources in the Ugnu formation by improving our understanding of the formationâ??s vertical and lateral heterogeneities via core evaluation, evaluating possible recovery processes, and employing geophysical monitoring to assess production and modify production operations.

  10. Downhole tool

    DOE Patents [OSTI]

    Hall, David R.; Muradov, Andrei; Pixton, David S.; Dahlgren, Scott Steven; Briscoe, Michael A.

    2007-03-20

    A double shouldered downhole tool connection comprises box and pin connections having mating threads intermediate mating primary and secondary shoulders. The connection further comprises a secondary shoulder component retained in the box connection intermediate a floating component and the primary shoulders. The secondary shoulder component and the pin connection cooperate to transfer a portion of makeup load to the box connection. The downhole tool may be selected from the group consisting of drill pipe, drill collars, production pipe, and reamers. The floating component may be selected from the group consisting of electronics modules, generators, gyroscopes, power sources, and stators. The secondary shoulder component may comprises an interface to the box connection selected from the group consisting of radial grooves, axial grooves, tapered grooves, radial protrusions, axial protrusions, tapered protrusions, shoulders, and threads.

  11. Using Fuel Oil",,,"Fuel Oil Consumption",,"Fuel Oil Expenditures...

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

    . Total Fuel Oil Consumption and Expenditures for Non-Mall Buildings, 2003" ,"All Buildings* Using Fuel Oil",,,"Fuel Oil Consumption",,"Fuel Oil Expenditures" ,"Number of Buildings...

  12. Using Fuel Oil",,,"Fuel Oil Consumption",,"Fuel Oil Expenditures...

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

    A. Total Fuel Oil Consumption and Expenditures for All Buildings, 2003" ,"All Buildings Using Fuel Oil",,,"Fuel Oil Consumption",,"Fuel Oil Expenditures" ,"Number of Buildings...

  13. Asia Pacific oil and gas conference: Proceedings

    SciTech Connect (OSTI)

    NONE

    1994-12-31

    This book is a compilation of conference proceedings on oil and gas development technologies for the Pacific Rim countries. It includes papers on horizontal drilling technologies, reservoir modeling, corrosion protection techniques, pipeline design and flow measurement, and well logging instrumentation. Other papers deal with resource management and reservoir engineering techniques and modeling. Reservoir engineering papers include enhanced recovery and well stimulation techniques as well as optimizing field depletion.

  14. Challenges in Industrial Heat Recovery 

    E-Print Network [OSTI]

    Dafft, T.

    2007-01-01

    This presentation will address several completed and working projects involving waste heat recovery in a chemical plant. Specific examples will be shown and some of the challenges to successful implementation and operation of heat recovery projects...

  15. New York Recovery Act Snapshot

    Broader source: Energy.gov [DOE]

    The American Recovery & Reinvestment Act (ARRA) is making a meaningful down payment on the nation's energy and environmental future. The Recovery Act investments in New York are supporting a...

  16. RISK REDUCTION WITH A FUZZY EXPERT EXPLORATION TOOL

    SciTech Connect (OSTI)

    Robert S. Balch; Ron Broadhead

    2005-03-01

    Incomplete or sparse data such as geologic or formation characteristics introduce a high level of risk for oil exploration and development projects. ''Expert'' systems developed and used in several disciplines and industries have demonstrated beneficial results when working with sparse data. State-of-the-art expert exploration tools, relying on a database, and computer maps generated by neural networks and user inputs, have been developed through the use of ''fuzzy'' logic, a mathematical treatment of imprecise or non-explicit parameters and values. Oil prospecting risk has been reduced with the use of these properly verified and validated ''Fuzzy Expert Exploration (FEE) Tools.'' Through the course of this project, FEE Tools and supporting software were developed for two producing formations in southeast New Mexico. Tools of this type can be beneficial in many regions of the U.S. by enabling risk reduction in oil and gas prospecting as well as decreased prospecting and development costs. In today's oil industry environment, many smaller exploration companies lack the resources of a pool of expert exploration personnel. Downsizing, volatile oil prices, and scarcity of domestic exploration funds have also affected larger companies, and will, with time, affect the end users of oil industry products in the U.S. as reserves are depleted. The FEE Tools benefit a diverse group in the U.S., allowing a more efficient use of scarce funds, and potentially reducing dependence on foreign oil and providing lower product prices for consumers.

  17. [Waste water heat recovery system

    SciTech Connect (OSTI)

    Not Available

    1993-04-28

    The production capabilities for and field testing of the heat recovery system are described briefly. Drawings are included.

  18. Running Out of and Into Oil: Analyzing Global Oil Depletion and Transition Through 2050

    SciTech Connect (OSTI)

    Greene, D.L.

    2003-11-14

    This report presents a risk analysis of world conventional oil resource production, depletion, expansion, and a possible transition to unconventional oil resources such as oil sands, heavy oil and shale oil over the period 2000 to 2050. Risk analysis uses Monte Carlo simulation methods to produce a probability distribution of outcomes rather than a single value. Probability distributions are produced for the year in which conventional oil production peaks for the world as a whole and the year of peak production from regions outside the Middle East. Recent estimates of world oil resources by the United States Geological Survey (USGS), the International Institute of Applied Systems Analysis (IIASA), the World Energy Council (WEC) and Dr. C. Campbell provide alternative views of the extent of ultimate world oil resources. A model of oil resource depletion and expansion for twelve world regions is combined with a market equilibrium model of conventional and unconventional oil supply and demand to create a World Energy Scenarios Model (WESM). The model does not make use of Hubbert curves but instead relies on target reserve-to-production ratios to determine when regional output will begin to decline. The authors believe that their analysis has a bias toward optimism about oil resource availability because it does not attempt to incorporate political or environmental constraints on production, nor does it explicitly include geologic constraints on production rates. Global energy scenarios created by IIASA and WEC provide the context for the risk analysis. Key variables such as the quantity of undiscovered oil and rates of technological progress are treated as probability distributions, rather than constants. Analyses based on the USGS and IIASA resource assessments indicate that conventional oil production outside the Middle East is likely to peak sometime between 2010 and 2030. The most important determinants of the date are the quantity of undiscovered oil, the rate at which unconventional oil production can be expanded, and the rate of growth of reserves and enhanced recovery. Analysis based on data produced by Campbell indicates that the peak of non-Middle East production will occur before 2010. For total world conventional oil production, the results indicate a peak somewhere between 2020 and 2050. Key determinants of the peak in world oil production are the rate at which the Middle East region expands its output and the minimum reserves-to-production ratios producers will tolerate. Once world conventional oil production peaks, first oil sands and heavy oil from Canada, Venezuela and Russia, and later some other source such as shale oil from the United States must expand if total world oil consumption is to continue to increase. Alternative sources of liquid hydrocarbon fuels, such as coal or natural gas are also possible resources but not considered in this analysis nor is the possibility of transition to a hydrogen economy. These limitations were adopted to simplify the transition analysis. Inspection of the paths of conventional oil production indicates that even if world oil production does not peak before 2020, output of conventional oil is likely to increase at a substantially slower rate after that date. The implication is that there will have to be increased production of unconventional oil after that date if world petroleum consumption is to grow.

  19. China's Global Oil Strategy

    E-Print Network [OSTI]

    Thomas, Bryan G

    2009-01-01

    unfettered access to oil resources including the possibleChina’s search for oil resources around the world. However,a survey of China’s oil resources, while others focus

  20. Understanding Crude Oil Prices

    E-Print Network [OSTI]

    Hamilton, James Douglas

    2008-01-01

    Figure 5. Monthly oil production for Iran, Iraq, and Kuwait,day. Monthly crude oil production Iran Iraq Kuwait Figure 6.and the peak in U.S. oil production account for the broad