WorldWideScience

Sample records for shale oil recovery

  1. Chemically assisted in situ recovery of oil shale

    Energy Technology Data Exchange (ETDEWEB)

    Ramierz, W.F.

    1993-12-31

    The purpose of the research project was to investigate the feasibility of the chemically assisted in situ retort method for recovering shale oil from Colorado oil shale. The chemically assisted in situ procedure uses hydrogen chloride (HCl), steam (H{sub 2}O), and carbon dioxide (CO{sub 2}) at moderate pressure to recovery shale oil from Colorado oil shale at temperatures substantially lower than those required for the thermal decomposition of kerogen. The process had been previously examined under static, reaction-equilibrium conditions, and had been shown to achieve significant shale oil recoveries from powdered oil shale. The purpose of this research project was to determine if these results were applicable to a dynamic experiment, and achieve penetration into and recovery of shale oil from solid oil shale. Much was learned about how to perform these experiments. Corrosion, chemical stability, and temperature stability problems were discovered and overcome. Engineering and design problems were discovered and overcome. High recovery (90% of estimated Fischer Assay) was observed in one experiment. Significant recovery (30% of estimated Fischer Assay) was also observed in another experiment. Minor amounts of freed organics were observed in two more experiments. Penetration and breakthrough of solid cores was observed in six experiments.

  2. Shale-oil-recovery systems incorporating ore beneficiation. Final report.

    Energy Technology Data Exchange (ETDEWEB)

    Weiss, M.A.; Klumpar, I.V.; Peterson, C.R.; Ring, T.A.

    1982-10-01

    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 identify systems which could be more attractive than conventional surface retorting of ore. No experimental work was carried out. The systems analyzed consisted of beneficiation methods which could increase kerogen concentrations by at least four-fold. Potentially attractive low-enrichment methods such as density separation were not examined. The technical alternatives considered were bounded by the secondary crusher as input and raw shale oil as output. A sequence of ball milling, froth flotation, and retorting concentrate is not attractive for Western shales compared to conventional ore retorting; transporting the concentrate to another location for retorting reduces air emissions in the ore region but cost reduction is questionable. The high capital and energy cost s results largely from the ball milling step which is very inefficient. Major improvements in comminution seem achievable through research and such improvements, plus confirmation of other assumptions, could make high-enrichment beneficiation competitive with conventional processing. 27 figures, 23 tables.

  3. Discussion of the feasibility of air injection for enhanced oil recovery in shale oil reservoirs

    Directory of Open Access Journals (Sweden)

    Hu Jia

    2017-06-01

    Full Text Available Air injection in light oil reservoirs has received considerable attention as an effective, improved oil recovery process, based primarily on the success of several projects within the Williston Basin in the United States. The main mechanism of air injection is the oxidation behavior between oxygen and crude oil in the reservoir. Air injection is a good option because of its wide availability and low cost. Whether air injection can be applied to shale is an interesting topic from both economic and technical perspectives. This paper initiates a comprehensive discussion on the feasibility and potential of air injection in shale oil reservoirs based on state-of-the-art literature review. Favorable and unfavorable effects of using air injection are discussed in an analogy analysis on geology, reservoir features, temperature, pressure, and petrophysical, mineral and crude oil properties of shale oil reservoirs. The available data comparison of the historically successful air injection projects with typical shale oil reservoirs in the U.S. is summarized in this paper. Some operation methods to improve air injection performance are recommended. This paper provides an avenue for us to make use of many of the favorable conditions of shale oil reservoirs for implementing air injection, or air huff ‘n’ puff injection, and the low cost of air has the potential to improve oil recovery in shale oil reservoirs. This analysis may stimulate further investigation.

  4. Energy supply strategy: getting technology commercialized, shale oil and enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Steger, J.E.; Sullo, P.; Michaelis, M.; Nason, H.K.

    1979-12-01

    Purpose is to identify factors inhibiting the near-term investment of industrial funds for producing oil from shale and through enhanced oil recovery, and to estimate the investment and production which would result if these deterrents were removed and suitable incentives provided. The barriers are discussed under the following categories: economic, environmental, institutional/regulatory, and technical. (DLC)

  5. Oil Shale

    Science.gov (United States)

    Birdwell, Justin E.

    2017-01-01

    Oil shales are fine-grained sedimentary rocks formed in many different depositional environments (terrestrial, lacustrine, marine) containing large quantities of thermally immature organic matter in the forms of kerogen and bitumen. If defined from an economic standpoint, a rock containing a sufficient concentration of oil-prone kerogen to generate economic quantities of synthetic crude oil upon heating to high temperatures (350–600 °C) in the absence of oxygen (pyrolysis) can be considered an oil shale.

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  9. Method for retorting oil shale

    Science.gov (United States)

    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. Fire and explosion hazards of oil shale

    Energy Technology Data Exchange (ETDEWEB)

    1989-01-01

    The US Bureau of Mines publication presents the results of investigations into the fire and explosion hazards of oil shale rocks and dust. Three areas have been examined: the explosibility and ignitability of oil shale dust clouds, the fire hazards of oil shale dust layers on hot surfaces, and the ignitability and extinguishment of oil shale rubble piles. 10 refs., 54 figs., 29 tabs.

  11. The Supercritical CO2 Huff-n-puff Experiment of Shale Oil Utilizing Isopropanol

    Science.gov (United States)

    Shang, Shengxiang; Dong, Mingzhe; Gong, Houjian

    2018-01-01

    In this study, the supercritical CO2 huff-n-puff experiment of shale oil has been investigated. Experimental data shows that the addition of isopropanol can greatly improve the recovery of shale oil. And this provides a new way to improve the recovery of shale oil. In this paper, it is also tried to analyze the influencing factor of isopropanol on the recovery of shale oil by analyzing the MMP.

  12. 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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  13. BLM Colorado Oil Shale Leases

    Data.gov (United States)

    Department of the Interior — KMZ File Format –This data set contains the Oil Shale Leases for the State of Colorado, derived from Legal Land Descriptions (LLD) contained in the US Bureau of Land...

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

    Energy Technology Data Exchange (ETDEWEB)

    1980-12-01

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

  15. LLNL oil shale project review

    Energy Technology Data Exchange (ETDEWEB)

    Cena, R.J. (ed.)

    1990-04-01

    Livermore's oil shale project is funded by two budget authorities, two thirds from base technology development and one third from environmental science. Our base technology development combines fundamental chemistry research with operation of pilot retorts and mathematical modeling. We've studied mechanisms for oil coking and cracking and have developed a detailed model of this chemistry. We combine the detailed chemistry and physics into oil shale process models (OSP) to study scale-up of generic second generation Hot-Recycled-Solid (HRS) retorting systems and compare with results from our 4 tonne-per-day continuous-loop HRS pilot retorting facility. Our environmental science program focuses on identification of gas, solid and liquid effluents from oil shale processes and development of abatement strategies where necessary. We've developed on-line instruments to quantitatively measure trace sulfur and nitrogen compounds released during shale pyrolysis and combustion. We've studied shale mineralogy, inorganic and organic reactions which generate and consume environmentally sensitive species. Figures, references, and tables are included with each discussion.

  16. Health effects research in oil shale development

    Energy Technology Data Exchange (ETDEWEB)

    Schultz, T.W.; Witschi, H.; Smith, L.H.; Haschek, W.M.; Holland, J.M.; Epler, J.L.; Fry, R.J.M.; Rao, T.K.; Larimer, F.W.; Dumont, J.N.

    1981-11-01

    This task includes the testing of primary effluents and products of oil shales to determine the risk posed to the shale oil industrial worker as well as consumer. Paraho/Sohio Shale Oil was found to be mutagenic in the Ames assay and confirmed in the yeast system. After chemical fractionation of the crude shale oil, it was found that the mutagenic activity was contributed by the organic constituents of the basic and neutral fractions. Hydrotreatment of the shale oil abolished the detectable mutagenic activity and also reduced the cytotoxicity as measured in cellular systems. Refined shale oil, jet fuel, and diesel fuel marine samples were not mutagenic. The samples rank for their mutagenic activity as coal oils > shale oil > natural petroleum crudes and only qualitatively agree with carcinogenic activity. Acute toxicity of Paraho Crude Shale Oil and its upgraded derivatives does not appear to be a problem of immediate concern. The data obtained in the lung adenoma bioassay suggest that Crude Shale Oil has tumorigenic potential. Paraho shale oil is carcinogenic in mouse skin. Hydrotreatment reduces but does not eliminate skin carcinogenicity and appreciable carcinogenic activity remains in the residue material. Kidney injury was noted following chronic dermal exposure to shale and petroleum derived middle distillates.

  17. Shale Oil Value Enhancement Research

    Energy Technology Data Exchange (ETDEWEB)

    James W. Bunger

    2006-11-30

    Raw kerogen oil is rich in heteroatom-containing compounds. Heteroatoms, N, S & O, are undesirable as components of a refinery feedstock, but are the basis for product value in agrochemicals, pharmaceuticals, surfactants, solvents, polymers, and a host of industrial materials. An economically viable, technologically feasible process scheme was developed in this research that promises to enhance the economics of oil shale development, both in the US and elsewhere in the world, in particular Estonia. Products will compete in existing markets for products now manufactured by costly synthesis routes. A premium petroleum refinery feedstock is also produced. The technology is now ready for pilot plant engineering studies and is likely to play an important role in developing a US oil shale industry.

  18. Oil shale, shale oil, shale gas and non-conventional hydrocarbons

    Science.gov (United States)

    Clerici, A.; Alimonti, G.

    2015-08-01

    In recent years there has been a world "revolution" in the field of unconventional hydrocarbon reserves, which goes by the name of "shale gas", gas contained inside clay sediments micropores. Shale gas finds particular development in the United States, which are now independent of imports and see a price reduction to less than one third of that in Europe. With the high oil prices, in addition to the non-conventional gas also "oil shales" (fine-grained sedimentary rocks that contain a large amount of organic material to be used both to be directly burned or to extract liquid fuels which go under the name of shale oil), extra heavy oils and bitumen are becoming an industrial reality. Both unconventional gas and oil reserves far exceed in the world the conventional oil and gas reserves, subverting the theory of fossil fuels scarcity. Values and location of these new fossil reserves in different countries and their production by comparison with conventional resources are presented. In view of the clear advantages of unconventional fossil resources, the potential environmental risks associated with their extraction and processing are also highlighted.

  19. Assessment of potential shale-oil and shale-gas resources in Silurian shales of Jordan, 2014

    Science.gov (United States)

    Schenk, Christopher J.; Pitman, Janet K.; Charpentier, Ronald R.; Klett, Timothy R.; Tennyson, Marilyn E.; Mercier, Tracey J.; Nelson, Philip H.; Brownfield, Michael E.; Pawlewicz, Mark J.; Wandrey, Craig J.

    2014-01-01

    Using a geology-based assessment methodology, the U.S. Geological Survey estimated means of 11 million barrels of potential shale-oil and 320 billion cubic feet of shale-gas resources in Silurian shales of Jordan.

  20. Oil shale, shale oil, shale gas and non-conventional hydrocarbons

    Directory of Open Access Journals (Sweden)

    Clerici A.

    2015-01-01

    Full Text Available In recent years there has been a world “revolution” in the field of unconventional hydrocarbon reserves, which goes by the name of “shale gas”, gas contained inside clay sediments micropores. Shale gas finds particular development in the United States, which are now independent of imports and see a price reduction to less than one third of that in Europe. With the high oil prices, in addition to the non-conventional gas also “oil shales” (fine-grained sedimentary rocks that contain a large amount of organic material to be used both to be directly burned or to extract liquid fuels which go under the name of shale oil, extra heavy oils and bitumen are becoming an industrial reality. Both unconventional gas and oil reserves far exceed in the world the conventional oil and gas reserves, subverting the theory of fossil fuels scarcity. Values and location of these new fossil reserves in different countries and their production by comparison with conventional resources are presented. In view of the clear advantages of unconventional fossil resources, the potential environmental risks associated with their extraction and processing are also highlighted.

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

    Energy Technology Data Exchange (ETDEWEB)

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

    2012-04-30

    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.

  2. Shale Gas and Oil in Germany - Resources and Environmental Impacts

    Science.gov (United States)

    Ladage, Stefan; Blumenberg, Martin; Houben, Georg; Pfunt, Helena; Gestermann, Nicolai; Franke, Dieter; Erbacher, Jochen

    2017-04-01

    In light of the controversial debate on "unconventional" oil and gas resources and the environmental impacts of "fracking", the Federal Institute for Geosciences and Natural Resources (BGR) conducted a comprehensive resource assessment of shale gas and light tight oil in Germany and studied the potential environmental impacts of shale gas development and hydraulic fracturing from a geoscientific perspective. Here, we present our final results (BGR 2016), incorporating the majority of potential shale source rock formations in Germany. Besides shale gas, light tight oil has been assessed. According to our set of criteria - i.e. thermal maturity 0.6-1.2 %vitrinite reflectance (VR; oil) and >1.2 % VR (gas) respectively, organic carbon content > 2%, depth between 500/1000 m and 5000 m as well as a net thickness >20 m - seven potentially generative shale formations were indentified, the most important of them being the Lower Jurassic (Toarcian) Posidonia shale with both shale gas and tight oil potential. The North German basin is by far the most prolific basin. The resource assessment was carried out using a volumetric in-place approach. Variability inherent in the input parameters was accounted for using Monte-Carlo simulations. Technically recoverable resources (TRR) were estimated using recent, production-based recovery factors of North American shale plays and also employing Monte-Carlo simulations. In total, shale gas TRR range between 320 and 2030 bcm and tight oil TRR between 13 and 164 Mio. t in Germany. Tight oil potential is therefore considered minor, whereas the shale gas potential exceeds that of conventional resources by far. Furthermore an overview of numerical transport modelling approaches concerning environmental impacts of the hydraulic fracturing is given. These simulations are based on a representative lithostratigraphy model of the North-German basin, where major shale plays can be expected. Numerical hydrogeological modelling of frac fluid

  3. Environmental control costs for oil shale processes

    Energy Technology Data Exchange (ETDEWEB)

    None

    1979-10-01

    The studies reported herein are intended to provide more certainty regarding estimates of the costs of controlling environmental residuals from oil shale technologies being readied for commercial application. The need for this study was evident from earlier work conducted by the Office of Environment for the Department of Energy Oil Shale Commercialization Planning, Environmental Readiness Assessment in mid-1978. At that time there was little reliable information on the costs for controlling residuals and for safe handling of wastes from oil shale processes. The uncertainties in estimating costs of complying with yet-to-be-defined environmental standards and regulations for oil shale facilities are a critical element that will affect the decision on proceeding with shale oil production. Until the regulatory requirements are fully clarified and processes and controls are investigated and tested in units of larger size, it will not be possible to provide definitive answers to the cost question. Thus, the objective of this work was to establish ranges of possible control costs per barrel of shale oil produced, reflecting various regulatory, technical, and financing assumptions. Two separate reports make up the bulk of this document. One report, prepared by the Denver Research Institute, is a relatively rigorous engineering treatment of the subject, based on regulatory assumptions and technical judgements as to best available control technologies and practices. The other report examines the incremental cost effect of more conservative technical and financing alternatives. An overview section is included that synthesizes the products of the separate studies and addresses two variations to the assumptions.

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

    Energy Technology Data Exchange (ETDEWEB)

    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

  5. Kinetic simulation model for steam pyrolysis of shale oil feedstock

    Energy Technology Data Exchange (ETDEWEB)

    Kavianian, H.R.; Yesavage, V.F.; Dickson, P.F.; Peters, R.W. (Argonne National Lab., Argonne, IL (US))

    1990-04-01

    Steam pyrolysis of shale oil feedstocks for the production of chemical intermediates was studied in a bench-scale tubular reactor. The results have been correlated as a function of temperature, residence time, and pyrolysis severity. The experimental results obtained upon pyrolysis of shale oil indicate that shale oil should make an excellent feedstock for steam pyrolysis.

  6. Organic Substances from Unconventional Oil and Gas Production in Shale

    Science.gov (United States)

    Orem, W. H.; Varonka, M.; Crosby, L.; Schell, T.; Bates, A.; Engle, M.

    2014-12-01

    Unconventional oil and gas (UOG) production has emerged as an important element in the US and world energy mix. Technological innovations in the oil and gas industry, especially horizontal drilling and hydraulic fracturing, allow for the enhanced release of oil and natural gas from shale compared to conventional oil and gas production. This has made commercial exploitation possible on a large scale. Although UOG is enormously successful, there is surprisingly little known about the effects of this technology on the targeted shale formation and on environmental impacts of oil and gas production at the surface. We examined water samples from both conventional and UOG shale wells to determine the composition, source and fate of organic substances present. Extraction of hydrocarbon from shale plays involves the creation and expansion of fractures through the hydraulic fracturing process. This process involves the injection of large volumes of a water-sand mix treated with organic and inorganic chemicals to assist the process and prop open the fractures created. Formation water from a well in the New Albany Shale that was not hydraulically fractured (no injected chemicals) had total organic carbon (TOC) levels that averaged 8 mg/L, and organic substances that included: long-chain fatty acids, alkanes, polycyclic aromatic hydrocarbons, heterocyclic compounds, alkyl benzenes, and alkyl phenols. In contrast, water from UOG production in the Marcellus Shale had TOC levels as high as 5,500 mg/L, and contained a range of organic chemicals including, solvents, biocides, scale inhibitors, and other organic chemicals at thousands of μg/L for individual compounds. These chemicals and TOC decreased rapidly over the first 20 days of water recovery as injected fluids were recovered, but residual organic compounds (some naturally-occurring) remained up to 250 days after the start of water recovery (TOC 10-30 mg/L). Results show how hydraulic fracturing changes the organic

  7. Hydrocarbon distribution in the Irati shale oil

    Energy Technology Data Exchange (ETDEWEB)

    Afonso, J.C.; Schmal, M.; Cardoso, J.N. [Federal University of Rio de Janeiro, Rio de Janeiro (Brazil)

    1994-03-01

    This work reports a detailed characterization of the various hydrocarbon structures present in a sample of the Irati shale oil (Sao Mateus do Sul, Parana), obtained by the Petrosix Process, by means of a combination of gas chromatography-mass spectrometry (g.c.-m.s.), co-injection with authentic standards, and retention time data of model compounds. Hydrocarbon structures, the main constituents of the shale oil ({approximately} 38 wt%), include: linear, branched and isoprenoidal alkanes, linear and isoprenoidal alkenes, alkycyclopentanes and cyclohexanes, alkylcycloalkenes, hopanes, hopenes and steranes. Linear structures are dominant (43% of the total hydrocarbons), followed by isoprenoidal skeletons. Saturated compounds strongly predominate over their unsaturated counterparts. The use of several maturity parameters attested to the immaturity of the sediment. Data further suggested a predominant algal/microbial origin and a basic lacustrine depositional environment to the Irati shale, probably under a moderate oxidative condition, thus confirming previous conclusions obtained via analysis of the Irati bitumen and the shale rock. Additionally, the data confirmed the usual classification of this shale as containing Type-II kerogen. 34 refs., 2 tabs.

  8. Oil shale development and its environmental considerations

    Science.gov (United States)

    Stone, R.T.; Johnson, H.; Decora, A.

    1974-01-01

    The petroleum shortage recently experienced by many nations throughout the world has created an intense interest in obtaining new and supplemental energy sources. In the United States, this interest has been centered on oil shale. Any major action by the federal government having significant environmental effects requires compliance with the National Environmental Policy Act of 1969 (NEPA). Since most oil shale is found on federal lands, and since its development involves significant environmental impacts, leasing oil shale lands to private interests must be in compliance with NEPA. For oil shale, program planning began at approximately the same time that NEPA was signed into law. By structuring the program to permit a resource and technological inventory by industry and the federal agencies, the Department of the Interior was able simultaneously to conduct the environmental assessments required by the act. This required: 1. Clearly defined program objections; 2. An organization which could integrate public policy with diverse scientific disciplines and environmental concerns; and 3. Flexible decisionmaking to adjust to policy changes as well as to evolving interpretations on EPA as clarified by court decisions. This paper outlines the program, the organization structure that was created for this specific task, and the environmental concerns which were investigated. The success of the program has been demonstrated by meeting the requirements of NEPA, without court challenge, and by industry's acceptance of a leasing program that included the most stringent environmental protection provisions ever required. The need for energy development has spurred the acceptance of the program. However, by its awareness and willingness to meet the environmental challenges of the future, industry has shown a reasonable understanding of its commitments. The pros and cons of development were publicly considered in hearings and analyzed in the final environmental statement. This

  9. A Simple Physics-Based Model Predicts Oil Production from Thousands of Horizontal Wells in Shales

    KAUST Repository

    Patzek, Tadeusz

    2017-10-18

    Over the last six years, crude oil production from shales and ultra-deep GOM in the United States has accounted for most of the net increase of global oil production. Therefore, it is important to have a good predictive model of oil production and ultimate recovery in shale wells. Here we introduce a simple model of producing oil and solution gas from the horizontal hydrofractured wells. This model is consistent with the basic physics and geometry of the extraction process. We then apply our model thousands of wells in the Eagle Ford shale. Given well geometry, we obtain a one-dimensional nonlinear pressure diffusion equation that governs flow of mostly oil and solution gas. In principle, solutions of this equation depend on many parameters, but in practice and within a given oil shale, all but three can be fixed at typical values, leading to a nonlinear diffusion problem we linearize and solve exactly with a scaling

  10. Carbon nanotubes (CNT) for enhanced oil production from shales

    OpenAIRE

    Hussain, Aqeel

    2014-01-01

    The shale gas production has brought a revolution in US energy market and the global prospect of shale gas production is on continuous increase. The advancements in hydraulic fracturing made it possible to extract very low permeability shale gas through fracturing the shale rock. The once fractured shale rock is kept open with the induction of spherical particles known as proppants. The performance of proppants is crucial for oil & gas production. Therefore, the prospect of applic...

  11. Pressurized fluidized-bed hydroretorting of Eastern oil shales -- Beneficiation

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Lau, F.S.; Mensinger, M.C. (Institute of Gas Technology, Chicago, IL (United States)); Schultz, C.W.; Mehta, R.K.; Lamont, W.E. (Alabama Univ., University, AL (United States)); Chiang, S.H.; Venkatadri, R. (Pittsburgh Univ., PA (United States)); Misra, M. (Nevada Univ., Reno, NV (United States))

    1992-05-01

    The Mineral Resources Institute at the University of Alabama, along with investigators from the University of Pittsburgh and the University of Nevada-Reno, have conducted a research program on the beneficiation, of Eastern oil shales. The objective of the research program was to evaluate and adapt those new and emerging technologies that have the potential to improve the economics of recovering oil from Eastern oil shales. The technologies evaluated in this program can be grouped into three areas: fine grinding kerogen/mineral matter separation, and waste treatment and disposal. Four subtasks were defined in the area of fine grinding. They were as follows: Ultrasonic Grinding, Pressure Cycle Comminution, Stirred Ball Mill Grinding, and Grinding Circuit Optimization. The planned Ultrasonic grinding research was terminated when the company that had contracted to do the research failed. Three technologies for effecting a separation of kerogen from its associated mineral matter were evaluated: column flotation, the air-sparged hydrocyclone, and the LICADO process. Column flotation proved to be the most effective means of making the kerogen/mineral matter separation. No problems are expected in the disposal of oil shale tailings. It is assumed that the tailings will be placed in a sealed pond and the water recycled to the plant as is the normal practice. It may be advantageous, however, to conduct further research on the recovery of metals as by-products and to assess the market for tailings as an ingredient in cement making.

  12. Analysis of Applicability of Oil Shale for in situ Conversion

    OpenAIRE

    Martemyanov, Sergey Mikhailovich; Bukharkin, Andrey Andreevich; Koryashov, Iliya Aleksandrovich; Ivanov, Aleksey Alekseevich

    2016-01-01

    There are only a few substantial oil shale industries in the world, mainly because of the high cost of oilshale development relative to coal, oil and natural gas. Innovative approaches to oil shale processing could change this situation. Underground (or in situ) conversion could become a very useful technology, once an efficient way is found to prepare oil shale deposits for heating and to transfer heat into them. A new electrophysical method, which uses electrical treeing breakdown and resis...

  13. Chattanooga shale: an assessment of the resource and technology for the recovery of hydrocarbons and minerals

    Energy Technology Data Exchange (ETDEWEB)

    Spiewak, I.; Bomar, E.S.; Butz, T.R.

    1982-04-01

    Chattanooga shale, a large and mineral-rich member of the Devonian oil shales of the Eastern United States, is a resource of about 100 billion bbl of oil, 10 million tons of uranium, and significant quantities of other metals including aluminum, molybdenum, cobalt, columbium, and vanadium. Unlike coal and western oil shale, however, Chattanooga shale is not yet ready for commercial exploitation. The hydrocarbon content, while comparable to that of western shales, is more difficult to extract, and the metals, while generally more varied, are less concentrated than those of resources that are being exploited today. Although this study indicates that a large scale (100,000 tons/day) combined operation for oil and metals recovery appears to be economically attractive, commercial operations are presently impeded by the risks associated with the need for an extremely large capital investment and substantial unknowns with respect to envionmental effects and the methods for mining, processing, and waste disposal. Some of the principal technical problems that require resolution are those of roof stability and water intrusion associated with the underground mining of Chattanooga shale, the need for environmentally acceptable methods for disposal of tremendous quantities of spent shale, and the need for processes that can efficiently recover most of the hydrocarbon and mineral values with minimal loss of expensive processing reagents.

  14. Modeling an oil shale fluid bed combustor

    Energy Technology Data Exchange (ETDEWEB)

    Vasalos, I.A.; Lefkopoulos, A.; Georgiadou, M.

    1988-02-01

    Oil shale retorting involves heating of solid particles and pyrolysis of the organic matter to produce hydrocarbon liquid shale oil. During the pyrolysis process, part of the organic material remains in the inorganic matrix as coke residue. Combustion of the coke residue can provide the energy necessary for retorting. In this paper the use of a fluid bed combustor to burn the coke residue is examined. The basis for predicting the performance of the fluid bed combustor is the application of the two-phase theory of fluidization. The carbon burning efficiency was calculated as a function of temperature, pressure, and bubble size. For the same conditions, the carbonate decomposition and the associated energy loss were also established. Conditions were found which make feasible complete carbon combustion with minimum carbonate decomposition.

  15. Modeling an oil shale fluid bed combustor

    Energy Technology Data Exchange (ETDEWEB)

    Vasalos, I.A.; Lefkopoulos, A.; Georgiadou, M.

    1985-01-01

    Oil shale retorting involves heating of solid particles and pyrolysis of the organic matter to produce hydrocarbon liquid--shale oil. During the pyrolysis process part of the organic material remains in the inorganic matrix as coke residue. Combustion of the coke residue can provide the energy necessary for retorting. In this paper the use of a fluid bed combustor to burn the coke residue is examined. The basis for predicting the performance of the fluid bed combustor is the application of the two-phase theory of fluidization. The carbon burning efficiency was calculated as a function of temperature, pressure, and bubble size. For the same conditions the carbonate decomposition and the associated energy loss was also established.

  16. Oxygen compounds in the Irati Shale oil

    Energy Technology Data Exchange (ETDEWEB)

    Alfonso, J.C.; Schmal, M. (Federal Univ. of Rio de Janeiro, COPPE/EQ/UFRJ, C.P. 68502, 21945 Rio de Janeiro (Brazil)); Cardoso, J.N. (Inst. of Chemistry/UFRJ, Centro de Technologia, Bloco A, Sala A-603, 21901 Rio de Janeiro (Brazil))

    1992-04-01

    This paper reports the principal alkylphenols (4 wt %) and carboxylic acids (1.2 wt %) present in the Irati Shale oil S[tilde a]o Mateus do Sul, Paran acute (a) by means of a combination of gas chromatography-mass spectrometry (GC-MS) and retention time-data of standard compounds. it appears that the phenols are essentially monocyclic in nature with methyl groups as the main substituents. Carboxylic acids are principally linear and predominantly of the range C[sub 14]--C[sub 20]. After catalytic hydrotreatment (400 [degrees]C, 125 atm) high hydrodeoxygenation levels were obtained (87 wt %) for phenols and carboxylic acids, although the relative distribution of the various compounds was not significantly changed. Oxygen is present in the carbonaceous residue as several functionalities xanthenes, phenols, aryl ethers, carbonyl compounds, and furanic structures. The remaining acidic compounds may cause instability of the treated shale oil.

  17. Comparative study on direct burning of oil shale and coal

    Science.gov (United States)

    Hammad, Ahmad; Al Asfar, Jamil

    2017-07-01

    A comparative study of the direct burning processes of oil shale and coal in a circulating fluidized bed (CFB) was done in this study using ANSYS Fluent software to solve numerically the governing equations of continuity, momentum, energy and mass diffusion using finite volume method. The model was built based on an existing experimental combustion burner unit. The model was validated by comparing the theoretical results of oil shale with proved experimental results from the combustion unit. It was found that the temperature contours of the combustion process showed that the adiabatic flame temperature was 1080 K for oil shale compared with 2260 K for coal, while the obtained experimental results of temperatures at various locations of burner during the direct burning of oil shale showed that the maximum temperature reached 962 K for oil shale. These results were used in economic and environmental analysis which show that oil shale may be used as alternative fuel for coal in cement industry in Jordan.

  18. Plan for addressing issues relating to oil shale plant siting

    Energy Technology Data Exchange (ETDEWEB)

    Noridin, J. S.; Donovan, R.; Trudell, L.; Dean, J.; Blevins, A.; Harrington, L. W.; James, R.; Berdan, G.

    1987-09-01

    The Western Research Institute plan for addressing oil shale plant siting methodology calls for identifying the available resources such as oil shale, water, topography and transportation, and human resources. Restrictions on development are addressed: land ownership, land use, water rights, environment, socioeconomics, culture, health and safety, and other institutional restrictions. Descriptions of the technologies for development of oil shale resources are included. The impacts of oil shale development on the environment, socioeconomic structure, water availability, and other conditions are discussed. Finally, the Western Research Institute plan proposes to integrate these topics to develop a flow chart for oil shale plant siting. Western Research Institute has (1) identified relative topics for shale oil plant siting, (2) surveyed both published and unpublished information, and (3) identified data gaps and research needs. 910 refs., 3 figs., 30 tabs.

  19. Introduction to special section: China shale gas and shale oil plays

    Science.gov (United States)

    Jiang, Shu; Zeng, Hongliu; Zhang, Jinchuan; Fishman, Neil; Bai, Baojun; Xiao, Xianming; Zhang, Tongwei; Ellis, Geoffrey S.; Li, Xinjing; Richards-McClung, Bryony; Cai, Dongsheng; Ma, Yongsheng

    2015-01-01

    In the last 10 years, the success of shale gas and shale oil productions as a result of technological advances in horizontal drilling, hydraulic fracturing and nanoscale reservoir characterization have revolutionized the energy landscape in the United States. Resource assessment by the China Ministry of Land and Resources in 2010 and 2012 and by the U.S. Energy Information Administration in 2011 and 2013 indicates China’s shale gas resource is the largest in the world and shale oil resource in China is also potentially significant. Inspired by the success in the United States, China looks forward to replicating the U.S. experience to produce shale gas to power its economy and reduce greenhouse gas emissions. By 2014, China had drilled 400 wells targeting marine, lacustrine, and coastal swamp transitional shales spanning in age from the Precambrian to Cenozoic in the last five years. So far, China is the leading country outside of North America in the viable production of shale gas, with very promising prospects for shale gas and shale oil development, from the Lower Silurian Longmaxi marine shale in Fuling in the southeastern Sichuan Basin. Geological investigations by government and academic institutions as well as exploration and production activities from industry indicate that the tectonic framework, depositional settings, and geomechanical properties of most of the Chinese shales are more complex than many of the producing marine shales in the United States. These differences limit the applicability of geologic analogues from North America for use in Chinese shale oil and gas resource assessments, exploration strategies, reservoir characterization, and determination of optimal hydraulic fracturing techniques. Understanding the unique features of the geology, shale oil and gas resource potential, and reservoir characteristics is crucial for sweet spot identification, hydraulic fracturing optimization, and reservoir performance prediction.

  20. Leaching study of oil shale in Kentucky : with a section on Hydrologic reconnaissance of the oil shale outcrop in Kentucky

    Science.gov (United States)

    Leung, Samuel S.; Leist, D.W.; Davis, R.W.; Cordiviola, Steven

    1984-01-01

    Oil shales in Kentucky are rocks of predominantly Devonian age. The most prominant are the Ohio, Chattanooga, and New Albany Shales. A leaching study was done on six fresh oil shale samples and one retorted oil shale sample. Leaching reagents were distilled water, 0.0005 N sulfuric acid, and 0.05 N sulfuric acid. The concentration of constituents in the leachates were highly variable. The concentration of sodium, manganese, and zinc in the retorted shale leachate was several orders of magnitude higher than those of the leachates of fresh shale samples. The major oil shale outcrop covers approximately 1,000 square miles in a horseshoe pattern from Vanceburg, Lewis County , in the east, to Louisville, Jefferson County, in the west. The Kentucky, Red, and Licking Rivers cross the outcrop belt, the Rolling Fork River flows along the strike of the shale in the southwest part of the outcrop, and the Ohio River flows past the outcrop at the ends of the horseshoe. Oil shale does not appear to significantly alter the water quality of these streams. Oil shale is not an aquifer, but seeps and springs found in the shale indicate that water moves through it. Ground water quality is highly variable. (USGS)

  1. 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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  2. Catalytic gasification of oil-shales

    Energy Technology Data Exchange (ETDEWEB)

    Lapidus, A.; Avakyan, T. [I.M. Gubkin Russian State Univ. of Oil and Gas, Moscow (Russian Federation); Strizhakova, Yu. [Samara State Univ. (Russian Federation)

    2012-07-01

    Nowadays, the problem of complex usage of solid fossil fuels as raw materials for obtaining of motor fuels and chemical products is becoming increasingly important. A one of possible solutions of the problem is their gasification with further processing of gaseous and liquid products. In this work we have investigated the process of thermal and catalytic gasification of Baltic and Kashpir oil-shales. We have shown that, as compared with non-catalytic process, using of nickel catalyst in the reaction increases the yield of gas, as well as hydrogen content in it, and decreases the amount of liquid products. (orig.)

  3. Occidental vertical modified in situ process for the recovery of oil from oil shale. Phase II. Quarterly progress report, September 1, 1980-November 30, 1980

    Energy Technology Data Exchange (ETDEWEB)

    1981-01-01

    The major activities at OOSI's Logan Wash site during the quarter were: mining the voids at all levels for Retorts 7 and 8; blasthole drilling; tracer testing MR4; conducting the start-up and burner tests on MR3; continuing the surface facility construction; and conducting Retorts 7 and 8 related Rock Fragmentation tests. Environmental monitoring continued during the quarter, and the data and analyses are discussed. Sandia National Laboratory and Laramie Energy Technology Center (LETC) personnel were active in the DOE support of the MR3 burner and start-up tests. In the last section of this report the final oil inventory for Retort 6 production is detailed. The total oil produced by Retort 6 was 55,696 barrels.

  4. Current status of the production of chemicals from oil shale

    Energy Technology Data Exchange (ETDEWEB)

    Yesavage, V.F.; Griswold, C.F.; Dickson, P.F.

    1980-08-01

    An alternate use of shale oil is as a feedstock for chemical intermediates (ethylene, propylene, benzene, toluene, and xylene (BTX)) production. The most extensively used method for production of petrochemical intermediates is by steam pyrolysis of a hydrocarbon feed. Steam pyrolysis is generally directed towards maximizing ethylene production while producing other olefins and aromatics as salable by-products. Crude shale oil has a high content of organic nitrogen (2% by weight), which acts as a catalyst poison, contains a large residuum fraction (20 to 50% by weight) and has a high pour point (generally > 40/sup 0/). Thus, it has generally been considered necessary to prerefine crude shale oil to produce a synthetic crude compatible with typical refineries. The prerefinery steps generally consist either of a delayed coking step on the crude shale oil or residuum fraction, followed by one or several hydrogenation steps, or of direct hydrogenation of crude shale oil at more severe conditions. These hydrogenation steps must generally be accomplished under severe operating conditions (750/sup 0/F, 2000 psia hydrogen partial pressure and up to 2000 Scf/bbl hydrogen uptake). Since such severe prerefining of crude shale oil may not be required for the utilization of shale oil as a steam pyrolysis feedstock, use of shale oil as a petrochemical feedstock offers a potential advantage over usage for a refinery feedstock. Studies made by the US Bureau of Mines, the Institute of Gas Technology, and the Colorado School of Mines on the conversion of shale oil to petrochemicals are summarized. A comparison is made between shale oil and petroleum oil pyrolysis. (DMC)

  5. Shale oil specialty markets: Screening survey for United States applications

    Energy Technology Data Exchange (ETDEWEB)

    1987-12-01

    EG and G requested J. E. Sinor Consultants Inc. to carry out an initial screening study on the possibilities for producing specialty chemicals from oil shale. Raw shale oil is not an acceptable feedstock to refineries and there are not enough user of heavy fuel oil in the western oil shale region to provide a dependable market. The only alternatives are to hydrotreat the oil, or else ship it long distances to a larger market area. Either of these alternatives results in a cost penalty of several dollars per barrel. Instead of attempting to enter the large-volume petroleum products market, it was hypothesized that a small shale oil facility might be able to produce specialty chemicals with a high enough average value to absorb the high costs of shipping small quantities to distant markets and still provide a higher netback to the plant site than sales to the conventional petroleum products market. This approach, rather than attempting to refine shale oil or to modify its characteristics to satisfy the specifications for petroleum feedstocks or products, focuses instead on those particular characteristics which distinguish shale oil from petroleum, and attempts to identify applications which would justify a premium value for those distinctive characteristics. Because byproducts or specialty chemicals production has been a prominent feature of oil shale industries which have flourished for periods of time in various countries, a brief review of those industries provides a starting point for this study. 9 figs., 32 tabs.

  6. Assessment of industry needs for oil shale research and development

    Energy Technology Data Exchange (ETDEWEB)

    Hackworth, J.H.

    1987-05-01

    Thirty-one industry people were contacted to provide input on oil shale in three subject areas. The first area of discussion dealt with industry's view of the shape of the future oil shale industry; the technology, the costs, the participants, the resources used, etc. It assessed the types and scale of the technologies that will form the industry, and how the US resource will be used. The second subject examined oil shale R D needs and priorities and potential new areas of research. The third area of discussion sought industry comments on what they felt should be the role of the DOE (and in a larger sense the US government) in fostering activities that will lead to a future commercial US oil shale shale industry.

  7. Paraho Oil Shale Project. [Review of accomplishments of operation of Rifle, Colorado facility since 1973

    Energy Technology Data Exchange (ETDEWEB)

    Pforzheimer, H.

    1976-01-01

    The Paraho Oil Shale Demonstration is a privately financed project sponsored by seventeen participants. The program to demonstrate the Paraho technology on oil shale is being conducted at the Anvil Points Experiment Station of the Energy Research and Development Administration (ERDA). The facility is located on the Naval Oil Shale Reserve near Rifle, Colorado. A $9 million, 34 month, mining, retorting and disposal program is scheduled for completion by mid 1976. A large pilot plant and a semi-works scale plant were erected and put into operation in 1974. Two modes of operation, direct and indirect heating, have been successfully demonstrated. Large scale refining of crude shale oil and retorted shale management experiments have been carried out. The extended retorting demonstration runs on Paraho's cylindrical, vertical shaft kilns have characterized this new technology as environmentally acceptable, with high liquid recovery, high thermal efficiency and low water consumption. The demonstration operations and the outlook for the commercial development of oil shale are discussed.

  8. A Geochemical Method for Determining Heat History of Retorted Shale Oil.

    Science.gov (United States)

    1980-06-01

    porphyrin fraction from oil shale bitumen and the total retorted shale oil. The demetallated porphyrins were separated into etio and phyllo series by silica ...PAGE I. Yield of Porphyrin Fraction from GPC. ..... ...... 9 Il. High Resolution Mass Spectroscopic Results f or Oil Shale Bitumen ...13 Ill. Mass Spectroscopic Data for Shale Oil Bitumen . .. ..... 14 - __ , : , v. =- , . .= 7- , 4 =-- . -.. : -=? - L : T , LIST OF FIGURES

  9. Trace elements in oil shale. Progress report, 1979-1980

    Energy Technology Data Exchange (ETDEWEB)

    Chappell, W R

    1980-01-01

    The purpose of this research program is to understand the potential impact of an oil shale industry on environmental levels of trace contaminants in the region. The program involves a comprehensive study of the sources, release mechanisms, transport, fate, and effects of toxic trace chemicals, principally the trace elements, in an oil shale industry. The overall objective of the program is to evaluate the environmental and health consequences of the release of toxic trace elements by shale and oil production and use. The baseline geochemical survey shows that stable trace elements maps can be constructed for numerous elements and that the trends observed are related to geologic and climatic factors. Shale retorted by above-ground processes tends to be very homogeneous (both in space and in time) in trace element content. Leachate studies show that significant amounts of B, F, and Mo are released from retorted shales and while B and Mo are rapidly flushed out, F is not. On the other hand, As, Se, and most other trace elements are not present in significant quantities. Significant amounts of F and B are also found in leachates of raw shales. Very large concentrations of reduced sulfur species are found in leachates of processed shale. Very high levels of B and Mo are taken up in some plants growing on processed shale with and without soil cover. There is a tendency for some trace elements to associate with specific organic fractions, indicating that organic chelation or complexation may play an important role. Many of the so-called standard methods for analyzing trace elements in oil shale-related materials are inadequate. A sampling manual is being written for the environmental scientist and practicing engineer. A new combination of methods is developed for separating the minerals in oil shale into different density fractions. Microbial investigations have tentatively identified the existence of thiobacilli in oil shale materials such as leachates. (DC)

  10. Multivariate analysis relating oil shale geochemical properties to NMR relaxometry

    Science.gov (United States)

    Birdwell, Justin E.; Washburn, Kathryn E.

    2015-01-01

    Low-field nuclear magnetic resonance (NMR) relaxometry has been used to provide insight into shale composition by separating relaxation responses from the various hydrogen-bearing phases present in shales in a noninvasive way. Previous low-field NMR work using solid-echo methods provided qualitative information on organic constituents associated with raw and pyrolyzed oil shale samples, but uncertainty in the interpretation of longitudinal-transverse (T1–T2) relaxometry correlation results indicated further study was required. Qualitative confirmation of peaks attributed to kerogen in oil shale was achieved by comparing T1–T2 correlation measurements made on oil shale samples to measurements made on kerogen isolated from those shales. Quantitative relationships between T1–T2 correlation data and organic geochemical properties of raw and pyrolyzed oil shales were determined using partial least-squares regression (PLSR). Relaxometry results were also compared to infrared spectra, and the results not only provided further confidence in the organic matter peak interpretations but also confirmed attribution of T1–T2 peaks to clay hydroxyls. In addition, PLSR analysis was applied to correlate relaxometry data to trace element concentrations with good success. The results of this work show that NMR relaxometry measurements using the solid-echo approach produce T1–T2 peak distributions that correlate well with geochemical properties of raw and pyrolyzed oil shales.

  11. Methanogenic archaea in marcellus shale: a possible mechanism for enhanced gas recovery in unconventional shale resources.

    Science.gov (United States)

    Tucker, Yael Tarlovsky; Kotcon, James; Mroz, Thomas

    2015-06-02

    Marcellus Shale occurs at depths of 1.5-2.5 km (5000 to 8000 feet) where most geologists generally assume that thermogenic processes are the only source of natural gas. However, methanogens in produced fluids and isotopic signatures of biogenic methane in this deep shale have recently been discovered. This study explores whether those methanogens are indigenous to the shale or are introduced during drilling and hydraulic fracturing. DNA was extracted from Marcellus Shale core samples, preinjected fluids, and produced fluids and was analyzed using Miseq sequencing of 16s rRNA genes. Methanogens present in shale cores were similar to methanogens in produced fluids. No methanogens were detected in injected fluids, suggesting that this is an unlikely source and that they may be native to the shale itself. Bench-top methane production tests of shale core and produced fluids suggest that these organisms are alive and active under simulated reservoir conditions. Growth conditions designed to simulate the hydrofracture processes indicated somewhat increased methane production; however, fluids alone produced relatively little methane. Together, these results suggest that some biogenic methane may be produced in these wells and that hydrofracture fluids currently used to stimulate gas recovery could stimulate methanogens and their rate of producing methane.

  12. Validation Results for Core-Scale Oil Shale Pyrolysis

    Energy Technology Data Exchange (ETDEWEB)

    Staten, Josh; Tiwari, Pankaj

    2015-03-01

    This report summarizes a study of oil shale pyrolysis at various scales and the subsequent development a model for in situ production of oil from oil shale. Oil shale from the Mahogany zone of the Green River formation was used in all experiments. Pyrolysis experiments were conducted at four scales, powdered samples (100 mesh) and core samples of 0.75”, 1” and 2.5” diameters. The batch, semibatch and continuous flow pyrolysis experiments were designed to study the effect of temperature (300°C to 500°C), heating rate (1°C/min to 10°C/min), pressure (ambient and 500 psig) and size of the sample on product formation. Comprehensive analyses were performed on reactants and products - liquid, gas and spent shale. These experimental studies were designed to understand the relevant coupled phenomena (reaction kinetics, heat transfer, mass transfer, thermodynamics) at multiple scales. A model for oil shale pyrolysis was developed in the COMSOL multiphysics platform. A general kinetic model was integrated with important physical and chemical phenomena that occur during pyrolysis. The secondary reactions of coking and cracking in the product phase were addressed. The multiscale experimental data generated and the models developed provide an understanding of the simultaneous effects of chemical kinetics, and heat and mass transfer on oil quality and yield. The comprehensive data collected in this study will help advance the move to large-scale in situ oil production from the pyrolysis of oil shale.

  13. Assessment of potential unconventional lacustrine shale-oil and shale-gas resources, Phitsanulok Basin, Thailand, 2014

    Science.gov (United States)

    Schenk, Christopher J.; Charpentier, Ronald R.; Klett, Timothy R.; Mercier, Tracey J.; Tennyson, Marilyn E.; Pitman, Janet K.; Brownfield, Michael E.

    2014-01-01

    Using a geology-based assessment methodology, the U.S. Geological Survey assessed potential technically recoverable mean resources of 53 million barrels of shale oil and 320 billion cubic feet of shale gas in the Phitsanulok Basin, onshore Thailand.

  14. Explosive fragmentation of oil shale: Results from Colony and Anvil Points Mines, Colorado

    Energy Technology Data Exchange (ETDEWEB)

    Dick, R.D.; Fourney, W.L. [Maryland Univ., College Park, MD (United States). Dept. of Mechanical Engineering; Young, C. III [Sunburst Recovery, Inc., Steamboat Springs, CO (United States)

    1992-12-31

    From 1978 through 1983, numerous oil shale fragmentation tests were conducted at the Colony and Anvil Points Mines, Colorado. These experiments were part of an investigation to determine factors required for the adequate fragmentation of oil shale and to evaluate the feasibility of using the vertical modified in situ retort (VMIS) method for recovery of kerogen from oil shale. The objective of this research was to support the design of a large volume (10{sup 4} m{sup 3}) rubble bed for in situ processing. In addition, this rubble bed was to be formed in a large single-blast event which included decked charges, time delays, and multiple boreholes. Results are described.

  15. Rehabilitation potential and practices of Colorado oil shale lands

    Energy Technology Data Exchange (ETDEWEB)

    Sims, P.L.; Redente, E.F.

    1977-01-01

    Considering the problems associated with rehabilitating oil shale disturbed lands in Colorado, a research grant was awarded to Colorado State University by US ERDA. The goal of this research program is to define the rehabilitation potential and practices of Colorado Oil Shale lands. Rehabilitation guidelines are presently being formulated through the study of long-term fertility requirements, soil microorganism dynamics and activity, rate and direction of secondary plant succession, and selection and improvement of plant materials.

  16. United States Air Force Shale Oil to Fuels. Phase II.

    Science.gov (United States)

    1981-11-01

    There is no attempt to recover propane , and the light end hydrocarbons are taken to the fuel gas system for feed to the hydrogen plant. Part of the...shale oil charged from the high pressure hydro- treater separator. The hydrotreated shale oil charge stock is combined with the recycle hydrogen rich gas...sulfide and ammonia are steam stripped from the water. The clean water is returned to the refinery and the gas is sent to the amine treater for

  17. Energy Return on Investment (EROI of Oil Shale

    Directory of Open Access Journals (Sweden)

    Peter A. O’Connor

    2011-11-01

    Full Text Available The two methods of processing synthetic crude from organic marlstone in demonstration or small-scale commercial status in the U.S. are in situ extraction and surface retorting. The considerable uncertainty surrounding the technological characterization, resource characterization, and choice of the system boundary for oil shale operations indicate that oil shale is only a minor net energy producer if one includes internal energy (energy in the shale that is used during the process as an energy cost. The energy return on investment (EROI for either of these methods is roughly 1.5:1 for the final fuel product. The inclusions or omission of internal energy is a critical question. If only external energy (energy diverted from the economy to produce the fuel is considered, EROI appears to be much higher. In comparison, fuels produced from conventional petroleum show overall EROI of approximately 4.5:1. “At the wellhead” EROI is approximately 2:1 for shale oil (again, considering internal energy and 20:1 for petroleum. The low EROI for oil shale leads to a significant release of greenhouse gases. The large quantities of energy needed to process oil shale, combined with the thermochemistry of the retorting process, produce carbon dioxide and other greenhouse gas emissions. Oil shale unambiguously emits more greenhouse gases than conventional liquid fuels from crude oil feedstocks by a factor of 1.2 to 1.75. Much of the discussion regarding the EROI for oil shale should be regarded as preliminary or speculative due to the very small number of operating facilities that can be assessed.

  18. Microbial Deterioration of Marine Diesel Fuel from Oil Shale.

    Science.gov (United States)

    1981-04-09

    eesar mnd Identify by block rumlber) Microbial deterioration DFM Cladosporium resinae Oil shale Synthetic fuel *QNjd&Sp. ACoal Fungi Seawater Petroleum...well in the synthetic fuel as in fuel derived from petroleum. Growth of certain strains of the fungus, Cladosporium resinae , was initially... resina ., and a yeast (Candida sp.) but no inhibition was noted with another shale oil fuel from which the nitrogen constituents ware almost completely

  19. Analysis of the environmental control technology for oil shale development

    Energy Technology Data Exchange (ETDEWEB)

    de Nevers, N.; Eckhoff, D.; Swanson, S.; Glenne, B.; Wagner, F.

    1978-02-01

    The environmental control technology proposed in the various oil shale projects which are under development are examined. The technologies for control of air pollution, water pollution, and for the disposal, stabilization, and vegetation of the processed shale were thoroughly investigated. Although some difficulties may be encountered in any of these undertakings, it seems clear that the air and water pollution problems can be solved to meet any applicable standard. There are no published national standards against which to judge the stabilization and vegetation of the processed shale. However, based on the goal of producing an environmentally and aesthetically acceptable finished processed shale pile, it seems probable that this can be accomplished. It is concluded that the environmental control technology is available to meet all current legal requirements. This was not the case before Colorado changed their applicable Air Pollution regulations in August of 1977; the previous ones for the oil shale region were sufficiently stringent to have caused a problem for the current stage of oil shale development. Similarly, the federal air-quality, non-deterioration regulations could be interpreted in the future in ways which would be difficult for the oil shale industry to comply with. The Utah water-quality, non-deterioration regulations could also be a problem. Thus, the only specific regulations which may be a problem are the non-deterioration parts of air and water quality regulations. The unresolved areas of environmental concern with oil shale processing are mostly for the problems not covered by existing environmental law, e.g., trace metals, polynuclear organics, ground water-quality changes, etc. These may be problems, but no evidence is yet available that these problems will prevent the successful commercialization of oil shale production.

  20. Oil shale as an alternative energy source

    Energy Technology Data Exchange (ETDEWEB)

    Hepbasli, A. [Ege University, Izmir (Turkey). Mechanical Engineering Dept.

    2004-02-15

    Oil shale (OS) is one of the world's most important energy resources, and its use can be traced back to ancient times. The objective of this study is to investigate many aspects of OS as an alternative energy source in Turkey, giving Turkey's OS deposits, the history of oil in Turkey, and some studies conducted to evaluate OSs. Research into the utilization of Turkish OSs has been going on since the 1970s, while OSs comprise the second largest solid fuel deposit in Turkey after lignites. OS deposits in Turkey are widely distributed in middle and western Anatolia, with an estimated current reserve of approximately 1,865 million tons. Other potential areas in the north Anatolian fault zone are also under investigation. With the continuing decline of petroleum supplies, accompanied by increasing costs of petroleum-based products, OS may present opportunities for supplying some of Turkey's fossil energy needs in the years ahead. (author)

  1. Processing use, and characterization of shale oil products

    Science.gov (United States)

    Decora, Andrew W.; Kerr, Robert D.

    1979-01-01

    Oil shale is a potential source of oil that will supplement conventional sources for oil as our needs for fossil fuels begin to exceed our supplies. The resource may be mined and processed on the surface or it may be processed in situ. An overview of the potential technologies and environmental issues is presented. PMID:446454

  2. Western Greece unconventional hydrocarbon potential from oil shale and shale gas reservoirs

    Science.gov (United States)

    Karakitsios, Vasileios; Agiadi, Konstantina

    2013-04-01

    It is clear that we are gradually running out of new sedimentary basins to explore for conventional oil and gas and that the reserves of conventional oil, which can be produced cheaply, are limited. This is the reason why several major oil companies invest in what are often called unconventional hydrocarbons: mainly oil shales, heavy oil, tar sand and shale gas. In western Greece exist important oil and gas shale reservoirs which must be added to its hydrocarbon potential1,2. Regarding oil shales, Western Greece presents significant underground immature, or close to the early maturation stage, source rocks with black shale composition. These source rock oils may be produced by applying an in-situ conversion process (ICP). A modern technology, yet unproven at a commercial scale, is the thermally conductive in-situ conversion technology, developed by Shell3. Since most of western Greece source rocks are black shales with high organic content, those, which are immature or close to the maturity limit have sufficient thickness and are located below 1500 meters depth, may be converted artificially by in situ pyrolysis. In western Greece, there are several extensive areas with these characteristics, which may be subject of exploitation in the future2. Shale gas reservoirs in Western Greece are quite possibly present in all areas where shales occur below the ground-water level, with significant extent and organic matter content greater than 1%, and during their geological history, were found under conditions corresponding to the gas window (generally at depths over 5,000 to 6,000m). Western Greece contains argillaceous source rocks, found within the gas window, from which shale gas may be produced and consequently these rocks represent exploitable shale gas reservoirs. Considering the inevitable increase in crude oil prices, it is expected that at some point soon Western Greece shales will most probably be targeted. Exploration for conventional petroleum reservoirs

  3. Western oil shale development: a technology assessment. Volume 8. Health effects of oil shale development

    Energy Technology Data Exchange (ETDEWEB)

    Rotariu, G.J.

    1982-02-01

    Information on the potential health effects of a developing oil shale industry can be derived from two major sources: (1) the historical experience in foreign countries that have had major industries; and (2) the health effects research that has been conducted in the US in recent years. The information presented here is divided into two major sections: one dealing with the experience in foreign countries and the second dealing with the more recent work associated with current oil shale development in the US. As a result of the study, several observations can be made: (1) most of the current and historical data from foreign countries relate to occupational hazards rather than to impacts on regional populations; (2) neither the historical evidence from other countries nor the results of current research have shown pulmonary neoplasia to be a major concern, however, certain types of exposure, particularly such mixed source exposures as dust/diesel or dust/organic-vapor have not been adequately studied and the lung cancer question is not closed; (3) the industry should be alert to the incidence of skin disease in the industrial setting, however, automated techniques, modern industrial hygiene practices and realistic personal hygiene should greatly reduce the hazards associated with skin contact; and (4) the entire question of regional water contamination and any resultant health hazard has not been adequately addressed. The industrial practice of hydrotreating the crude shale oil will diminish the carcinogenic hazard of the product, however, the quantitative reduction of biological activity is dependent on the degree of hydrotreatment. Both Soviet and American experimentalists have demonstrated a correlation betweed carcinogenicity/toxicity and retorting temperature; the higher temperatures producing the more carcinogenic or toxic products.

  4. Occidental vertical modified in situ process for the recovery of oil from oil shale, Phase 2. Construction, operation, testing, and environmental impact. Final report, August 1981-December 1982. Volume 1

    Energy Technology Data Exchange (ETDEWEB)

    Stevens, A.L.; Zahradnik, R.L.; Kaleel, R.J.

    1984-01-01

    Occidential Oil Shale, Inc. (OOSI) recently completed the demonstration of mining, rubblization, ignition, and simulataneous processing of two commericalized modified in situ (MIS) retorts at the Logas Wash facility near DeBeque, Colorado. Upon completion of Retort 6 in 1978, Occidential began incorporating all of the knowledge previously acquired in an effort to design two more commercial-sized MIS retorts. Any commercial venture of the future would require the ability to operate simultaneously more than one retort. Thus, Retorts 7 and 8 were developed during 1980 and 1981 through joint funding of the DOE and OOSI in Phase II. Rubblization of the retorts produced an average rubble void of 18.5% in the low grade shale (17 gallons per ton) at the Logan Wash site. After rubblization, bulkheads were constructed, inlet and offgas pipes were installed and connected to surface processing facilities and liquid product handling systems were connected to the retorts. Extensive instrumentation was installed in cooperation with Sandia National Laboratories for monitoring the complete operation of the retorts. After pre-ignition testing, Retort 8 was ignited in December of 1981 and Retort 7 was ignited in January of 1982. The retorts were operated without interruption from ignition until mid- November of 1982 at which time inlet gas injection was terminated and water quenching was begun. Total product yield from the two retorts was approximately 200,000 barrels of oil, or 70% of the Fischer Assay oil-in-place in the rubblized rock in the two retrots. Water quenching studies were conducted over a period of several months, with the objective of determining the rate of heat extraction from the retorts as well as determining the quantity and quality of offgas and water coming out from the quenching process. Data from these studies are also included in this Summary Report. 62 figs., 18 tabs.

  5. A Transversely Isotropic Thermo-mechanical Framework for Oil Shale

    Science.gov (United States)

    Semnani, S. J.; White, J. A.; Borja, R. I.

    2014-12-01

    The present study provides a thermo-mechanical framework for modeling the temperature dependent behavior of oil shale. As a result of heating, oil shale undergoes phase transformations, during which organic matter is converted to petroleum products, e.g. light oil, heavy oil, bitumen, and coke. The change in the constituents and microstructure of shale at high temperatures dramatically alters its mechanical behavior e.g. plastic deformations and strength, as demonstrated by triaxial tests conducted at multiple temperatures [1,2]. Accordingly, the present model formulates the effects of changes in the chemical constituents due to thermal loading. It is well known that due to the layered structure of shale its mechanical properties in the direction parallel to the bedding planes is significantly different from its properties in the perpendicular direction. Although isotropic models simplify the modeling process, they fail to accurately describe the mechanical behavior of these rocks. Therefore, many researchers have studied the anisotropic behavior of rocks, including shale [3]. The current study presents a framework to incorporate the effects of transverse isotropy within a thermo-mechanical formulation. The proposed constitutive model can be readily applied to existing finite element codes to predict the behavior of oil shale in applications such as in-situ retorting process and stability assessment in petroleum reservoirs. [1] Masri, M. et al."Experimental Study of the Thermomechanical Behavior of the Petroleum Reservoir." SPE Eastern Regional/AAPG Eastern Section Joint Meeting. Society of Petroleum Engineers, 2008. [2] Xu, B. et al. "Thermal impact on shale deformation/failure behaviors---laboratory studies." 45th US Rock Mechanics/Geomechanics Symposium. American Rock Mechanics Association, 2011. [3] Crook, AJL et al. "Development of an orthotropic 3D elastoplastic material model for shale." SPE/ISRM Rock Mechanics Conference. Society of Petroleum Engineers

  6. Cyclone oil shale retorting concept. [Use it all retorting process

    Energy Technology Data Exchange (ETDEWEB)

    Harak, A.E.; Little, W.E.; Faulders, C.R.

    1984-04-01

    A new concept for above-ground retorting of oil shale was disclosed by A.E. Harak in US Patent No. 4,340,463, dated July 20, 1982, and assigned to the US Department of Energy. This patent titled System for Utilizing Oil Shale Fines, describes a process wherein oil shale fines of one-half inch diameter and less are pyrolyzed in an entrained-flow reactor using hot gas from a cyclone combustor. Spent shale and supplemental fuel are burned at slagging conditions in this combustor. Because of fines utilization, the designation Use It All Retorting Process (UIARP) has been adopted. A preliminary process engineering design of the UIARP, analytical tests on six samples of raw oil shale, and a preliminary technical and economic evaluation of the process were performed. The results of these investigations are summarized in this report. The patent description is included. It was concluded that such changes as deleting air preheating in the slag quench and replacing the condenser with a quench-oil scrubber are recognized as being essential. The addition of an entrained flow raw shale preheater ahead of the cyclone retort is probably required, but final acceptance is felt to be contingent on some verification that adequate reaction time cannot be obtained with only the cyclone, or possibly some other twin-cyclone configuration. Sufficient raw shale preheating could probably be done more simply in another manner, perhaps in a screw conveyor shale transporting system. Results of the technical and economic evaluations of Jacobs Engineering indicate that further investigation of the UIARP is definitely worthwhile. The projected capital and operating costs are competitive with costs of other processes as long as electric power generation and sales are part of the processing facility.

  7. La rivoluzione dello shale oil e i mercati finanziari (The Shale Oil Revolution and Financial Markets

    Directory of Open Access Journals (Sweden)

    Alessandro Roncaglia

    2017-07-01

    Full Text Available Shale oil exhibits structural characteristics that set it apart from ‘traditional’ oil, such as the shorter time required to build new plants, the shorter duration of the investment, and a lower ratio of fixed to variable costs. These differences imply a lower degree of oligopolistic control of the market, which in the medium term could lead to further downward pressure on prices. However, the high degree of financialization of these markets makes it a necessary condition, for such a regime change to materialize, that financial market operators internalize new behavioural and procedural conventions, adapted to the changed technological scenario. JEL codes: L13, L71, Q41

  8. Assessment of undiscovered shale gas and shale oil resources in the Mississippian Barnett Shale, Bend Arch–Fort Worth Basin Province, North-Central Texas

    Science.gov (United States)

    Marra, Kristen R.; Charpentier, Ronald R.; Schenk, Christopher J.; Lewan, Michael D.; Leathers-Miller, Heidi M.; Klett, Timothy R.; Gaswirth, Stephanie B.; Le, Phuong A.; Mercier, Tracey J.; Pitman, Janet K.; Tennyson, Marilyn E.

    2015-12-17

    Using a geology-based assessment methodology, the U.S. Geological Survey estimated mean volumes of 53 trillion cubic feet of shale gas, 172 million barrels of shale oil, and 176 million barrels of natural gas liquids in the Barnett Shale of the Bend Arch–Fort Worth Basin Province of Texas.

  9. Clean and Secure Energy from Domestic Oil Shale and Oil Sands Resources

    Energy Technology Data Exchange (ETDEWEB)

    Spinti, Jennifer [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Birgenheier, Lauren [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Deo, Milind [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Facelli, Julio [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Hradisky, Michal [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Kelly, Kerry [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Miller, Jan [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); McLennan, John [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Ring, Terry [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Ruple, John [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States); Uchitel, Kirsten [Inst. for Clean and Secure Energy, Salt Lake City, UT (United States)

    2015-09-30

    This report summarizes the significant findings from the Clean and Secure Energy from Domestic Oil Shale and Oil Sands Resources program sponsored by the Department of Energy through the National Energy Technology Laboratory. There were four principle areas of research; Environmental, legal, and policy issues related to development of oil shale and oil sands resources; Economic and environmental assessment of domestic unconventional fuels industry; Basin-scale assessment of conventional and unconventional fuel development impacts; and Liquid fuel production by in situ thermal processing of oil shale Multiple research projects were conducted in each area and the results have been communicated via sponsored conferences, conference presentations, invited talks, interviews with the media, numerous topical reports, journal publications, and a book that summarizes much of the oil shale research relating to Utah’s Uinta Basin. In addition, a repository of materials related to oil shale and oil sands has been created within the University of Utah’s Institutional Repository, including the materials generated during this research program. Below is a listing of all topical and progress reports generated by this project and submitted to the Office of Science and Technical Information (OSTI). A listing of all peer-reviewed publications generated as a result of this project is included at the end of this report; Geomechanical and Fluid Transport Properties 1 (December, 2015); Validation Results for Core-Scale Oil Shale Pyrolysis (February, 2015); and Rates and Mechanisms of Oil Shale Pyrolysis: A Chemical Structure Approach (November, 2014); Policy Issues Associated With Using Simulation to Assess Environmental Impacts (November, 2014); Policy Analysis of the Canadian Oil Sands Experience (September, 2013); V-UQ of Generation 1 Simulator with AMSO Experimental Data (August, 2013); Lands with Wilderness Characteristics, Resource Management Plan Constraints, and Land Exchanges

  10. Slow Radio-Frequency Processing of Large Oil Shale Volumes to Produce Petroleum-Like Shale Oil

    Energy Technology Data Exchange (ETDEWEB)

    Burnham, A K

    2003-08-20

    A process is proposed to convert oil shale by radio frequency heating over a period of months to years to create a product similar to natural petroleum. Electrodes would be placed in drill holes, either vertical or horizontal, and a radio frequency chosen so that the penetration depth of the radio waves is of the order of tens to hundreds of meters. A combination of excess volume production and overburden compaction drives the oil and gas from the shale into the drill holes, where it is pumped to the surface. Electrical energy for the process could be provided initially by excess regional capacity, especially off-peak power, which would generate {approx}3 x 10{sup 5} bbl/day of synthetic crude oil, depending on shale grade. The electricity cost, using conservative efficiency assumptions, is $4.70 to $6.30/bbl, depending on grade and heating rate. At steady state, co-produced gas can generate more than half the electric power needed for the process, with the fraction depending on oil shale grade. This would increase production to 7.3 x 10{sup 5} bbl/day for 104 l/Mg shale and 1.6 x 10{sup 6} bbl/day for 146 l/Mg shale using a combination of off-peak power and power from co-produced gas.

  11. Pressurized fluidized-bed hydroretorting of Eastern oil shales

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Mensinger, M.C.; Rue, D.M.; Lau, F.S. (Institute of Gas Technology, Chicago, IL (United States)); Schultz, C.W. (Alabama Univ., University, AL (United States)); Parekh, B.K. (Kentucky Univ., Lexington, KY (United States)); Misra, M. (Nevada Univ., Reno, NV (United States)); Bonner, W.P. (Tennessee Technological Univ., Cookeville, TN (United States))

    1992-11-01

    The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the multi-year program, initiated in October 1987 by the US Department of Energy is to perform the research necessary to develop the Pressurized Fluidized-Bed Hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The results of the original 3-year program, which was concluded in May 1991, have been summarized in a four-volume final report published by IGT. DOE subsequently approved a 1-year extension to the program to further develop the PFH process specifically for application to beneficiated shale as feedstock. Studies have shown that beneficiated shale is the preferred feedstock for pressurized hydroretorting. The program extension is divided into the following active tasks. Task 3. testing of process improvement concepts; Task 4. beneficiation research; Task 5. operation of PFH on beneficiated shale; Task 6. environmental data and mitigation analyses; Task 7. sample procurement, preparation, and characterization; and Task 8. project management and reporting. In order to accomplish all the program objectives, the Institute of Gas Technology (IGT), the prime contractor, worked with four other institutions: the University of Alabama/Mineral Resources Institute (MRI), the University of Kentucky Center for Applied Energy Research (UK-CAER), the University of Nevada (UN) at Reno, and Tennessee Technological University (TTU). This report presents the work performed during the program extension from June 1, 1991 through May 31, 1992.

  12. Oil shale hydro cracking; Hidrocraqueamento de oleo de xisto

    Energy Technology Data Exchange (ETDEWEB)

    Silva, M.I.P. da; Souza, G.L.M. de; Schmal, M. [Universidade Federal, Rio de Janeiro, RJ (Brazil). Coordenacao dos Programas de Pos-graduacao de Engenharia

    1984-12-31

    Diesel production from alternative feedstocks becomes increasingly important as our country struggles to reduce oil imports. This paper reports on the development of a catalytic hydro treatment process, aimed at the cracking of heavy oils derived from shale oil with a Co Mo/Al{sub 2} O{sub 3} catalyst. A significant increase of yield in diesel with respect to the load was observed. Temperature seemed to exert the greatest influence over the process. (author). 2 figs., 8 refs., 6 tabs

  13. Oil shale research and coordination. Progress report, 1980-1981

    Energy Technology Data Exchange (ETDEWEB)

    Chappell, W R

    1981-01-01

    Purpose is to evaluate the environmental and health consequences of the release of toxic trace elements by an oil shale industry. Emphasis is on the five elements As, Mo, F, Se, and B. Results of four years' research are summarized and the research results over the past year are reported in this document. Reports by the task force are included as appendices, together with individual papers on various aspects of the subject topic. Separate abstracts were prepared for the eleven individual papers. A progress report on the IWG oil shale risk analysis is included at the end of this document. (DLC)

  14. Executive summary. Western oil shale developmet: a technology assessment

    Energy Technology Data Exchange (ETDEWEB)

    1981-11-01

    The objectives are to review shale oil technologies as a means of supplying domestically produced fuels within environmental, social, economic, and legal/institutional constraints; using available data, analyses, and experienced judgment, to examine the major points of uncertainty regarding potential impacts of oil shale development; to resolve issues where data and analyses are compelling or where conclusions can be reached on judgmental grounds; to specify issues which cannot be resolved on the bases of the data, analyses, and experienced judgment currently available; and when appropriate and feasible, to suggest ways for the removal of existing uncertainties that stand in the way of resolving outstanding issues.

  15. Trace elements in oil shale. Progress report, 1976--1979

    Energy Technology Data Exchange (ETDEWEB)

    Chappell, W.R.

    1979-01-01

    The overall objective of the program is to evaluate the environmental and health consequences of the release of toxic trace elements (As, B, F, Mo, Se) by shale oil production and use. Some of the particularly significant results are: The baseline geochemical survey shows that stable trace elements maps can be constructed for numerous elements and that the trends observed are related to geologic and climatic factors. Shale retorted by above-ground processes tends to be very homogeneous (both in space and in time) in trace element content. This implies that the number of analytical determinations required of processed shales is not large. Leachate studies show that significant amounts of B, F, And Mo are released from retorted shales and while B and Mo are rapidly flushed out, F is not. On the other hand, As, Se, and most other trace elements ae not present in significant quantities. Significant amounts of F and B are also found in leachates of raw shales. Very large concentrations of reduced sulfur species are found in leachates of processed shale. Upon oxidation a drastic lowering in pH is observed. Preliminary data indicates that this oxidation is catalyzed by bacteria. Very high levels of B and Mo are taken up in some plants growing on processed shale with and without soil cover. These amounts depend upon the process and various site specific characteristics. In general, the amounts taken up decrease with increasing soil cover. On the other hand, we have not observed significant uptake of As, Se, and F into plants. There is a tendency for some trace elements to associate with specific organic fractions, indicating that organic chelation or complexation may play an important role. In particular, most of the Cd, Se, and Cr in shale oil is associated with the organic fraction containing most of the nitrogen-containing compounds.

  16. Organic geochemical characterization of Aleksinac oil shale deposit (Serbia)

    Science.gov (United States)

    Gajica, Gordana; Kašanin-Grubin, Milica; Šajnović, Aleksandra; Stojanović, Ksenija; Kostić, Aleksandar; Jovančićević, Branimir

    2016-04-01

    Oil shales represent a good source of energy and industrial raw material. The Aleksinac oil shale deposit is the biggest and most important oil shale deposit in Serbia. It covers an area of over 20 km2, and it has three fields: "Dubrava", "Morava" and "Logorište". The potential reserves of oil shale in the Aleksinac deposit are estimated at about 2.1 billion tons. The genesis of oil shales is associated with the lacustrine depositional environments, which existed from Upper to Lower Miocene. In order to determine the generative potential, type of organic matter (OM) and thermal maturity, Rock-Eval pyrolysis was used. In analyzed oil shale samples the content of total organic carbon (TOC), as a general indicator of petroleum generation potential, range from 1.48 to 29.57%. The content of naturally generated hydrocarbons, expressed as S1 peak from the Rock-Eval pyrolysis in most analyzed samples have extremely low values 0.002-0.28, which indicate low maturity level [1]. The pyrolysable hydrocarbons expressed as S2 peak from the Rock-Eval pyrolysis, represent the potential to generate hydrocarbons and with that the potential of oil generation through thermal decomposition of kerogen. S2 ranging 3.93-141.36 mg HC/g rock is higher than 20 mg HC/g rock and indicates excellent source rock potential [1]. In order to accept a formation as a source rock, it should exhibit TOC more than 0.5 % and sufficient maturity, but also OM types should be suitable for the oil and gas generation. The kerogen type is determined by Hydrogen Index (HI) and diagram HI vs. Tmax (temperature, corresponding to S2 peak maximum). HI in range 265-728 mg HC/g TOC, indicates Type I and Type II kerogen or their mixture i.e. oil prone kerogen [1], whereas only one sample appears to be oil/gas prone (Type II/III). Similar results are obtained by plotting the Tmax against HI. Maturation degree depends on the overall thermal history of the evaluated rocks; it is very important parameter for evaluation

  17. Rapid estimation of organic nitrogen in oil shale wastewaters

    Energy Technology Data Exchange (ETDEWEB)

    Jones, B.M.; Harris, G.J.; Daughton, C.G.

    1984-03-01

    Many of the characteristics of oil shale process wastewaters (e.g., malodors, color, and resistance to biotreatment) are imparted by numerous nitrogen heterocycles and aromatic amines. For the frequent performance assessment of waste treatment procsses designed to remove these nitrogenous organic compounds, a rapid and colligative measurement of organic nitrogen is essential.

  18. Trace metal emissions from the Estonian oil shale fired power

    DEFF Research Database (Denmark)

    Aunela-Tapola, Leena A.; Frandsen, Flemming; Häsänen, Erkki K.

    1998-01-01

    Emission levels of selected trace metals from the Estonian oil shale fired power plant were studied. The plant is the largest single power plant in Estonia with an electricity production capacity of 1170 MWe (1995). Trace metals were sampled from the flue gases by a manual method incorporating...

  19. Ground disposal of oil shale wastes: a review with an indexed annotated bibliography through 1976

    Energy Technology Data Exchange (ETDEWEB)

    Routson, R.C.; Bean, R.M.

    1977-12-01

    This review covers the available literature concerning ground-disposed wastes and effluents of a potential oil shale industry. Ground disposal has been proposed for essentially all of the solid and liquid wastes produced (Pfeffer, 1974). Since an oil shale industry is not actually in operation, the review is anticipatory in nature. The section, Oil Shale Technology, provides essential background for interpreting the literature on potential shale oil wastes and the topics are treated more completely in the section entitled Environmental Aspects of the Potential Disposal of Oil Shale Wastes to Ground. The first section of the annotated bibliography cites literature concerning potential oil shale wastes and the second section cites literature concerning oil shale technology. Each section contains references arranged historically by year. An index is provided.

  20. Perform research in process development for hydroretorting of Eastern oil shales: Volume 2, Expansion of the Moving-Bed Hydroretorting Data Base for Eastern oil shales

    Energy Technology Data Exchange (ETDEWEB)

    1989-11-01

    An extensive data base was developed for six Eastern oil shales: Alabama Chattanooga, Indiana New Albany, Kentucky Sunbury, Michigan Antrim, Ohio Cleveland, and Tennessee Chattanooga shales. The data base included the hydroretorting characteristics of the six shales, as well as the retorting characteristics in the presence of synthesis gas and ionized gas. Shale gasification was also successfully demonstrated. Shale fines (20%) can produce enough hydrogen for the hydroretorting of the remaining 80% of the shale. The amount of fines tolerable in a moving bed was also determined. 16 refs., 59 figs., 43 tabs.

  1. The Alberta Taciuk Processor (ATP System) for direct thermal processing of oil sands, oil shales and heavy oil

    Energy Technology Data Exchange (ETDEWEB)

    Rojek, L.; Odut, S. [AECOM Canada, UMATAC Industrial Processes Division, Calgary, AB (Canada)

    2009-07-01

    This presentation provided an overview of the Alberta Taciuk Processor (ATP) which improves oil recovery, reduces water use and eliminates the needs for tailings ponds that are commonly used in water based oil sand extraction processes. ATP technology has been used successfully to extract and upgrade bitumens and heavy oils. Mineable oil sands are directly processed using ATP technology to pipelineable, low viscosity crude oil. This presentation focused on major scale up achievements of the past decade and processability of the oil products. The ATP process uses a solid heat carrier in a rotating process vessel to thermally crack the hydrocarbons. The ATP also produces much of its own fuel, thereby minimizing the need to import natural gas. The UMATAC division of AECOM Canada maintains test facilities in Calgary which include a 5 ton per hour portable ATP unit. This unit has processed more than 15,000 tons of various grades of oil feeds. It is capable of processing about 60 bbl/day. The technology has also been adapted to processing oil shales in Australia and China. The increased demand for this technology can be attributed to growing environmental concerns regarding water consumption and phased elimination of tailings ponds. It was concluded that the ATP system provides a viable technology to meet these challenges with improved environmental performance. tabs., figs.

  2. Anvil Points oil shale tailings management in Rifle, Colorado

    Energy Technology Data Exchange (ETDEWEB)

    Rudy, R.; Galli LaBerge, C.; McClurg, J. [Ecology and Environment Inc., Lancaster, NY (United States); Walsh Integrated, Lachine, PQ (Canada)

    2009-07-01

    This presentation summarized the oil shale tailings management program used at the Anvil Points mining site in Colorado. Decommissioning and reclamation of the site occurred between 1984 and 1986. The geology of the region is comprised of Tertiary bedrock sedimentary formations and Quaternary formations on the surface. Oil shales mined at the facility are from the Eocene Green River formation. While the site lies within big game winter ranges, the areas around the shale pile supports are not a significant nesting or feeding habitat for wildlife. No sensitive plants are located on the waste shale pile. The program currently includes revegetation test plots and the reclamation of an area where heating oil storage tanks were located. The dumping area is currently being monitored, and geophysical surveys are being conducted. Documents produced by mining activities are also being reviewed. Results of the study to date have indicated the presence of asbestos-containing materials, significant physical hazards, and significant cultural resources. An engineering evaluation and cost analysis has demonstrated that arsenic, beryllium, and iron exceed established soil screening levels. It was concluded that off-site removal actions will be conducted to prevent or reduce human exposure to the metals of concern. tabs., figs.

  3. Wet separation processes as method to separate limestone and oil shale

    Science.gov (United States)

    Nurme, Martin; Karu, Veiko

    2015-04-01

    Biggest oil shale industry is located in Estonia. Oil shale usage is mainly for electricity generation, shale oil generation and cement production. All these processes need certain quality oil shale. Oil shale seam have interlayer limestone layers. To use oil shale in production, it is needed to separate oil shale and limestone. A key challenge is find separation process when we can get the best quality for all product types. In oil shale separation typically has been used heavy media separation process. There are tested also different types of separation processes before: wet separation, pneumatic separation. Now oil shale industry moves more to oil production and this needs innovation methods for separation to ensure fuel quality and the changes in quality. The pilot unit test with Allmineral ALLJIG have pointed out that the suitable new innovation way for oil shale separation can be wet separation with gravity, where material by pulsating water forming layers of grains according to their density and subsequently separates the heavy material (limestone) from the stratified material (oil shale)bed. Main aim of this research is to find the suitable separation process for oil shale, that the products have highest quality. The expected results can be used also for developing separation processes for phosphorite rock or all others, where traditional separation processes doesn't work property. This research is part of the study Sustainable and environmentally acceptable Oil shale mining No. 3.2.0501.11-0025 http://mi.ttu.ee/etp and the project B36 Extraction and processing of rock with selective methods - http://mi.ttu.ee/separation; http://mi.ttu.ee/miningwaste/

  4. Utilization of shale oil as a feedstock for steam pyrolysis and petrochemical intermediate production. Final report

    Energy Technology Data Exchange (ETDEWEB)

    Dickson, P.F.; Yesavage, V.F.

    1979-09-01

    The major objectives of this study were to determine the effects of prerefining on product yields for steam pyrolysis of a shale oil feed and to determine the suitability of shale oil as a petrochemical feedstock. The results of this research program have in general been highly successful. A bench scale pyrolysis reactor was designed and constructed which was used to obtain yield data for variable operating conditions in the range typically employed commercially. Two crude shale oils were used in this study, a Tosco II shale oil as an example of above ground retorting and simulated in-situ shale oil as an example of in-situ processing. Each crude oil was processed to four different levels of prerefining: vacuum distillation and hydrogenation of the vacuum distillate at three levels of severity. A total of 112 experimental runs have been performed on the 10 shale oil samples. An initial comparison of shale oil with petroleum feedstocks indicates that yields of all major gaseous components for shale oil feedstocks are comparable with yields for petroleum fractions with the exception of ethylene. Yields of ethylene are in general considerably higher for the shale oil feedstocks than for typical petroleum feedstocks. A tendency for severely hydrogenated samples to gasify is at present the major qualification to the potential advantages of using shale oil as a petrochemical feedstock. To more fully define the sutiability of shale oil and prerefined shale oil as petrochemical feedstocks more thorough investigation of the liquid products is essential. A preliminary kinetics model was developed which consists of a reaction of feed shale oil to primary products, with subsequent reaction of these products to secondary products.

  5. Upgrading of western shale oil by hydropyrolysis and hydrotreating

    Energy Technology Data Exchange (ETDEWEB)

    Bunger, J.W.; Russell, C.P.; Jeong, Soon-Yong; Pu, J.

    1992-07-01

    A proof-of-concept study for a new shale oil upgrading and refining process was undertaken. This project is aimed at reducing upgrading costs, thereby malting shale oil development more feasible for commercialization. Raw shale oil was topped to remove the most volatile components. The topped shale oil was distilled into three narrow boiling cuts, representing of 175--275{degrees}C, 275--365{degrees}C, and 365--455{degrees}C, and a residue portion (>455{degrees}C). The distillate cuts were used to study molecular weight effects, and the residue was used to test the performance of hydropyrolysis. Hydropyrolysis converts the heavy residue into lower boiling point materials which can be more easily hydrotreated. In the experiment to test molecular weight effects, it was found that geometric hindrance accounts for the inhibition effect. Diffusion limitation and inhibition by competitive adsorption are not strong effects. These results imply that there is no process substitute for the requirement of molecular weight reduction. In the experiment to test the performance of hydropyrolysis, average molecular weight is reduced from 495 to 359 at moderate severities. In HDN of the hydropyrolized residue, however, high process severities are still required to remove nitrogen to the level of refinery-acceptable-feed (< 0.15 wt %). Based on experimental data, the product slate is 1.9 wt % gas, 13.1 wt % gasoline, 27.3 wt % kerosene, 55.6 wt % total gas oil, 1.3 wt % vacuum residue, and 0.8 wt % coke with 1376 scf/bbl total hydrogen consumption. The removal of sulfur is 96%, and that of nitrogen is 84%. The concentration of sulfur in the final product is 0.038 wt %, and that of nitrogen in final product is 0.26%. The conversion of heavy residue to atmospheric distillate is 47%. However, the remaining residue is partially upgraded as a refinery feed.

  6. Soil stabilization using oil shale solid wastes: Laboratory evaluation of engineering properties

    Energy Technology Data Exchange (ETDEWEB)

    Turner, J.P.

    1991-01-01

    Oil shale solid wastes were evaluated for possible use as soil stabilizers. A laboratory study was conducted and consisted of the following tests on compacted samples of soil treated with water and spent oil shale: unconfined compressive strength, moisture-density relationships, wet-dry and freeze-thaw durability, and resilient modulus. Significant increases in strength, durability, and resilient modulus were obtained by treating a silty sand with combusted western oil shale. Moderate increases in strength, durability, and resilient modulus were obtained by treating a highly plastic clay with combusted western oil shale. Solid waste from eastern shale can be used for soil stabilization if limestone is added during combustion. Without limestone, eastern oil shale waste exhibits little or no cementation. The testing methods, results, and recommendations for mix design of spent shale-stabilized pavement subgrades are presented. 11 refs., 3 figs., 10 tabs.

  7. Oil Shale Development from the Perspective of NETL's Unconventional Oil Resource Repository

    Energy Technology Data Exchange (ETDEWEB)

    Smith, M.W. (REM Engineering Services, Morgantown, WV); Shadle, L.J.; Hill, D. (REM Engineering Services, Morgantown, WV)

    2007-01-01

    The history of oil shale development was examined by gathering relevant research literature for an Unconventional Oil Resource Repository. This repository contains over 17,000 entries from over 1,000 different sources. The development of oil shale has been hindered by a number of factors. These technical, political, and economic factors have brought about R&D boom-bust cycles. It is not surprising that these cycles are strongly correlated to market crude oil prices. However, it may be possible to influence some of the other factors through a sustained, yet measured, approach to R&D in both the public and private sectors.

  8. Two-step processing of oil shale to linear hydrocarbons

    Energy Technology Data Exchange (ETDEWEB)

    Eliseev, O.L.; Ryzhov, A.N.; Latypova, D.Zh.; Lapidus, A.L. [Russian Academy of Sciences, Moscow (Russian Federation). N.D. Zelinsky Institute of Organic Chemistry; Avakyan, T.A. [Gubkin Russian State University of Oil and Gas, Moscow (Russian Federation)

    2013-11-01

    Thermal and catalytic steam reforming of oil shale mined from Leningrad and Kashpir deposits was studied. Experiments were performed in fixed bed reactor by varying temperature and steam flow rate. Data obtained were approximated by empirical formulas containing some parameters calculated by least-squares method. Thus predicting amount of hydrogen, carbon monoxide and methane in producer gas is possible for given particular kind of oil shale, temperature and steam flow rate. Adding Ni catalyst enriches hydrogen and depletes CO content in effluent gas at low gasification temperatures. Modeling gas simulating steam reforming gases (H{sub 2}, CO, CO{sub 2}, and N{sub 2} mixture) was tested in hydrocarbon synthesis over Co-containing supported catalyst. Selectivity of CO conversion into C{sub 5+} hydrocarbons reaches 84% while selectivity to methane is 7%. Molecular weight distribution of synthesized alkanes obeys Anderson-Schulz-Flory equation and chain growth probability 0.84. (orig.)

  9. Fluidized-bed pyrolysis of oil shale: oil yield, composition, and kinetics

    Energy Technology Data Exchange (ETDEWEB)

    Richardson, J H; Huss, E B; Ott, L L; Clarkson, J E; Bishop, M O; Taylor, J R; Gregory, L J; Morris, C J

    1982-09-01

    A quartz isothermal fluidized-bed reactor has been used to measure kinetics and oil properties relevant to surface processing of oil shale. The rate of oil formation has been described with two sequential first-order rate equations characterized by two rate constants, k/sub 1/ = 2.18 x 10/sup 10/ exp(-41.6 kcal/RT) s/sup -1/ and k/sub 2/ = 4.4 x 10/sup 6/ exp(-29.7 kcal/RT) s/sup -1/. These rate constants together with an expression for the appropriate weighting coefficients describe approximately 97/sup +/% of the total oil produced. A description is given of the results of different attempts to mathematically describe the data in a manner suitable for modeling applications. Preliminary results are also presented for species-selective kinetics of methane, ethene, ethane and hydrogen, where the latter is clearly distinguished as the product of a distinct intermediate. Oil yields from Western oil shale are approximately 100% Fischer assay. Oil composition is as expected based on previous work and the higher heating rates (temperatures) inherent in fluidized-bed pyrolysis. Neither the oil yield, composition nor the kinetics varied with particle size between 0.2 and 2.0 mm within experimental error. The qualitatively expected change in oil composition due to cracking was observed over the temperature range studied (460 to 540/sup 0/C). Eastern shale exhibited significantly faster kinetics and higher oil yields than did Western shale.

  10. Paraho oil shale module. Site development plan, Task 4

    Energy Technology Data Exchange (ETDEWEB)

    1981-10-01

    A management plan and schedule which covers all requirements for gaining access to the site and for conducting a Paraho Process demonstration program have been prepared. The oil shale available should represent a regional resource of suitable size and quality for commercial development. Discussed in this report are: proof of ownership; requirements for rights-of-way for access to the site; local zoning restrictions; water rights; site availability verification; and other legal requirements. (DMC)

  11. Disposal of mine water from a deep oil shale mine

    Energy Technology Data Exchange (ETDEWEB)

    Sinor, J.E.

    1977-01-01

    A number of options were examined for the disposal of excess water from a deep room and pillar oil-shale mine. High fluoride levels in the water will prevent direct discharge. Evaporation via sprinkler irrigation was the least expensive option but could provide only limited capacity. Defluoridation via ion exchange was technically feasible but expensive. Reinjection into the major producing aquifer was the preferred solution. Computer simulations showed limited pressure effects due to reinjection.

  12. Revegetation research on oil shale lands in the Piceance Basin

    Energy Technology Data Exchange (ETDEWEB)

    Redente, E.F.; Cook, C.W.

    1981-02-01

    The overall objective of this project is to study the effects of various reclamation practices on above- and belowground ecosystem development associated with disturbed oil shale lands in northwestern Colorado. Plant growth media that are being used in field test plots include retorted shale, soil over retorted shale, subsoil materials, and surface disturbed topsoils. Satisfactory stands of vegetation failed to establish on unleached retorted shale during two successive years of seeding. All seedings with soil over retorted shale were judged to be successful at the end of three growing seasons, but deep-rooted shrubs that depend upon subsoil moisture may have their growth hampered by the retorted shale substrate. Natural revegetation on areas with various degrees of disturbance shows that natural invasion and succession was slow at best. Invasion of species on disturbed topsoil plots showed that after three years introduced seed mixtures were more effective than native mixtures in occupying space and closing the community to invading species. Fertilizer appears to encourage the invasion of annual plants even after the third year following application. Long-term storage of topsoil without vegetation significantly decreases the mycorrhizal infection potential and, therefore, decreases the relative success of aboveground vegetation and subsequent succession. Ecotypic differentation related to growth and competitive ability, moisture stress tolerance, and reproductive potential have been found in five native shrub species. Germplasm sources of two grasses and two legumes, that have shown promise as revegetation species, have been collected and evaluated for the production of test seed. Fertilizer (nitrogen) when added to the soil at the time of planting may encourage competition from annual weeds to the detriment of seeded species.

  13. Oil Shale: History, Incentives, and Policy

    Science.gov (United States)

    2006-04-13

    refining processes. The catalytic - cracking process developed during the World War II era enabled refineries to produce high-octane gasolines needed...for the war effort. Hydrocracking, which entered commercial operation in 1958, improved on catalytic - cracking by adding hydrogen to convert residuum...and light coker gas-oil ( cracked residuum). Diesel fuel can be blended from naphtha , kerosene, and light cracked -oils from coker CRS-5 15

  14. The chemistry which created Green River Formation oil shale

    Energy Technology Data Exchange (ETDEWEB)

    Smith, J.W.

    1983-02-01

    The genesis pattern presented for Green River Formation oil shale explains the major observation. Deposition of relatively large quantities of hydrogen-rich organic matter in the oil shales is a natural consequence of the chemical conditions (basic water and reducing atmosphere) and the physical limitation of clastic materials developed in the stratified ancient Lake Uinta. Stability of the stratification produced the continuous deposition of the organic matter and its uniformity over the deposit. Authigenic formation of the oil-shale minerals proceeds naturally from the lake stratification, and the varve production stems from the seasonable development of organic matter. The lake's stratification produced uniform deposition over the entire area it covered, making the correlatable lateral persistence of the thin laminations a natural consequence. As the lake developed, the attack on aluminosilicates by sodium carbonate in the lake's lower layer produced a silicate skeleton protected by aluminum trihydroxide. On deposition, this aluminum-rich skeleton formed illite in quantity. As the lake became more basic, the protecting aluminum hydroxide coating dissolved amphoterically and illite production dropped at a specific point. Continual build-up of sodium carbonate and aluminate ion in the water of the lake's lower layer reached conditions which

  15. Chemistry which created Green River Formation oil shale

    Energy Technology Data Exchange (ETDEWEB)

    Smith, J.W.

    1983-01-01

    The genesis pattern presented for Green River Formation oil shale explains the major observation. Deposition of relatively large quantities of hydrogen-rich organic matter in the oil shales is a natural consequence of the chemical conditions (basic water and reducing atmosphere) and the physical limitation of clastic materials developed in the stratified ancient Lake Uinta. Stability of the stratification produced the continuous deposition of the organic matter and its uniformity over the deposit. Authigenic formation of the oil-shale minerals proceeds naturally from the lake stratification, and the varve production stems from the seasonable development of organic matter. The lake's stratification produced uniform deposition over the entire area it covered, making the correlatable lateral persistence of the thin laminations a natural consequence. As the lake developed, the attack on aluminosilicates by sodium carbonate in the lower layer produced a silicate skeleton protected by aluminum trihydroxide. On deposition, this aluminum-rich skeleton formed illite in quantity. As the lake became more basic, the protecting aluminum hydroxide coating dissolved amphoterically and illite production dropped at a specific point. Continual build-up of sodium carbonate and aluminate ion in the water of the lake's lower layer reached conditions which precipitated dawsonite and crystallized nahcolite in the sediment as a result of CO/sub 2/ production from organic matter. (JMT)

  16. Proof-of-Concept Oil Shale Facility Environmental Analysis Program

    Energy Technology Data Exchange (ETDEWEB)

    1990-11-01

    The objectives of the Project are to demonstrate: (1) the Modified In- Situ (MIS) shale oil extraction process and (2) the application of CFBC technology using oil shale, coal and waste gas streams as fuels. The project will focus on evaluating and improving the efficiency and environmental performance of these technologies. The project will be modest by commercial standards. A 17-retort MIS system is planned in which two retorts will be processed simultaneously. Production of 1206-barrels per calendar day of raw shale oil and 46-megawatts of electricity is anticipated. West Virginia University coordinated an Environmental Analysis Program for the Project. Experts from around the country were retained by WVU to prepare individual sections of the report. These experts were exposed to all of OOSI`s archives and toured Tract C-b and Logan Wash. Their findings were incorporated into this report. In summary, no environmental obstacles were revealed that would preclude proceeding with the Project. One of the most important objectives of the Project was to verify the environmental acceptability of the technologies being employed. Consequently, special attention will be given to monitoring environmental factors and providing state of the art mitigation measures. Extensive environmental and socioeconomic background information has been compiled for the Tract over the last 15 years and permits were obtained for the large scale operations contemplated in the late 1970`s and early 1980`s. Those permits have been reviewed and are being modified so that all required permits can be obtained in a timely manner.

  17. Oil production by vacuum pyrolysis of Canadian oil shales and fate of the biological markers

    Energy Technology Data Exchange (ETDEWEB)

    Pakdel, H.; Roy, C.; Kalkreuth, W. [Institut Pyrovac Inc., Quebec, PQ (Canada)

    1999-02-01

    A bench-scale experiment study was undertaken to investigate the potential of vacuum pyrolysis for the production of oil from Carboniferous-age oil shales from New Brunswick and Nova Scotia. Vacuum pyrolysis limits the secondary decomposition reactions, which as a result provides a high yield of pyrolysis oil and a low yield of gas. The objectives of this study were: (1) to determine the optimum pyrolysis conditions for the production of pyrolysis oil; (2) to study the influence of reaction conditions on the nature of the oil; (3) to correlate the oil composition with the organic source material; and (4) to gain some insight into the kerogen decomposition. Batches of 120 g oil shale samples sieved to 1-5 mm particle size were heated to 600{degree}C and 1 kPa total pressure. The oil yield varied in the range of 10-20 wt% depending on the type of oil shale pyrolyzed. These oil yields are significantly higher than yields obtained by other industrial processes. The major pyrolysis gases generated during pyrolysis were CO{sub 2} (the most abundant), CO, H{sub 2}, CH{sub 4} and C{sub 2}-C{sub 4} hydrocarbons. The pyrolysis shale oils were deasphalted and yielded about 60-80 wt% maltene. n-Alkanes with biomodal distribution in the range of C{sub 8}-C{sub 34} were found in maltene fractions. The maltene fraction of a lamosite pyrolysis shale oil from New Brunswick was analyzed in detail. The analytical results were interpreted in terms of biological markers including n-alkanes, 2-alkylthiophenes, 2-alkylketones and triterpenoid hopanes. The soluble organic matter in the samples analyzed was found to be from a mixture of terrestrial and aquatic origins deposited in a lacustrine environment. 36 refs., 7 figs., 4 tabs.

  18. Joint DoD/DoE Shale Oil Project. Volume 3. Testing of Refined Shale Oil Fuels.

    Science.gov (United States)

    1983-12-01

    16-14 TABLE 16-6. RESPONSE OF SELENASTRUM CAPRICORNUTUM AND MICROCYSTIS AERUGINOSA TO WATER-SOLUBLE FRACTIONS OF COAL...oxidation process in uresence of an oxidation inhibitor. d. Evaluation of the compatibility of oil shale JP-5 with polymeric elastomers, :~o?; sulfide sealants...thrive by the reduction of sulfate to sulfides , which accelerates corrosion in storage tanks and fuel handling systems and S generates particulate

  19. Depositional Environment of the Sangkarewang Oil Shale, Ombilin Basin, Indonesia

    Directory of Open Access Journals (Sweden)

    Komang Anggayana

    2014-12-01

    Full Text Available Five samples from 56 m long drill core of lacustrine Sangkarewang oil shale have been studied by means of petrography and organic geochemistry to investigate the organic matter composition and depositional environments of the shale. The organic matter consists of abundant lamalginite (30%, v/v and very limited amount of vitrinite, suggesting aquatic depositional environments with minor terrestrial influence. Organic geochemical analysis exhibits the dominance of pristane, phytane, and generally n-alkanes compounds. These compounds might originate mostly from aquatic photosynthetic organisms. The oil shale was likely deposited in anoxic lake environments, suggested by the presence of framboidal pyrite (6%, v/v and preserved organic matter with total organic carbon (TOC about 4.9%. The pristane/phytane ratio is relatively high about 3.9 and thought as source sensitive rather than redox sensitive. Hopanoid and aryl isoprenoid compounds are present in minor amounts. The latter compounds are interpreted to be derived from green sulfur bacteria dwelling in anoxic and the presence of H2S in bottom water.

  20. Prospect of shale gas recovery enhancement by oxidation-induced rock burst

    Directory of Open Access Journals (Sweden)

    Lijun You

    2017-11-01

    Full Text Available By horizontal well multi-staged fracturing technology, shale rocks can be broken to form fracture networks via hydraulic force and increase the production rate of shale gas wells. Nonetheless, the fracturing stimulation effect may be offset by the water phase trapping damage caused by water retention. In this paper, a technique in transferring the negative factor of fracturing fluid retention into a positive factor of changing the gas existence state and facilitating shale cracking was discussed using the easy oxidation characteristics of organic matter, pyrite and other minerals in shale rocks. Furthermore, the prospect of this technique in tackling the challenges of large retention volume of hydraulic fracturing fluid in shale gas reservoirs, high reservoir damage risks, sharp production decline rate of gas wells and low gas recovery, was analyzed. The organic matter and pyrite in shale rocks can produce a large number of dissolved pores and seams to improve the gas deliverability of the matrix pore throats to the fracture systems. Meanwhile, in the oxidation process, released heat and increased pore pressure will make shale rock burst, inducing expansion and extension of shale micro-fractures, increasing the drainage area and shortening the gas flowing path in matrix, and ultimately, removing reservoir damage and improving gas recovery. To sum up, the technique discussed in the paper can be used to “break” shale rocks via hydraulic force and to “burst” shale rocks via chemical oxidation by adding oxidizing fluid to the hydraulic fracturing fluid. It can thus be concluded that this method can be a favorable supplementation for the conventional hydraulic fracturing of shale gas reservoirs. It has a broad application future in terms of reducing costs and increasing profits, maintaining plateau shale gas production and improving shale gas recovery.

  1. Aerobic microbial enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Torsvik, T. [Univ. of Bergen (Norway); Gilje, E.; Sunde, E.

    1995-12-31

    In aerobic MEOR, the ability of oil-degrading bacteria to mobilize oil is used to increase oil recovery. In this process, oxygen and mineral nutrients are injected into the oil reservoir in order to stimulate growth of aerobic oil-degrading bacteria in the reservoir. Experiments carried out in a model sandstone with stock tank oil and bacteria isolated from offshore wells showed that residual oil saturation was lowered from 27% to 3%. The process was time dependent, not pore volume dependent. During MEOR flooding, the relative permeability of water was lowered. Oxygen and active bacteria were needed for the process to take place. Maximum efficiency was reached at low oxygen concentrations, approximately 1 mg O{sub 2}/liter.

  2. The Potential of Ketungau and Silat Shales in Ketungau and Melawi Basins, West Kalimantan: For Oil Shale and Shale Gas Exploration

    Directory of Open Access Journals (Sweden)

    Lauti Dwita Santy

    2014-07-01

    Full Text Available DOI: 10.17014/ijog.v8i1.154The Ketungau and Melawi Basins, in West Kalimantan, are Tertiary intramontane basins of which the potential for economic conventional oil and gas discoveries have not previously been confirmed. The Ketungau Basin is bordered by the Melawi Basin in the south. Besides non-ideal trapping mechanisms, another major problem in these basins is source rock maturation. Nevertheless, both basins are promising to be explored for oil shale and shale gas energy resources. Therefore, the aim of this paper is to give some perspectives on their source rocks, as an input for the evaluation of the potential of unconventional oil and gas. About twenty samples collected from the Ketungau and Melawi Basins were analyzed using pyrolysis and organic petrographic methods. The results show a poor to good quality of source rock potential. The Ketungau shale, which is the main source rock in the Ketungau Basin, is dominated by type III, immature, and gas prone kerogen. The Silat shale, which is the main source rock in the Melawi Basin, is dominated by type II, immature to early mature, mixed gas, and oil prone kerogen. In the field, Ketungau and Silat Formations have a widespread distribution, and are typically 900 m to 1000 m thick. Both the Ketungau and Silat shales occur within synclinal structures, which have a poor trapping mechanism for conventional oil or gas targets, but are suitable for oil shale and shale gas exploration. This early stage of research clearly shows good potential for the future development of unconventional energy within the Ketungau and Melawi Basins.

  3. Primary oil-shale resources of the Green River Formation in the eastern Uinta Basin, Utah

    Energy Technology Data Exchange (ETDEWEB)

    Trudell, L.G.; Smith, J.W.; Beard, T.N.; Mason, G.M.

    1983-04-01

    Resources of potential oil in place in the Green River Formation are measured and estimated for the primary oil-shale resource area east of the Green River in Utah's Uinta Basin. The area evaluated (Ts 7-14 S, Rs 19-25 E) includes most of, and certainly the best of Utah's oil-shale resource. For resource evaluation the principal oil-shale section is divided into ten stratigraphic units which are equivalent to units previously evaluated in the Piceance Creek Basin of Colorado. Detailed evaluation of individual oil-shale units sampled by cores, plus estimates by extrapolation into uncored areas indicate a total resource of 214 billion barrels of shale oil in place in the eastern Uinta Basin.

  4. Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, April, May, June 1980

    Energy Technology Data Exchange (ETDEWEB)

    Hutchinson, D.L.

    1980-08-01

    The Retort No. 18 burn was terminated on May 11, 1980. A total of 5547 barrels of shale oil or 46 percent of in-place resource was recovered from the retort. The EPA-DOE/LETC post-burn core sampling program is underway on Retort No. 16. Eleven core holes (of 18 planned) have been completed to date. Preliminary results indicate excellent core recovery has been achieved. Recovery of 702 ft of core was accomplished. The Prevention of Significant Deterioration (PSD) permit application was submitted to the EPA regional office in Denver for review by EPA and Utah air quality officials. The application for an Underground Injection Control (UIC) permit to authorize GKI to inject retort wastewater into the Mesa Verde Formation is being processed by the State of Utah. A hearing before the Board of Oil, Gas and Mining is scheduled in Salt Lake City, Utah, for July 22, 1980. Re-entry drilling on Retort No. 24 is progressing and placement of surface equipment is underway. Retort No. 25 blasthole drilling was completed and blast preparations are ongoing. Retort No. 25 will be blasted on July 18, 1980. The retort will be similar to Retort No. 24, with improvements in blasthole loading and detonation. US Patent No. 4,205,610 was assigned to GKI for a shale oil recovery process. Rocky Mountain Energy Company (RME) is evaluating oil shale holdings in Wyoming for application of the GKI process there.

  5. Proof-of-Concept Oil Shale Facility Environmental Analysis Program

    Energy Technology Data Exchange (ETDEWEB)

    1990-11-01

    The objectives of the Project are to demonstrate: (1) the Modified In- Situ (MIS) shale oil extraction process and (2) the application of CFBC technology using oil shale, coal and waste gas streams as fuels. The project will focus on evaluating and improving the efficiency and environmental performance of these technologies. The project will be modest by commercial standards. A 17-retort MIS system is planned in which two retorts will be processed simultaneously. Production of 1206-barrels per calendar day of raw shale oil and 46-megawatts of electricity is anticipated. West Virginia University coordinated an Environmental Analysis Program for the Project. Experts from around the country were retained by WVU to prepare individual sections of the report. These experts were exposed to all of OOSI's archives and toured Tract C-b and Logan Wash. Their findings were incorporated into this report. In summary, no environmental obstacles were revealed that would preclude proceeding with the Project. One of the most important objectives of the Project was to verify the environmental acceptability of the technologies being employed. Consequently, special attention will be given to monitoring environmental factors and providing state of the art mitigation measures. Extensive environmental and socioeconomic background information has been compiled for the Tract over the last 15 years and permits were obtained for the large scale operations contemplated in the late 1970's and early 1980's. Those permits have been reviewed and are being modified so that all required permits can be obtained in a timely manner.

  6. Oil shale derived pollutant control materials and methods and apparatuses for producing and utilizing the same

    Science.gov (United States)

    Boardman, Richard D.; Carrington, Robert A.

    2010-05-04

    Pollution control substances may be formed from the combustion of oil shale, which may produce a kerogen-based pyrolysis gas and shale sorbent, each of which may be used to reduce, absorb, or adsorb pollutants in pollution producing combustion processes, pyrolysis processes, or other reaction processes. Pyrolysis gases produced during the combustion or gasification of oil shale may also be used as a combustion gas or may be processed or otherwise refined to produce synthetic gases and fuels.

  7. Jet Fuel Looks to Shale Oil: 1980 Technology Review.

    Science.gov (United States)

    1981-05-01

    Potential Yields from Phases I and II BASlS: 100,0W 11po IN SITU SHALE OIL Yield Estimate, Net Volume Percent Products Phase I Phase It Propane 0.6 2.8...proprietary catalysts for use in the various catalytic processing units. Main hydro- treater catalyst aging tests were performed. A six-month run...104 45.0 104 45.0 104 45.0 DIST. HYDROTREATER, MBPSD 25 31.5 28 34.4 25 31.5 HCL TREATER , MBPSD 74 2.4 61 2.3 74 2.4 HYDROCRACKER 9 ATM. DISNT., MBPSD

  8. Hydrotreatment of Irati shale oil; Behavior of the aromatic fraction

    Energy Technology Data Exchange (ETDEWEB)

    Afonso, J.C.; Schmal, M. (Federal Univ. of Rio de Janeiro, COPPE/EQ/UFRJ, C.P. 68502, 21945 Rio de Janeiro (BR)); Cardoso, J.N. (Inst. of Chemistry/UFRJ, Centro de Tecnologia, bloco A, Sala A-603, 21910 Rio de Janeiro (BR)); Frety, R. (Inst. de Recherches sur la Catalyse, CNRS, 2 Avenue Albert Einstein, 69626 Villeurbanne Cedex (FR))

    1991-09-01

    This paper presents the chemical transformations that occur in the aromatic fraction of Irati shale oil under rather drastic hydrotreating conditions, at 400{degrees} C and 125 atm, using a commercial Ni-Mo/Al{sub 2}O{sub 3} catalyst in sulfided form. The aromatic fraction was analyzed before and after reaction by gas chromatography/ mass spectrometry. Several compounds were identified by using this method. The main reactions are the partial hydrogenation of the aromatic rings forming hydroaromatic compounds and the cracking of the lateral alkyl chains. Hydrotreatment leads to a more complex aromatic fraction due to the formation of new compounds.

  9. Inflation and government indecisiveness: key deterrents to significant shale oil production by 1985

    Energy Technology Data Exchange (ETDEWEB)

    1976-10-01

    This work examines the progress of the shale oil industry in its efforts to achieve production of synthetic crude oil from oil shale on a profitable, commercial basis. A projection is made regarding the ability of the shale oil industry to produce 1,000,000 bbl of synthetic crude oil by 1985. That year was chosen because of the long lead time required to obtained leases; to acquire investment capital; to gain approval of environmental impact documents; and to acquire the equipment and construct plants of sufficient magnitude to be economically feasible. 31 references.

  10. Retardation effect of nitrogen compounds and condensed aromatics on shale oil catalytic cracking processing and their characterization

    OpenAIRE

    Li, Nan; Chen, Chen; Wang, Bin; Li, Shaojie; Yang, Chaohe; Chen, Xiaobo

    2015-01-01

    Untreated shale oil, shale oil treated with HCl aqueous solution and shale oil treated with HCl and furfural were used to do comparative experiments in fixed bed reactors. Nitrogen compounds and condensed aromatics extracted by HCl and furfural were characterized by electrospray ionization Fourier transform cyclotron resonance mass spectrometry and gas chromatography and mass spectrometry, respectively. Compared with untreated shale oil, the conversion and yield of liquid products increased c...

  11. Effect of mineral matter and phenol in supercritical extraction of oil shale with toluene

    Science.gov (United States)

    Abourriche, A.; Ouman, M.; Ichcho, S.; Hannache, H.; Pailler, R.; Naslain, R.; Birot, M.; Pillot, J.-P.

    2005-03-01

    In the present work, Tarfaya oil shale was subjected to supercritical toluene extraction. The experimental results obtained show clearly that the mineral matter and phenol have a significant effect on the yield and the composition of the obtained oil.

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

    Energy Technology Data Exchange (ETDEWEB)

    1982-01-01

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

  13. Volume 9: A Review of Socioeconomic Impacts of Oil Shale Development WESTERN OIL SHALE DEVELOPMENT: A TECHNOLOGY ASSESSMENT

    Energy Technology Data Exchange (ETDEWEB)

    Rotariu, G. J.

    1982-02-01

    The development of an oil shale industry in northwestern Colorado and northeastern Utah has been forecast at various times since early this century, but the comparatively easy accessibility of other oil sources has forestalled development. Decreasing fuel supplies, increasing energy costs, and the threat of a crippling oil embargo finally may launch a commercial oil shale industry in this region. Concern for the possible impacts on the human environment has been fostered by experiences of rapid population growth in other western towns that have hosted energy resource development. A large number of studies have attempted to evaluate social and economic impacts of energy development and to determine important factors that affect the severity of these impacts. These studies have suggested that successful management of rapid population growth depends on adequate front-end capital for public facilities, availability of housing, attention to human service needs, long-range land use and fiscal planning. This study examines variables that affect the socioeconomic impacts of oil shale development. The study region is composed of four Colorado counties: Mesa, Moffat, Garfield and Rio Blanco. Most of the estimated population of 111 000 resides in a handful of urban areas that are separated by large distances and rugged terrain. We have projected the six largest cities and towns and one planned company town (Battlement Mesa) to be the probable centers for potential population impacts caused by development of an oil shale industry. Local planners expect Battlement Mesa to lessen impacts on small existing communities and indeed may be necessary to prevent severe regional socioeconomic impacts. Section II describes the study region and focuses on the economic trends and present conditions in the area. The population impacts analyzed in this study are contingent on a scenario of oil shale development from 1980-90 provided by the Department of Energy and discussed in Sec. III. We

  14. Rapid estimation of organic nitrogen in oil shale waste waters

    Energy Technology Data Exchange (ETDEWEB)

    Jones, B.M.; Daughton, C.G.; Harris, G.J.

    1984-04-01

    Many of the characteristics of oil shale process waste waters (e.g., malodors, color, and resistance to biotreatment) are imparted by numerous nitrogenous heterocycles and aromatic amines. For the frequent performance assessment of waste treatment processes designed to remove these nitrogenous organic compounds, a rapid and colligative measurement of organic nitrogen is essential. Quantification of organic nitrogen in biological and agricultural samples is usually accomplished using the time-consuming, wet-chemical Kjeldahl method. For oil shale waste waters, whose primary inorganic nitorgen constituent is amonia, organic Kjeldahl nitrogen (OKN) is determined by first eliminating the endogenous ammonia by distillation and then digesting the sample in boiling H/sub 2/SO/sub 4/. The organic material is oxidized, and most forms of organically bound nitrogen are released as ammonium ion. After the addition of base, the ammonia is separated from the digestate by distillation and quantified by acidimetric titrimetry or colorimetry. The major failings of this method are the loss of volatile species such as aliphatic amines (during predistillation) and the inability to completely recover nitrogen from many nitrogenous heterocycles (during digestion). Within the last decade, a new approach has been developed for the quantification of total nitrogen (TN). The sample is first combusted, a

  15. Eastern gas shales bibliography selected annotations: gas, oil, uranium, etc. Citations in bituminous shales worldwide

    Energy Technology Data Exchange (ETDEWEB)

    Hall, V.S. (comp.)

    1980-06-01

    This bibliography contains 2702 citations, most of which are annotated. They are arranged by author in numerical order with a geographical index following the listing. The work is international in scope and covers the early geological literature, continuing through 1979 with a few 1980 citations in Addendum II. Addendum I contains a listing of the reports, well logs and symposiums of the Unconventional Gas Recovery Program (UGR) through August 1979. There is an author-subject index for these publications following the listing. The second part of Addendum I is a listing of the UGR maps which also has a subject-author index following the map listing. Addendum II includes several important new titles on the Devonian shale as well as a few older citations which were not found until after the bibliography had been numbered and essentially completed. A geographic index for these citations follows this listing.

  16. Pressurized fluidized-bed hydroretorting of Eastern oil shales -- Sulfur control

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Abbasian, J.; Akin, C.; Lau, F.S.; Maka, A.; Mensinger, M.C.; Punwani, D.V.; Rue, D.M. (Institute of Gas Technology, Chicago, IL (United States)); Gidaspow, D.; Gupta, R.; Wasan, D.T. (Illinois Inst. of Tech., Chicago, IL (United States)); Pfister, R.M.: Krieger, E.J. (Ohio State Univ., Columbus, OH (United States))

    1992-05-01

    This topical report on Sulfur Control'' presents the results of work conducted by the Institute of Gas Technology (IGT), the Illinois Institute of Technology (IIT), and the Ohio State University (OSU) to develop three novel approaches for desulfurization that have shown good potential with coal and could be cost-effective for oil shales. These are (1) In-Bed Sulfur Capture using different sorbents (IGT), (2) Electrostatic Desulfurization (IIT), and (3) Microbial Desulfurization and Denitrification (OSU and IGT). The objective of the task on In-Bed Sulfur Capture was to determine the effectiveness of different sorbents (that is, limestone, calcined limestone, dolomite, and siderite) for capturing sulfur (as H{sub 2}S) in the reactor during hydroretorting. The objective of the task on Electrostatic Desulfurization was to determine the operating conditions necessary to achieve a high degree of sulfur removal and kerogen recovery in IIT's electrostatic separator. The objectives of the task on Microbial Desulfurization and Denitrification were to (1) isolate microbial cultures and evaluate their ability to desulfurize and denitrify shale, (2) conduct laboratory-scale batch and continuous tests to improve and enhance microbial removal of these components, and (3) determine the effects of processing parameters, such as shale slurry concentration, solids settling characteristics, agitation rate, and pH on the process.

  17. Characterization of raw and burnt oil shale from Dotternhausen: Petrographical and mineralogical evolution with temperature

    Energy Technology Data Exchange (ETDEWEB)

    Thiéry, Vincent, E-mail: vincent.thiery@mines-douai.fr [Mines Douai, LGCgE-GCE, F-59508 Douai (France); Université de Lille (France); Bourdot, Alexandra, E-mail: alexandra.bourdot@gmail.com [Mines Douai, LGCgE-GCE, F-59508 Douai (France); Bulteel, David, E-mail: david.bulteel@mines-douai.fr [Université de Lille (France)

    2015-08-15

    The Toarcian Posidonia shale from Dotternhausen, Germany, is quarried and burnt in a fluidized bed reactor to produce electricity. The combustion residue, namely burnt oil shale (BOS), is used in the adjacent cement work as an additive in blended cements. The starting material is a typical laminated oil shale with an organic matter content ranging from 6 to 18%. Mineral matter consists principally of quartz, feldspar, pyrite and clays. After calcination in the range, the resulting product, burnt oil shale, keeps the macroscopic layered texture however with different mineralogy (anhydrite, lime, iron oxides) and the formation of an amorphous phase. This one, studied under STEM, reveals a typical texture of incipient partial melting due to a long retention time (ca. 30 min) and quenching. An in-situ high temperature X-ray diffraction (HTXRD) allowed studying precisely the mineralogical changes associated with the temperature increase. - Highlights: • We present oil shale/burnt oil shale characterization. • The Posidonia Shale is burnt in a fluidized bed. • Mineralogical evolution with temperature is complex. • The burnt oil shale is used in composite cements.

  18. Experience and prospects of oil shale utilization for power production in Russia

    Science.gov (United States)

    Potapov, O. P.

    2016-09-01

    Due to termination of work at the Leningrad Shale Deposit, the Russian shale industry has been liquidated, including not only shale mining and processing but also research and engineering (including design) activities, because this deposit was the only commercially operated complex in Russia. UTT-3000 plants with solid heat carrier, created mainly by the Russian specialists under scientific guidance of members of Krzhizhanovsky Power Engineering Institute, passed under the control of Estonian engineers, who, alongside with their operation in Narva, construct similar plants in Kohtla-Jarve, having renamed the Galoter Process into the Enifit or Petroter. The main idea of this article is to substantiate the expediency of revival of the oil shale industry in Russia. Data on the UTT-3000 plants' advantages, shale oils, and gas properties is provided. Information on investments in an UTT-3000 plant and estimated cost of Leningrad oil shale mining at the Mezhdurechensk Strip Mine is given. For more detailed technical and economic assessment of construction of a complex for oil shale extraction and processing, it is necessary to develop a feasibility study, which should be the first stage of this work. Creation of such a complex will make it possible to produce liquid and gaseous power fuel from oil shale of Leningrad Deposit and provide the opportunity to direct for export the released volumes of oil and gas for the purposes of Russian budget currency replenishment.

  19. Assessment of industry needs for oil shale research and development. Final report

    Energy Technology Data Exchange (ETDEWEB)

    Hackworth, J.H.

    1987-05-01

    Thirty-one industry people were contacted to provide input on oil shale in three subject areas. The first area of discussion dealt with industry`s view of the shape of the future oil shale industry; the technology, the costs, the participants, the resources used, etc. It assessed the types and scale of the technologies that will form the industry, and how the US resource will be used. The second subject examined oil shale R&D needs and priorities and potential new areas of research. The third area of discussion sought industry comments on what they felt should be the role of the DOE (and in a larger sense the US government) in fostering activities that will lead to a future commercial US oil shale shale industry.

  20. Geological characteristics and resource potentials of oil shale in Ordos Basin, Center China

    Energy Technology Data Exchange (ETDEWEB)

    Yunlai, Bai; Yingcheng, Zhao; Long, Ma; Wu-jun, Wu; Yu-hu, Ma

    2010-09-15

    It has been shown that not only there are abundant oil, gas, coal, coal-bed gas, groundwater and giant uranium deposits but also there are abundant oil shale resources in Ordos basin. It has been shown also that the thickness of oil shale is, usually, 4-36m, oil-bearing 1.5%-13.7%, caloric value 1.66-20.98MJ/kg. The resource amount of oil shale with burial depth less than 2000 m is over 2000x108t (334). Within it, confirmed reserve is about 1x108t (121). Not only huge economic benefit but also precious experience in developing oil shale may be obtained in Ordos basin.

  1. Selling 'Fracking': Legitimation of High Speed Oil and Gas Extraction in the Marcellus Shale Region

    Science.gov (United States)

    Matz, Jacob R.

    The advent of horizontal hydraulic fracture drilling, or 'fracking,' a technology used to access oil and natural gas deposits, has allowed for the extraction of deep, unconventional shale gas and oil deposits in various shale seams throughout the United States and world. One such shale seam, the Marcellus shale, extends from New York State, across Pennsylvania, and throughout West Virginia, where shale gas development has significantly increased within the last decade. This boom has created a massive amount of economic activity surrounding the energy industry, creating jobs for workers, income from leases and royalties for landowners, and profits for energy conglomerates. However, this bounty comes with risks to environmental and public health, and has led to divisive community polarization over the issue in the Marcellus shale region. In the face of potential environmental and social disruption, and a great deal of controversy surrounding 'fracking,' the oil and gas industry has had to undertake a myriad of public relations campaigns and initiatives to legitimize their extraction efforts in the Marcellus shale region, and to project the oil and gas industry in a positive light to residents, policy makers, and landowners. This thesis describes one such public relations initiative, the Energy in Depth Northeast Marcellus Initiative. Through qualitative content analysis of Energy in Depth's online web material, this thesis examines the ways in which the oil and gas industry narrates the shale gas boom in the Marcellus shale region, and the ways in which the industry frames the discourse surrounding natural gas development. Through the use of environmental imagery, appeals to scientific reason, and appeals to patriotism, the oil and gas industry uses Energy in Depth to frame the shale gas extraction process in a positive way, all the while framing those who question or oppose the processes of shale gas extraction as irrational obstructionists.

  2. Enzymes for Enhanced Oil Recovery (EOR)

    OpenAIRE

    Nasiri, Hamidreza

    2011-01-01

    Primary oil recovery by reservoir pressure depletion and secondary oil recovery by waterflooding usually result in poor displacement efficiency. As a consequence there is always some trapped oil remaining in oil reservoirs. Oil entrapment is a result of complex interactions between viscous, gravity and capillary forces. Improving recovery from hydrocarbon fields typically involves altering the relative importance of the viscous and capillary forces. The potential of many EOR me...

  3. Post Retort, Pre Hydro-treat Upgrading of Shale Oil

    Energy Technology Data Exchange (ETDEWEB)

    Gordon, John

    2012-09-30

    Various oil feedstocks, including oil from oil shale, bitumen from tar sands, heavy oil, and refin- ery streams were reacted with the alkali metals lithium or sodium in the presence of hydrogen or methane at elevated temperature and pressure in a reactor. The products were liquids with sub- stantially reduced metals, sulfur and nitrogen content. The API gravity typically increased. Sodi- um was found to be more effective than lithium in effectiveness. The solids formed when sodium was utilized contained sodium sulfide which could be regenerated electrochemically back to so- dium and a sulfur product using a "Nasicon", sodium ion conducting membrane. In addition, the process was found to be effective reducing total acid number (TAN) to zero, dramatically reduc- ing the asphaltene content and vacuum residual fraction in the product liquid. The process has promise as a means of eliminating sulfur oxide and carbon monoxide emissions. The process al- so opens the possibility of eliminating the coking process from upgrading schemes and upgrad- ing without using hydrogen.

  4. Reclamation studies on oil shale lands in northwestern Colorado

    Energy Technology Data Exchange (ETDEWEB)

    Cook, C.W.; Redente, E.F.

    1980-02-01

    The overall objective of this project is to study the effects of various reclamation practices on above- and belowground ecosystem development associated with disturbed oil shale lands in northwestern Colorado. Plant growth media that are being used in field test plots include retorted shale, soil over retorted shale, subsoil materials, and surface disturbed topsoils. Some of the more significant results are: (1) a soil cover of at least 61 cm in conjunction with a capiallary barrier provided the best combination of treatments for the establishment of vegetation and a functional microbial community, (2) aboveground production values for native and introduced species mixtures are comparable after three growing seasons, (3) cover values for native species mixtures are generally greater than for introduced species, (4) native seed mixtures, in general, allow greater invasion to occur, (5) sewage sludge at relatively low rates appears to provide the most beneficial overall effect on plant growth, (6) cultural practices, such as irrigated and mulching have significant effects on both above- and belowground ecosystem development, (7) topsoil storage after 1.5 years does not appear to significantly affect general microbial activities but does reduce the mycorrhizal infection potential of the soil at shallow depths, (8) populations of mycorrhizal fungi are decreased on severely disturbed soils if a cover of vegetation is not established, (9) significant biological differences among ecotypes of important shrub species have been identified, (10) a vegetation model is outlined which upon completion will enable the reclamation specialist to predict the plant species combinations best adapted to specific reclamation sites, and (11) synthetic strains of two important grass species are close to development which will provide superior plant materials for reclamation in the West.

  5. Method for closing a drift between adjacent in situ oil shale retorts

    Science.gov (United States)

    Hines, Alex E.

    1984-01-01

    A row of horizontally spaced-apart in situ oil shale retorts is formed in a subterranean formation containing oil shale. Each row of retorts is formed by excavating development drifts at different elevations through opposite side boundaries of a plurality of retorts in the row of retorts. Each retort is formed by explosively expanding formation toward one or more voids within the boundaries of the retort site to form a fragmented permeable mass of formation particles containing oil shale in each retort. Following formation of each retort, the retort development drifts on the advancing side of the retort are closed off by covering formation particles within the development drift with a layer of crushed oil shale particles having a particle size smaller than the average particle size of oil shale particles in the adjacent retort. In one embodiment, the crushed oil shale particles are pneumatically loaded into the development drift to pack the particles tightly all the way to the top of the drift and throughout the entire cross section of the drift. The closure between adjacent retorts provided by the finely divided oil shale provides sufficient resistance to gas flow through the development drift to effectively inhibit gas flow through the drift during subsequent retorting operations.

  6. Fluidized-bed retorting of Colorado oil shale: Topical report. [None

    Energy Technology Data Exchange (ETDEWEB)

    Albulescu, P.; Mazzella, G.

    1987-06-01

    In support of the research program in converting oil shale into useful forms of energy, the US Department of Energy is developing systems models of oil shale processing plants. These models will be used to project the most attractive combination of process alternatives and identify future direction for R and D efforts. With the objective of providing technical and economic input for such systems models, Foster Wheeler was contracted to develop conceptual designs and cost estimates for commercial scale processing plants to produce syncrude from oil shales via various routes. This topical report summarizes the conceptual design of an integrated oil shale processing plant based on fluidized bed retorting of Colorado oil shale. The plant has a nominal capacity of 50,000 barrels per operating day of syncrude product, derived from oil shale feed having a Fischer Assay of 30 gallons per ton. The scope of the plant encompasses a grassroots facility which receives run of the mine oil shale, delivers product oil to storage, and disposes of the processed spent shale. In addition to oil shale feed, the battery limits input includes raw water, electric power, and natural gas to support plant operations. Design of the individual processing units was based on non-confidential information derived from published literature sources and supplemented by input from selected process licensors. The integrated plant design is described in terms of the individual process units and plant support systems. The estimated total plant investment is similarly detailed by plant section and an estimate of the annual operating requirements and costs is provided. In addition, the process design assumptions and uncertainties are documented and recommendations for process alternatives, which could improve the overall plant economics, are discussed.

  7. Immiscible foam for enhancing oil recovery

    NARCIS (Netherlands)

    Simjoo, M.

    2012-01-01

    Growing worldwide oil demand increased the need of new and efficient oil recovery methods. Gas injection in oil reservoirs is deemed one of the most widely used methods to increase oil recovery. However, the full potential of gas injection is often not realized due to poor vertical and areal sweep

  8. Recuperation of the organic matter from oil shales with phenol in subcritical conditions; Recuperation a l'autoclave de la matiere organique de schistes bitumineux marocains par le phenol en conditions sub-critiques

    Energy Technology Data Exchange (ETDEWEB)

    Abourriche, A.; Oumam, M.; Hannache, H. [Faculte des Sciences Ben M' sik, Lab. des Materiaux Thermostructuraux, Casablanca (Morocco); Pailler, R.; Naslain, R. [Bordeaux-1 Univ., Lab. des Composites Thermostructuraux, UMR 5801 CNRS-CEA-Snecma, 33 - Pessac (France); Birot, M.; Pillot, J.P. [Bordeaux-1 Univ., Lab. de Chimie Organique et Organometallique, UMR 5802 CNRS, 33 - Pessac (France)

    2005-02-01

    Phenol was used for the recovery of the organic matter from Tarfaya's oil shales in subcritical conditions. The analyses carried out on the recovered oils revealed that phenol had a significant role on the increase of the yield of recuperation, amount of maltenes, aromatic compounds and the reduction of the amount of sulphur in oils. (author)

  9. Trace elements in oil shale. Progress report, June 1, 1976--May 31, 1977

    Energy Technology Data Exchange (ETDEWEB)

    1977-02-01

    A substantial number of samples of water, stream sediment, soils, plants, oil shale, spent shale, shale oil and other materials were collected for analyses. A considerable amount of effort was also involved in the development and validation of methods for preparing and analyzing these samples for trace element content. Among the results are: Cu, Li, and Zn exhibit well-defined trends in soils over the Piceance Basin, with values increasing from north to south; As, Mo, B, and Se are all elevated in the soils of the Piceance Basin; Mo and B are more soluble in TOSCO spent shale than in unprocessed shale and are also elevated in plants growing on spent shale; F is less soluble in spent (TOSCO) shale than in unprocessed oil shale, but although the levels in leachates are quite significant (25 mg/l). F is not readily leached out; and As and Se are not very soluble in spent shale (TOSCO) and are not taken up to a significant extent by plants.

  10. A study of pyrolysis of oil shale of the Leningrad deposit by solid heat carrier

    Science.gov (United States)

    Gerasimov, G. Ya; Khaskhachikh, V. V.; Potapov, O. P.

    2017-11-01

    The investigation of the oil shale pyrolysis with a solid heat carrier was carried out using the experimental retorting system that simulates the Galoter industrial process. This system allows verifying both fractional composition of the oil shale and solid heat carrier, and their ratio and temperature. The oil shale of the Leningradsky deposit was used in the work, and quartz sand was used as the solid heat carrier. It is shown that the yield of the shale oil under the pyrolysis with solid heat carrier exceeds by more than 20% the results received in the standard Fisher retort. Using ash as the solid heat carrier results in a decrease in the yield of oil and gas with simultaneous increase in the amount of the solid residue. This is due to the chemical interaction of the acid components of the vapor-gas mixture with the oxides of alkaline-earth metals that are part of the ash.

  11. Thermodynamically consistent model of brittle oil shales under overpressure

    Science.gov (United States)

    Izvekov, Oleg

    2016-04-01

    The concept of dual porosity is a common way for simulation of oil shale production. In the frame of this concept the porous fractured media is considered as superposition of two permeable continua with mass exchange. As a rule the concept doesn't take into account such as the well-known phenomenon as slip along natural fractures, overpressure in low permeability matrix and so on. Overpressure can lead to development of secondary fractures in low permeability matrix in the process of drilling and pressure reduction during production. In this work a new thermodynamically consistent model which generalizes the model of dual porosity is proposed. Particularities of the model are as follows. The set of natural fractures is considered as permeable continuum. Damage mechanics is applied to simulation of secondary fractures development in low permeability matrix. Slip along natural fractures is simulated in the frame of plasticity theory with Drucker-Prager criterion.

  12. Hydrothermal Liquefaction Biocrude Compositions Compared to Petroleum Crude and Shale Oil

    Energy Technology Data Exchange (ETDEWEB)

    Jarvis, Jacqueline M.; Billing, Justin M.; Hallen, Richard T.; Schmidt, Andrew J.; Schaub, Tanner M.

    2017-02-17

    We provide a direct and detailed comparison of the chemical composition of petroleum crude oil (from the Gulf of Mexico), shale oil, and three biocrudes (i.e., clean pine, microalgae Chlorella sp., and sewage sludge feedstocks) generated by hydrothermal liquefaction (HTL). Ultrahigh resolution Fourier transform ion cyclotron resonance mass spectrometry (FT-ICR MS) reveals that HTL biocrudes are compositionally more similar to shale oil than petroleum crude oil and that only a few heteroatom classes (e.g., N1, N2, N1O1, and O1) are common to organic sediment- and biomass-derived oils. All HTL biocrudes contain a diverse range of oxygen-containing compounds when compared to either petroleum crude or shale oil. Overall, petroleum crude and shale oil are compositionally dissimilar to HTL oils, and >85% of the elemental compositions identified within the positive-ion electrospray (ESI) mass spectra of the HTL biocrudes were not present in either the petroleum crude or shale oil (>43% for negative-ion ESI). Direct comparison of the heteroatom classes that are common to both organic sedimentand biomass-derived oils shows that HTL biocrudes generally contain species with both smaller core structures and a lower degree of alkylation relative to either the petroleum crude or the shale oil. Three-dimensional plots of carbon number versus molecular double bond equivalents (with observed abundance as the third dimension) for abundant molecular classes reveal the specific relationship of the composition of HTL biocrudes to petroleum and shale oils to inform the possible incorporation of these oils into refinery operations as a partial amendment to conventional petroleum feeds.

  13. An overview of heavy oil properties and its recovery and transportation methods

    Directory of Open Access Journals (Sweden)

    R. G. Santos

    2014-09-01

    Full Text Available Unconventional oils - mainly heavy oils, extra heavy oils and bitumens - represent a significant share of the total oil world reserves. Oil companies have expressed interest in unconventional oil as alternative resources for the energy supply. These resources are composed usually of viscous oils and, for this reason, their use requires additional efforts to guarantee the viability of the oil recovery from the reservoir and its subsequent transportation to production wells and to ports and refineries. This review describes the main properties of high-viscosity crude oils, as well as compares traditional and emergent methods for their recovery and transportation. The main characteristics of viscous oils are discussed to highlight the oil properties that affect their flowability in the processes of recovery and pipeline transportation. Chemical composition is the starting point for the oil characterization and it has major impact on other properties, including key properties for their dynamics, such as density and viscosity. Next, enhanced oil recovery (EOR methods are presented, followed by a discussion about pipeline and transportation methods. In addition, the main challenges to achieve viable recovery and transportation of unconventional oils are compared for the different alternatives proposed. The work is especially focused on the heavy oils, while other hydrocarbon solid sources, such as oil sands and shale oil, are outside of the scope of this review.

  14. Pressurized fluidized-bed hydroretorting of Eastern oil shales -- Beneficiation. Topical report for Task 4, Beneficiation research

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Lau, F.S.; Mensinger, M.C. [Institute of Gas Technology, Chicago, IL (United States); Schultz, C.W.; Mehta, R.K.; Lamont, W.E. [Alabama Univ., University, AL (United States); Chiang, S.H.; Venkatadri, R. [Pittsburgh Univ., PA (United States); Misra, M. [Nevada Univ., Reno, NV (United States)

    1992-05-01

    The Mineral Resources Institute at the University of Alabama, along with investigators from the University of Pittsburgh and the University of Nevada-Reno, have conducted a research program on the beneficiation, of Eastern oil shales. The objective of the research program was to evaluate and adapt those new and emerging technologies that have the potential to improve the economics of recovering oil from Eastern oil shales. The technologies evaluated in this program can be grouped into three areas: fine grinding kerogen/mineral matter separation, and waste treatment and disposal. Four subtasks were defined in the area of fine grinding. They were as follows: Ultrasonic Grinding, Pressure Cycle Comminution, Stirred Ball Mill Grinding, and Grinding Circuit Optimization. The planned Ultrasonic grinding research was terminated when the company that had contracted to do the research failed. Three technologies for effecting a separation of kerogen from its associated mineral matter were evaluated: column flotation, the air-sparged hydrocyclone, and the LICADO process. Column flotation proved to be the most effective means of making the kerogen/mineral matter separation. No problems are expected in the disposal of oil shale tailings. It is assumed that the tailings will be placed in a sealed pond and the water recycled to the plant as is the normal practice. It may be advantageous, however, to conduct further research on the recovery of metals as by-products and to assess the market for tailings as an ingredient in cement making.

  15. Gas seal for an in situ oil shale retort and method of forming thermal barrier

    Science.gov (United States)

    Burton, III, Robert S.

    1982-01-01

    A gas seal is provided in an access drift excavated in a subterranean formation containing oil shale. The access drift is adjacent an in situ oil shale retort and is in gas communication with the fragmented permeable mass of formation particles containing oil shale formed in the in situ oil shale retort. The mass of formation particles extends into the access drift, forming a rubble pile of formation particles having a face approximately at the angle of repose of fragmented formation. The gas seal includes a temperature barrier which includes a layer of heat insulating material disposed on the face of the rubble pile of formation particles and additionally includes a gas barrier. The gas barrier is a gas-tight bulkhead installed across the access drift at a location in the access drift spaced apart from the temperature barrier.

  16. Piceance Creek Basin, Colorado, Oil Shale Geodatabase (Compiled from 3 legacy publications)

    Data.gov (United States)

    U.S. Geological Survey, Department of the Interior — This geodatabase is a digital reproduction of three legacy USGS oil shale publications--MF-958 (Pitman and Johnson, 1978), MF-1069 (Pitman, 1979), and OC-132 (Pitman...

  17. State-of-the - art technologies of oil shale thermal processing

    Science.gov (United States)

    Potapov, O. P.; Khaskhachikh, V. V.; Gerasimov, G. Ya

    2017-11-01

    Development of advanced oil shale processing technologies for production of liquid and gaseous fuels, as well as chemical raw materials, is a very topical problem. The article provides information on commercially implemented oil shale thermal processing technologies which use gaseous (Fushun, Kiviter and Petrosix) and solid (Lurgi-Ruhrgas, Tosco II, Aostra-Tasiyuk, Galoter) heat carriers. The authors note that the Galoter process implemented in plants with solid heat carriers has significant advantages compared to other processes.

  18. High voltage-power frequency electrical heating in-situ conversion technology of oil shale

    Science.gov (United States)

    Sun, Youhong; Yang, Yang; Lopatin, Vladimir; Guo, Wei; Liu, Baochang; Yu, Ping; Gao, Ke; Ma, Yinlong

    2014-05-01

    With the depletion of conventional energy sources,oil shale has got much attention as a new type of energy resource,which is rich and widespread in the world.The conventional utilization of oil shale is mainly focused on resorting to produce shale oil and fuel gas with low extraction efficiency about one in a million due to many shortcomings and limitations.And the in-situ conversion of oil shale,more environmentally friendly,is still in the experimental stage.High voltage-power frequency electrical heating in-situ conversion of oil shale is a new type of in-situ pyrolysis technology.The main equipment includes a high voltage-power frequency generator and interior reactor. The high voltage-power frequency generator can provide a voltage between 220-8000 V which can be adjusted in real time according to the actual situation.Firstly,high voltage is used to breakdown the oil shale to form a dendritic crack between two electrodes providing a conductive channel inside the oil shale rock.And then the power frequency(220V) is used to generate the electric current for heating the internal surface of conductive channel,so that the energy can be transmitted to the surrounding oil shale.When the temperature reaches 350 degree,the oil shale begins to pyrolysis.In addition,the temperature in the conductive channel can be extremely high with high voltage,which makes the internal surface of conductive channel graphitization and improves its heat conduction performance.This technology can successfully make the oil shale pyrolysis, based on a lot of lab experiments,and also produce the combustible shale oil and fuel gas.Compared to other in-situ conversion technology,this method has the following advantages: high speed of heating oil shale,the equipment underground is simple,and easy to operate;it can proceed without the limitation of shale thickness, and can be used especially in the thin oil shale reservoir;the heating channel is parallel to the oil shale layers,which has more

  19. Detection of porphyrin features in visible and near-infrared reflectance spectra of oil shales

    Energy Technology Data Exchange (ETDEWEB)

    Holden, P.N.; Gaffey, M.J.

    1988-01-01

    Features caused by porphyrin organo-metallic compounds, important biomarkers in oil to oil and oil to source rock correlations, have been detected in the whole-rock visible and near-infrared reflectance spectra of various oil shales. Visible and near-infrared reflectance spectroscopy is a remote sensing and laboratory technique that has been primarily used to determine mineralogy and trace-element chemistry of rock bodies. Recent investigations using oil shales in the laboratory have shown that absorption features due to nickel and vanadium porphyrin organic ring structures are detectable in the whole rock reflectance spectra even at very low concentrations (1 ppm). The predominant feature seen is the d-pi transition near 0.4 ..mu..m. Two smaller features are also seen near 0.55 ..mu..m due to d-shell transitions in the complexing metal ion. All of these features shift, depending on the complexed metal ion making nickel porphyrins distinguishable from vanadyl porphyrins. The relative ease and economy of this technique combined with the fact that nickel and vanadyl porphyrins are indicators of depositional environment create some interesting possibilities with regard to the evaluation of oil shales as oil source rocks. It may be possible to analyze core samples of oil shales in the field or to identify significant outcrops of oil shales and their type from aerial surveys or to simplify an existing laboratory procedure for oil shale evaluation. The porphyrin features seen at 0.4 and 0.55 ..mu..m are the first features due to individual organic species identified in visible and near-infrared reflectance spectra. The porphyrin class is an important biomarker as an indicator of depositional environment and as an oil to oil and oil to source rock correlator.

  20. Oil shale, tar sand, coal research advanced exploratory process technology, jointly sponsored research. Quarterly technical progress report, October--December 1992

    Energy Technology Data Exchange (ETDEWEB)

    Speight, J.G.

    1992-12-31

    Accomplishments for the past quarter are presented for the following five tasks: oil shale; tar sand; coal; advanced exploratory process technology; and jointly sponsored research. Oil shale research covers oil shale process studies. Tar sand research is on process development of Recycle Oil Pyrolysis and Extraction (ROPE) Process. Coal research covers: coal combustion; integrated coal processing concepts; and solid waste management. Advanced exploratory process technology includes: advanced process concepts;advanced mitigation concepts; and oil and gas technology. Jointly sponsored research includes: organic and inorganic hazardous waste stabilization; CROW field demonstration with Bell Lumber and Pole; development and validation of a standard test method for sequential batch extraction fluid; PGI demonstration project; operation and evaluation of the CO{sub 2} HUFF-N-PUFF Process; fly ash binder for unsurfaced road aggregates; solid state NMR analysis of Mesaverde Group, Greater Green River Basin, tight gas sands; flow-loop testing of double-wall pipe for thermal applications; characterization of petroleum residue; shallow oil production using horizontal wells with enhanced oil recovery techniques; surface process study for oil recovery using a thermal extraction process; NMR analysis of samples from the ocean drilling program; in situ treatment of manufactured gas plant contaminated soils demonstration program; and solid state NMR analysis of naturally and artificially matured kerogens.

  1. Characteristic fly-ash particles from oil-shale combustion found in lake sediments

    Energy Technology Data Exchange (ETDEWEB)

    Alliksaar, T.; Hoerstedt, P.; Renberg, I. [Estonian Academy of Sciences, Tallinn (Estonia). Dept. of Geoecology

    1998-05-01

    Fly-ash particles accumulate in sediments and can be used to assess spatial distribution and temporal trends of atmospheric deposition of pollutants derived from high temperature combustion of fossil fuels. Previous work has concerned fly-ash derived from oil and coal. Oil-shale is the main fossil fuel used in Estonia and a major source of atmospheric pollution in the Baltic states. To assess if oil-shale power plants produce specific fly-ash particles scanning electron microscopy (SEM) and energy dispersive X-ray analysis (EDX) were used to compare fly-ash particles from oil-shale combustion with particles from oil and coal combustion. Two types were analysed, large black (10-30{mu}m) and small glassy ({lt} 5 {mu}m) spheroidal particles. Although article morphology to some extent is indicative of the fuel burnt, morphological characters are not sufficient to differentiate between particles of different origin. However, the results indicate that with EDX analysis the fly-ash from oil-shale can be distinguished form oil and coal derived particles in environmental samples. Concentrations of large black and small glassy spheroidal fly-ash particles in a sediment core from an Estonian lake showed similar trends to oil-shale combustion statistics from Estonian power plants. 27 refs., 6 figs., 2 tabs.

  2. Volatile-organic molecular characterization of shale-oil produced water from the Permian Basin

    Science.gov (United States)

    Khan, Naima A.; Engle, Mark A.; Dungan, Barry; Holguin, F. Omar; Xu, Pei; Carroll, Kenneth C.

    2016-01-01

    Growth in unconventional oil and gas has spurred concerns on environmental impact and interest in beneficial uses of produced water (PW), especially in arid regions such as the Permian Basin, the largest U.S. tight-oil producer. To evaluate environmental impact, treatment, and reuse potential, there is a need to characterize the compositional variability of PW. Although hydraulic fracturing has caused a significant increase in shale-oil production, there are no high-resolution organic composition data for the shale-oil PW from the Permian Basin or other shale-oil plays (Eagle Ford, Bakken, etc.). PW was collected from shale-oil wells in the Midland sub-basin of the Permian Basin. Molecular characterization was conducted using high-resolution solid phase micro extraction gas chromatography time-of-flight mass spectrometry. Approximately 1400 compounds were identified, and 327 compounds had a >70% library match. PW contained alkane, cyclohexane, cyclopentane, BTEX (benzene, toluene, ethylbenzene, and xylene), alkyl benzenes, propyl-benzene, and naphthalene. PW also contained heteroatomic compounds containing nitrogen, oxygen, and sulfur. 3D van Krevelen and double bond equivalence versus carbon number analyses were used to evaluate molecular variability. Source composition, as well as solubility, controlled the distribution of volatile compounds found in shale-oil PW. The salinity also increased with depth, ranging from 105 to 162 g/L total dissolved solids. These data fill a gap for shale-oil PW composition, the associated petroleomics plots provide a fingerprinting framework, and the results for the Permian shale-oil PW suggest that partial treatment of suspended solids and organics would support some beneficial uses such as onsite reuse and bio-energy production.

  3. Volatile-organic molecular characterization of shale-oil produced water from the Permian Basin.

    Science.gov (United States)

    Khan, Naima A; Engle, Mark; Dungan, Barry; Holguin, F Omar; Xu, Pei; Carroll, Kenneth C

    2016-04-01

    Growth in unconventional oil and gas has spurred concerns on environmental impact and interest in beneficial uses of produced water (PW), especially in arid regions such as the Permian Basin, the largest U.S. tight-oil producer. To evaluate environmental impact, treatment, and reuse potential, there is a need to characterize the compositional variability of PW. Although hydraulic fracturing has caused a significant increase in shale-oil production, there are no high-resolution organic composition data for the shale-oil PW from the Permian Basin or other shale-oil plays (Eagle Ford, Bakken, etc.). PW was collected from shale-oil wells in the Midland sub-basin of the Permian Basin. Molecular characterization was conducted using high-resolution solid phase micro extraction gas chromatography time-of-flight mass spectrometry. Approximately 1400 compounds were identified, and 327 compounds had a >70% library match. PW contained alkane, cyclohexane, cyclopentane, BTEX (benzene, toluene, ethylbenzene, and xylene), alkyl benzenes, propyl-benzene, and naphthalene. PW also contained heteroatomic compounds containing nitrogen, oxygen, and sulfur. 3D van Krevelen and double bond equivalence versus carbon number analyses were used to evaluate molecular variability. Source composition, as well as solubility, controlled the distribution of volatile compounds found in shale-oil PW. The salinity also increased with depth, ranging from 105 to 162 g/L total dissolved solids. These data fill a gap for shale-oil PW composition, the associated petroleomics plots provide a fingerprinting framework, and the results for the Permian shale-oil PW suggest that partial treatment of suspended solids and organics would support some beneficial uses such as onsite reuse and bio-energy production. Copyright © 2016 Elsevier Ltd. All rights reserved.

  4. Military Fuels Refined from Paraho-II Shale Oil.

    Science.gov (United States)

    1981-03-01

    Laboratories showed that growth of Cladosporium resinae was supported by the shale-derived JP-5 and DFM. 1t The performances of shale fuels in a turbine...27 11 Corrosion Tendencies of Shale Fuels ............................. 28 12 Growth Rating of Cladosporium Resinae in Tubes After Days of...screw cap test tubes and overlayed with 3 ml of the test fuel. Each tube was inoculated with one drop of a spore suspension of Cladosporium resinae , QM

  5. An assessment of using oil shale for power production in the Hashemite Kingdom of Jordan

    Energy Technology Data Exchange (ETDEWEB)

    Hill, L.J.; Holcomb, R.S.; Petrich, C.H.; Roop, R.D.

    1990-11-01

    This report addresses the oil shale-for-power-production option in Jordan. Under consideration are 20- and 50-MW demonstration units and a 400-MW, commercial-scale plant with, at the 400-MW scale, a mining operation capable of supplying 7.8 million tonnes per year of shale fuel and also capable of disposal of up to 6.1 million tonnes per year of wetted ash. The plant would be a direct combustion facility, burning crushed oil shale through use of circulating fluidized bed combustion technology. The report emphasizes four areas: (1) the need for power in Jordan, (2) environmental aspects of the proposed oil shale-for-power plant(s), (3) the engineering feasibility of using Jordan's oil shale in circulating fluidized bed combustion (CFBC) boiler, and (4) the economic feasibility of the proposed plant(s). A sensitivity study was conducted to determine the economic feasibility of the proposed plant(s) under different cost assumptions and revenue flows over the plant's lifetime. The sensitivity results are extended to include the major extra-firm benefits of the shale-for-power option: (1) foreign exchange savings from using domestic energy resources, (2) aggregate income effects of using Jordan's indigenous labor force, and (3) a higher level of energy security. 14 figs., 47 tabs.

  6. Composition of pyrolysis gas from oil shale at various stages of heating

    Science.gov (United States)

    Martemyanov, S. M.; Bukharkin, A. A.; Koryashov, I. A.; Ivanov, A. A.

    2017-05-01

    Underground, the pyrolytic conversion of an oil shale in the nearest future may become an alternative source of a fuel gas and a synthetic oil. The main scientific problem in designing this technology is to provide a methodology for determination of the optimal mode of heating the subterranean formation. Such a methodology must allow predicting the composition of the pyrolysis products and the energy consumption at a given heating rate of the subterranean formation. The paper describes the results of heating of the oil shale fragments in conditions similar to the underground. The dynamics of composition of the gaseous products of pyrolysis are presented and analyzed.

  7. Investigation of the Geokinetics horizontal in situ oil-shale-retorting process. Fourth annual report, 1980

    Energy Technology Data Exchange (ETDEWEB)

    Hutchinson, D.L. (ed.)

    1981-03-01

    The Geokinetics in situ shale oil project is a cooperative venture between Geokinetics Inc. and the US Department of Energy. The objective is to develop a true in situ process for recovering shale oil using a fire front moving in a horizontal direction. The project is being conducted at a field site, Kamp Kerogen, located 70 miles south of Vernal, Utah. This Fourth Annual Report covers work completed during the calendar year 1980. During 1980 one full-size retort was blasted. Two retorts, blasted the previous year, were burned. A total of 4891 barrels of oil was produced during the year.

  8. Western oil shale development: a technology assessment. Volume 7: an ecosystem simulation of perturbations applied to shale oil development

    Energy Technology Data Exchange (ETDEWEB)

    1982-05-01

    Progress is outlined on activities leading toward evaluation of ecological and agricultural impacts of shale oil development in the Piceance Creek Basin region of northwestern Colorado. After preliminary review of the problem, it was decided to use a model-based calculation approach in the evaluation. The general rationale and objectives of this approach are discussed. Previous studies were examined to characterize climate, soils, vegetation, animals, and ecosystem response units. System function was methodically defined by developing a master list of variables and flows, structuring a generalized system flow diagram, constructing a flow-effects matrix, and conceptualizing interactive spatial units through spatial matrices. The process of developing individual mathematical functions representing the flow of matter and energy through the various system variables in different submodels is discussed. The system model diagram identified 10 subsystems which separately account for flow of soil temperatures, soil water, herbaceous plant biomass, shrubby plant biomass, tree cover, litter biomass, shrub numbers, animal biomass, animal numbers, and land area. Among these coupled subsystems there are 45 unique kinds of state variables and 150 intra-subsystem flows. The model is generalizeable and canonical so that it can be expanded, if required, by disaggregating some of the system state variables and allowing for multiple ecological response units. It integrates information on climate, surface water, ecology, land reclamation, air quality, and solid waste as it is being developed by several other task groups.

  9. Interactive Matching between the Temperature Profile and Secondary Reactions of Oil Shale Pyrolysis

    DEFF Research Database (Denmark)

    Zhang, Yu; Han, Zhennan; Wu, Hao

    2016-01-01

    degrees C and a shale char bed operating at different temperatures. At low temperatures (550 degrees C), severe cracking occurred, converting both heavy and light oil to carbon and gas. The desirably matched reactor temperature profile for high oil yield is discussed via analysis of the tendency......This article investigates the effect of the reactor temperature profile on the distribution and characteristics of the products from fixed-bed pyrolysis of oil shale. Experiments were performed in a one-stage fixed-bed reactor and in a two-stage fixed-bed reactor. In the one-stage reactor......, the shale oil yield reached 7.40 wt % with a reactor temperature profile from 900 to 550 degrees C and decreased to 2.23 wt % with the reverse temperature profile. The effect of the temperature profile was investigated further in the two-stage fixed-bed reactor combining a pyrolysis stage operating at 550...

  10. Naval Petroleum and Oil Shale Reserves. Annual report of operations, Fiscal year 1992

    Energy Technology Data Exchange (ETDEWEB)

    1992-12-31

    During fiscal year 1992, the reserves generated $473 million in revenues, a $181 million decrease from the fiscal year 1991 revenues, primarily due to significant decreases in oil and natural gas prices. Total costs were $200 million, resulting in net cash flow of $273 million, compared with $454 million in fiscal year 1991. From 1976 through fiscal year 1992, the Naval Petroleum and Oil Shale Reserves generated more than $15 billion in revenues and a net operating income after costs of $12.5 billion. In fiscal year 1992, production at the Naval Petroleum Reserves at maximum efficient rates yielded 26 million barrels of crude oil, 119 billion cubic feet of natural gas, and 164 million gallons of natural gas liquids. From April to November 1992, senior managers from the Naval Petroleum and Oil Shale Reserves held a series of three workshops in Boulder, Colorado, in order to build a comprehensive Strategic Plan as required by Secretary of Energy Notice 25A-91. Other highlights are presented for the following: Naval Petroleum Reserve No. 1--production achievements, crude oil shipments to the strategic petroleum reserve, horizontal drilling, shallow oil zone gas injection project, environment and safety, and vanpool program; Naval Petroleum Reserve No. 2--new management and operating contractor and exploration drilling; Naval Petroleum Reserve No. 3--steamflood; Naval Oil Shale Reserves--protection program; and Tiger Team environmental assessment of the Naval Petroleum and Oil Shale Reserves in Colorado, Utah, and Wyoming.

  11. Pressurized Fluidized-Bed Hydroretorting of Eastern Oil Shales. Progress report, July--September 1989

    Energy Technology Data Exchange (ETDEWEB)

    Punwani, D.V.; Lau, F.S.; Knowlton, T.M. [and others

    1989-12-01

    The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the 3-year program, initiated in October 1987 is to perform the research necessary to develop the pressurized fluidized-bed hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The program is divided into the following eight tasks: Task 1, PFH Scoping Studies; Task 2, PFH Optimization Tests; Task 3, Testing of Process Improvement Concepts; Task 4, Beneficiation Research; Task 5, Operation of PFH on Beneficiated Shale; Task 6, Environmental Data and Mitigation Analyses; Task 7, Sample Procurement, Preparation, and Characterization; Task 8, Project Management and Reporting. In order to accomplish all the program objectives, the Institute of Gas Technology, the prime contractor, is working with seven other institutions; the University of Alabama/Mineral Resources Institute, Illinois Institute of Technology, the University of Michigan, the University of Nevada, Ohio State University, Tennessee Technological University and the University of Pittsburgh. This report presents the work performed during the eighth program quarter from July 1 through September 30, 1989.

  12. Detailed description of oil shale organic and mineralogical heterogeneity via fourier transform infrared mircoscopy

    Science.gov (United States)

    Washburn, Kathryn E.; Birdwell, Justin E.; Foster, Michael; Gutierrez, Fernando

    2015-01-01

    Mineralogical and geochemical information on reservoir and source rocks is necessary to assess and produce from petroleum systems. The standard methods in the petroleum industry for obtaining these properties are bulk measurements on homogenized, generally crushed, and pulverized rock samples and can take from hours to days to perform. New methods using Fourier transform infrared (FTIR) spectroscopy have been developed to more rapidly obtain information on mineralogy and geochemistry. However, these methods are also typically performed on bulk, homogenized samples. We present a new approach to rock sample characterization incorporating multivariate analysis and FTIR microscopy to provide non-destructive, spatially resolved mineralogy and geochemistry on whole rock samples. We are able to predict bulk mineralogy and organic carbon content within the same margin of error as standard characterization techniques, including X-ray diffraction (XRD) and total organic carbon (TOC) analysis. Validation of the method was performed using two oil shale samples from the Green River Formation in the Piceance Basin with differing sedimentary structures. One sample represents laminated Green River oil shales, and the other is representative of oil shale breccia. The FTIR microscopy results on the oil shales agree with XRD and LECO TOC data from the homogenized samples but also give additional detail regarding sample heterogeneity by providing information on the distribution of mineral phases and organic content. While measurements for this study were performed on oil shales, the method could also be applied to other geological samples, such as other mudrocks, complex carbonates, and soils.

  13. Potential water resource impacts of hydraulic fracturing from unconventional oil production in the Bakken shale.

    Science.gov (United States)

    Shrestha, Namita; Chilkoor, Govinda; Wilder, Joseph; Gadhamshetty, Venkataramana; Stone, James J

    2017-01-01

    Modern drilling techniques, notably horizontal drilling and hydraulic fracturing, have enabled unconventional oil production (UOP) from the previously inaccessible Bakken Shale Formation located throughout Montana, North Dakota (ND) and the Canadian province of Saskatchewan. The majority of UOP from the Bakken shale occurs in ND, strengthening its oil industry and businesses, job market, and its gross domestic product. However, similar to UOP from other low-permeability shales, UOP from the Bakken shale can result in environmental and human health effects. For example, UOP from the ND Bakken shale generates a voluminous amount of saline wastewater including produced and flowback water that are characterized by unusual levels of total dissolved solids (350 g/L) and elevated levels of toxic and radioactive substances. Currently, 95% of the saline wastewater is piped or trucked onsite prior to disposal into Class II injection wells. Oil and gas wastewater (OGW) spills that occur during transport to injection sites can potentially result in drinking water resource contamination. This study presents a critical review of potential water resource impacts due to deterministic (freshwater withdrawals and produced water management) and probabilistic events (spills due to leaking pipelines and truck accidents) related to UOP from the Bakken shale in ND. Copyright © 2016 Elsevier Ltd. All rights reserved.

  14. Compositional modification of crude oil during oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Zhu, Yangming; Weng, Huanxin [Department of Earth Sciences, Zhejiang University, Hangzhou 310027 (China); Chen, Zulin; Chen, Qi [Petroleum Geochemistry Research Center, Jianghan Petroleum University, Jingzhou, Hubei (China)

    2003-05-01

    Ten crude oils from two recovery stages spanning 5-10-year interval of five productive wells in the Tarim Basin, northwest China were analyzed for their compositional modification during production process. Significant compositional changes in polar and nonpolar fractions between the previous oil samples and the latter ones were noted at both bulk and molecular level. The latter oil samples appear to contain more aromatic fraction and less asphaltenes and resin, and their gas chromatography (GC) data for whole oil show reduced alkanes with low molecular weight and enhanced high homologue relative to the previous oil samples. Compared with the oils collected from the previous recovery stage, the concentration of basic type of nitrogen-containing compounds and organic acids in oils from the latter recovery stage have a reducing trend, suggesting the occurrence of interaction between crude oil and reservoir rock.

  15. Molecular characterization and comparison of shale oils generated by different pyrolysis methods

    Science.gov (United States)

    Birdwell, Justin E.; Jin, Jang Mi; Kim, Sunghwan

    2012-01-01

    Shale oils generated using different laboratory pyrolysis methods have been studied using standard oil characterization methods as well as Fourier transform ion cyclotron resonance mass spectrometry (FT-ICR MS) with electrospray ionization (ESI) and atmospheric photoionization (APPI) to assess differences in molecular composition. The pyrolysis oils were generated from samples of the Mahogany zone oil shale of the Eocene Green River Formation collected from outcrops in the Piceance Basin, Colorado, using three pyrolysis systems under conditions relevant to surface and in situ retorting approaches. Significant variations were observed in the shale oils, particularly the degree of conjugation of the constituent molecules and the distribution of nitrogen-containing compound classes. Comparison of FT-ICR MS results to other oil characteristics, such as specific gravity; saturate, aromatic, resin, asphaltene (SARA) distribution; and carbon number distribution determined by gas chromatography, indicated correspondence between higher average double bond equivalence (DBE) values and increasing asphaltene content. The results show that, based on the shale oil DBE distributions, highly conjugated species are enriched in samples produced under low pressure, high temperature conditions, and under high pressure, moderate temperature conditions in the presence of water. We also report, for the first time in any petroleum-like substance, the presence of N4 class compounds based on FT-ICR MS data. Using double bond equivalence and carbon number distributions, structures for the N4 class and other nitrogen-containing compounds are proposed.

  16. Pressurized fluidized-bed hydroretorting of Eastern oil shales. Annual report, June 1991--May 1992

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Mensinger, M.C.; Rue, D.M.; Lau, F.S. [Institute of Gas Technology, Chicago, IL (United States); Schultz, C.W. [Alabama Univ., University, AL (United States); Parekh, B.K. [Kentucky Univ., Lexington, KY (United States); Misra, M. [Nevada Univ., Reno, NV (United States); Bonner, W.P. [Tennessee Technological Univ., Cookeville, TN (United States)

    1992-11-01

    The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the multi-year program, initiated in October 1987 by the US Department of Energy is to perform the research necessary to develop the Pressurized Fluidized-Bed Hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The results of the original 3-year program, which was concluded in May 1991, have been summarized in a four-volume final report published by IGT. DOE subsequently approved a 1-year extension to the program to further develop the PFH process specifically for application to beneficiated shale as feedstock. Studies have shown that beneficiated shale is the preferred feedstock for pressurized hydroretorting. The program extension is divided into the following active tasks. Task 3. testing of process improvement concepts; Task 4. beneficiation research; Task 5. operation of PFH on beneficiated shale; Task 6. environmental data and mitigation analyses; Task 7. sample procurement, preparation, and characterization; and Task 8. project management and reporting. In order to accomplish all the program objectives, the Institute of Gas Technology (IGT), the prime contractor, worked with four other institutions: the University of Alabama/Mineral Resources Institute (MRI), the University of Kentucky Center for Applied Energy Research (UK-CAER), the University of Nevada (UN) at Reno, and Tennessee Technological University (TTU). This report presents the work performed during the program extension from June 1, 1991 through May 31, 1992.

  17. Effects of processed oil shale on the element content of Atriplex cancescens

    Science.gov (United States)

    Anderson, B.M.

    1982-01-01

    Samples of four-wing saltbush were collected from the Colorado State University Intensive Oil Shale Revegetation Study Site test plots in the Piceance basin, Colorado. The test plots were constructed to evaluate the effects of processed oil shale geochemistry on plant growth using various thicknesses of soil cover over the processed shale and/or over a gravel barrier between the shale and soil. Generally, the thicker the soil cover, the less the influence of the shale geochemistry on the element concentrations in the plants. Concentrations of 20 elements were larger in the ash of four-wing saltbush growing on the plot with the gravel barrier (between the soil and processed shale) when compared to the sample from the control plot. A greater water content in the soil in this plot has been reported, and the interaction between the increased, percolating water and shale may have increased the availability of these elements for plant uptake. Concentrations of boron, copper, fluorine, lithium, molybdenum, selenium, silicon, and zinc were larger in the samples grown over processed shale, compared to those from the control plot, and concentrations for barium, calcium, lanthanum, niobium, phosphorus, and strontium were smaller. Concentrations for arsenic, boron, fluorine, molybdenum, and selenium-- considered to be potential toxic contaminants--were similar to results reported in the literature for vegetation from the test plots. The copper-to-molybdenum ratios in three of the four samples of four-wing saltbush growing over the processed shale were below the ratio of 2:1, which is judged detrimental to ruminants, particularly cattle. Boron concentrations averaged 140 ppm, well above the phytotoxicity level for most plant species. Arsenic, fluorine, and selenium concentrations were below toxic levels, and thus should not present any problem for revegetation or forage use at this time.

  18. The U.S. Shale Oil and Gas Resource - a Multi-Scale Analysis of Productivity

    Science.gov (United States)

    O'sullivan, F.

    2014-12-01

    Over the past decade, the large-scale production of natural gas, and more recently oil, from U.S. shale formations has had a transformative impact on the energy industry. The emergence of shale oil and gas as recoverable resources has altered perceptions regarding both the future abundance and cost of hydrocarbons, and has shifted the balance of global energy geopolitics. However, despite the excitement, shale is a resource in its nascency, and many challenges surrounding its exploitation remain. One of the most significant of these is the dramatic variation in resource productivity across multiple length scales, which is a feature of all of today's shale plays. This paper will describe the results of work that has looked to characterize the spatial and temporal variations in the productivity of the contemporary shale resource. Analysis will be presented that shows there is a strong stochastic element to observed shale well productivity in all the major plays. It will be shown that the nature of this stochasticity is consistent regardless of specific play being considered. A characterization of this stochasticity will be proposed. As a parallel to the discussion of productivity, the paper will also address the issue of "learning" in shale development. It will be shown that "creaming" trends are observable and that although "absolute" well productivity levels have increased, "specific" productivity levels (i.e. considering well and stimulation size) have actually falling markedly in many plays. The paper will also show that among individual operators' well ensembles, normalized well-to-well performance distributions are almost identical, and have remained consistent year-to-year. This result suggests little if any systematic learning regarding the effective management of well-to-well performance variability has taken place. The paper will conclude with an articulation of how the productivity characteristics of the shale resource are impacting on the resources

  19. Western oil shale development: a technology assessment. Volume 1. Main report

    Energy Technology Data Exchange (ETDEWEB)

    1981-11-01

    The general goal of this study is to present the prospects of shale oil within the context of (1) environmental constraints, (2) available natural and economic resources, and (3) the characteristics of existing and emerging technology. The objectives are: to review shale oil technologies objectively as a means of supplying domestically produced fuels within environmental, social, economic, and legal/institutional constraints; using available data, analyses, and experienced judgment, to examine the major points of uncertainty regarding potential impacts of oil shale development; to resolve issues where data and analyses are compelling or where conclusions can be reached on judgmental grounds; to specify issues which cannot be resolved on the bases of the data, analyses, and experienced judgment currently available; and when appropriate and feasible, to suggest ways for the removal of existing uncertainties that stand in the way of resolving outstanding issues.

  20. The Study on Preparation of Silica Using Residue of Oil Shale Residue

    Directory of Open Access Journals (Sweden)

    Nie L.

    2015-07-01

    Full Text Available Usage of oil shale produces abundant oil shale residue, which may not only directly cause serious pollution to the environment, but also result in a waste of resource. In this paper, acid leaching method and alkali soluble method were compared to obtain the optimum processing conditions for the preparation of white carbon black, which was determined as follows: the mass fraction of NaOH was 8 %, the alkali dissolving time was 5 h, and the reaction temperature was 100 °C. Then the performance characteristics of the obtained white carbon black were analysed by XRD, SEM and IR spectroscopy. The results showed that the product of silica has a particle size between 20 – 30 nm and a purity of 98.4 %. Preparation of the high quality white carbon black might be a good way to make sufficient and reasonable use of oil shale residues, which will bring many environmental and social benefits.

  1. Shale oil value enhancement research. Quarterly report, October 1, 1993--December 31, 1993

    Energy Technology Data Exchange (ETDEWEB)

    NONE

    1997-05-01

    The first year of this effort was focussed on the following broad objectives: (1) Analyze the molecular types present in shale oil (as a function of molecular weight distribution); (2) Determine the behavior of these molecular types in liquid-liquid extraction; (3) Develop the analytical tools needed to systematize the process development; (4) Survey the markets to assure that these have high value uses for the types found in shale oil; (5) Explore selective process means for extracting/converting shale oil components into concentrates of potentially marketable components; (6) Compile overview of the venture development strategy and begin implementation of that strategy. Each of these tasks has been completed in sufficient detail that we can now focus on filling in the knowledge gaps evident from the overview.

  2. Nickel, copper and vanadyl porphyrins from Moroccan oil shales. Composition, novel structures, biological precursors

    Energy Technology Data Exchange (ETDEWEB)

    Verne-Mismer, J.; Ocampo, R.; Bauder, C.; Callot, H.J.; Albrecht, P. (Universite Louis Pasteur, Strasbourg (France))

    1989-03-01

    An exhaustive structural investigation of the nickel and vanadyl-porphyrin fractions from two Moroccan oil shales, Timahdit and Oulad Abdoun, was carried out. More than 20 structures, half of them showing a novel carbon skeleton, were unambiguously assigned by combined spectroscopic (FT NMR + nOe) and synthetic (total or partial synthesis) methods. In addition to the classical series, two groups of structures are of particular interest: (a) the tetrahydrobenzoporphyrins which might derive from a still unknown family of natural chlorophylls; (b) the 17-nor-DPEPs which are likely fossils of the algal chlorophyll c. The last series is complementary to the known 15,17-ethanoporphyrins, specific markers for chlorophyll c and the distribution of both series in various oil shales will be discussed. The composition of a minor copper-porphyrin fraction and preliminary indications concerning the free bases from Oulad Abdoun oil shale will also be presented.

  3. Distribution and origin of organic sulphur compounds in Irati shale oil

    Energy Technology Data Exchange (ETDEWEB)

    Afonso, J.C.; Cardoso, J.N.; Schmal, M. (Federal University of Rio de Janeiro, Rio de Janeiro (Brazil). Coordenacao dos Programas de Pos-Graduacao em Engenharia)

    1992-04-01

    This work presents and discusses the occurrence of the principal organic sulphur compounds found in Irati shale oil (Sao Mateus do Sul, Parana, Brazil) as indicated by a combination of gas chromatography-mass spectrometry analysis, retention time data of standard compounds and, when possible by co-injection with authentic standards. The amount of sulphur in the shale oil corresponds to {approximately}40% of the organic sulphur and to a very small fraction of the total sulphur present in the shale (< 1%). A large predominance of low molecular alkylthiophenes (C2-C5 side chain) and low quantities of benzothiophene, dibenzothiophene and alkyldibenzothiophenes (methyl, dimethyl) were observed, attesting to the immaturity of the sample. The distributions of the alkylthiophenes and the hydrocarbons in the oil are apparently related, suggesting a precursor-product relationship at the time of formation of the sediment. 47 refs., 4 figs., 4 tabs.

  4. 77 FR 67663 - Notice of Availability of the Proposed Land Use Plan Amendments for Allocation of Oil Shale and...

    Science.gov (United States)

    2012-11-13

    ... Bureau of Land Management Notice of Availability of the Proposed Land Use Plan Amendments for Allocation of Oil Shale and Tar Sands Resources on Lands Administered by the Bureau of Land Management in...) Amendments for Allocation of Oil Shale and Tar Sands Resources on Lands Administered by the BLM in Colorado...

  5. Energy map of southwestern Wyoming, Part B: oil and gas, oil shale, uranium, and solar

    Science.gov (United States)

    Biewick, Laura R.H.; Wilson, Anna B.

    2014-01-01

    The U.S. Geological Survey (USGS) has compiled Part B of the Energy Map of Southwestern Wyoming for the Wyoming Landscape Conservation Initiative (WLCI). Part B consists of oil and gas, oil shale, uranium, and solar energy resource information in support of the WLCI. The WLCI represents the USGS partnership with other Department of the Interior Bureaus, State and local agencies, industry, academia, and private landowners, all of whom collaborate to maintain healthy landscapes, sustain wildlife, and preserve recreational and grazing uses while developing energy resources in southwestern Wyoming. This product is the second and final part of the Energy Map of Southwestern Wyoming series (also see USGS Data Series 683, http://pubs.usgs.gov/ds/683/), and encompasses all of Carbon, Lincoln, Sublette, Sweetwater, and Uinta Counties, as well as areas in Fremont County that are in the Great Divide and Green River Basins.

  6. Policy Analysis of Water Availability and Use Issues for Domestic Oil Shale and Oil Sands Development

    Energy Technology Data Exchange (ETDEWEB)

    Ruple, John [Univ. of Utah, Salt Lake City, UT (United States); Keiter, Robert [Univ. of Utah, Salt Lake City, UT (United States)

    2010-03-01

    Oil shale and oil sands resources located within the intermountain west represent a vast, and as of yet, commercially untapped source of energy. Development will require water, and demand for scarce water resources stands at the front of a long list of barriers to commercialization. Water requirements and the consequences of commercial development will depend on the number, size, and location of facilities, as well as the technologies employed to develop these unconventional fuels. While the details remain unclear, the implication is not – unconventional fuel development will increase demand for water in an arid region where demand for water often exceeds supply. Water demands in excess of supplies have long been the norm in the west, and for more than a century water has been apportioned on a first-come, first-served basis. Unconventional fuel developers who have not already secured water rights stand at the back of a long line and will need to obtain water from willing water purveyors. However, uncertainty regarding the nature and extent of some senior water claims combine with indeterminate interstate river management to cast a cloud over water resource allocation and management. Quantitative and qualitative water requirements associated with Endangered Species protection also stand as barriers to significant water development, and complex water quality regulations will apply to unconventional fuel development. Legal and political decisions can give shape to an indeterminate landscape. Settlement of Northern Ute reserved rights claims would help clarify the worth of existing water rights and viability of alternative sources of supply. Interstate apportionment of the White River would go a long way towards resolving water availability in downstream Utah. And energy policy clarification will help determine the role oil shale and oil sands will play in our nation’s future.

  7. Rates and Mechanisms of Oil Shale Pyrolysis: A Chemical Structure Approach

    Energy Technology Data Exchange (ETDEWEB)

    Fletcher, Thomas; Pugmire, Ronald

    2015-01-01

    Three pristine Utah Green River oil shale samples were obtained and used for analysis by the combined research groups at the University of Utah and Brigham Young University. Oil shale samples were first demineralized and the separated kerogen and extracted bitumen samples were then studied by a host of techniques including high resolution liquid-state carbon-13 NMR, solid-state magic angle sample spinning 13C NMR, GC/MS, FTIR, and pyrolysis. Bitumen was extracted from the shale using methanol/dichloromethane and analyzed using high resolution 13C NMR liquid state spectroscopy, showing carbon aromaticities of 7 to 11%. The three parent shales and the demineralized kerogens were each analyzed with solid-state 13C NMR spectroscopy. Carbon aromaticity of the kerogen was 23-24%, with 10-12 aromatic carbons per cluster. Crushed samples of Green River oil shale and its kerogen extract were pyrolyzed at heating rates from 1 to 10 K/min at pressures of 1 and 40 bar and temperatures up to 1000°C. The transient pyrolysis data were fit with a first-order model and a Distributed Activation Energy Model (DAEM). The demineralized kerogen was pyrolyzed at 10 K/min in nitrogen at atmospheric pressure at temperatures up to 525°C, and the pyrolysis products (light gas, tar, and char) were analyzed using 13C NMR, GC/MS, and FTIR. Details of the kerogen pyrolysis have been modeled by a modified version of the chemical percolation devolatilization (CPD) model that has been widely used to model coal combustion/pyrolysis. This refined CPD model has been successful in predicting the char, tar, and gas yields of the three shale samples during pyrolysis. This set of experiments and associated modeling represents the most sophisticated and complete analysis available for a given set of oil shale samples.

  8. HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS

    Energy Technology Data Exchange (ETDEWEB)

    Anthony R. Kovscek

    2002-07-01

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

  9. Survival of the Unfit: Path Dependence and the Estonian Oil Shale Industry

    Energy Technology Data Exchange (ETDEWEB)

    Holmberg, Rurik

    2009-01-15

    Estonia is the only country in the world, which is totally dependent on oil shale in its energy system. Although this fossil fuel exists in enormous quantities around the world, it has so far not been utilized on a larger scale. The reasons for this have been both economic and, in recent times, ecological. It can therefore be argued that in most cases, oil shale represents an inferior solution compared to other energy sources. This work examines why a technology utilizing oil shale has developed in Estonia and why Estonia appears not to be in a position to switch to other energy sources. In this work it is claimed that oil shale actually has been an appropriate solution to short-term concerns, despite the fact that its long-term drawbacks have been identified. These circumstances led to path dependence. Once the technology was in place, it advanced along its learning curve producing a satisfactory outcome, but not an optimal one. However, this situation has been accepted due to the extremely turbulent institutional environment Estonia has undergone in the 20th century. In Sweden, a somewhat similar (but smaller) oil shale industry was shut down in the 1960s because of poor economic performance, but also because of the competition from other energy sources. Such competition did not take place in Estonia, in part due to the specific institutional set-up of the Soviet Union. This made it possible for the Estonian oil shale industry to develop further, causing the present lock-in. Today the existing infrastructure, the knowledge-base, and the particular socio-political circumstances of Estonia effectively prevent change. Furthermore, it is argued that because there was only little oil shale-related technology developed outside Estonia, most technology had to be developed domestically. This in turn has forced the Estonian oil shale industry to make several highly inconvenient alliances in order to gain room to manoeuvre. Partially as a result of this, there is today

  10. Structure of Green River oil shale kerogen: determination using solid state /sup 13/C NMR spectroscopy

    Energy Technology Data Exchange (ETDEWEB)

    Trewhella, M.J.; Poplett, I.J.F.; Grint, A.

    1986-04-01

    A sample of kerogen isolated from a Green River oil shale has been examined using high resolution solid state /sup 13/C NMR spectroscopy. The relative concentrations of carbon types have been determined using a novel peak-synthesis technique applied to the /sup 13/C spectra. This technique has been successfully applied in determining the amount and type of individual carbon atoms in a sample of Green River oil shale kerogen, with sufficient resolution to enable an average structure to be proposed. The kerogen is highly aliphatic and appears to contain substantial quantities of both saturated polycondensed ring structures, and long chain n-alkanes or n-alkyl substituents. 20 references.

  11. Decaking of coal or oil shale during pyrolysis in the presence of iron oxides

    Science.gov (United States)

    Khan, M. Rashid

    1989-01-01

    A method for producing a fuel from the pyrolysis of coal or oil shale in the presence of iron oxide in an inert gas atmosphere. The method includes the steps of pulverizing feed coal or oil shale, pulverizing iron oxide, mixing the pulverized feed and iron oxide, and heating the mixture in a gas atmosphere which is substantially inert to the mixture so as to form a product fuel, which may be gaseous, liquid and/or solid. The method of the invention reduces the swelling of coals, such as bituminous coal and the like, which are otherwise known to swell during pyrolysis.

  12. GIS-and Web-based Water Resource Geospatial Infrastructure for Oil Shale Development

    Energy Technology Data Exchange (ETDEWEB)

    Zhou, Wei [Colorado School of Mines, Golden, CO (United States); Minnick, Matthew [Colorado School of Mines, Golden, CO (United States); Geza, Mengistu [Colorado School of Mines, Golden, CO (United States); Murray, Kyle [Colorado School of Mines, Golden, CO (United States); Mattson, Earl [Colorado School of Mines, Golden, CO (United States)

    2012-09-30

    The Colorado School of Mines (CSM) was awarded a grant by the National Energy Technology Laboratory (NETL), Department of Energy (DOE) to conduct a research project en- titled GIS- and Web-based Water Resource Geospatial Infrastructure for Oil Shale Development in October of 2008. The ultimate goal of this research project is to develop a water resource geo-spatial infrastructure that serves as “baseline data” for creating solutions on water resource management and for supporting decisions making on oil shale resource development. The project came to the end on September 30, 2012. This final project report will report the key findings from the project activity, major accomplishments, and expected impacts of the research. At meantime, the gamma version (also known as Version 4.0) of the geodatabase as well as other various deliverables stored on digital storage media will be send to the program manager at NETL, DOE via express mail. The key findings from the project activity include the quantitative spatial and temporal distribution of the water resource throughout the Piceance Basin, water consumption with respect to oil shale production, and data gaps identified. Major accomplishments of this project include the creation of a relational geodatabase, automated data processing scripts (Matlab) for database link with surface water and geological model, ArcGIS Model for hydrogeologic data processing for groundwater model input, a 3D geological model, surface water/groundwater models, energy resource development systems model, as well as a web-based geo-spatial infrastructure for data exploration, visualization and dissemination. This research will have broad impacts of the devel- opment of the oil shale resources in the US. The geodatabase provides a “baseline” data for fur- ther study of the oil shale development and identification of further data collection needs. The 3D geological model provides better understanding through data interpolation and

  13. Oil shale project: run summary for small retort Run S-11

    Energy Technology Data Exchange (ETDEWEB)

    Sandholtz, W.A.; Ackerman, F.J.; Bierman, A.; Kaehler, M.; Raley, J.; Laswell, B.H.; Tripp, L.J. (eds.)

    1978-06-01

    Results are reported on retort run S-11 conducted to observe the effects of combustion retorting with undiluted air at relatively rapid burn (retorting) rates and to provide a base case for retorting small uniform shale (Anvil Points master batch -2.5 +- 1.3 cm) with undiluted air. It was found that a 0.6 m/sup 3//m/sup 2//minute superficial gas velocity gave an average rate of propagation of the combustion peak of about 2.7 m/day and an average maximum temperature on the centerline of the rubble bed of 1003/sup 0/C. Oil yield was 93 percent of Fischer assay. For small uniform shale particles (-2.5 + 1.3 cm) it is concluded that only small losses in yield (92 percent vs 96 percent in Run S-10) result from high retorting rates. Maximum temperature considerations preclude going to higher rates with undiluted air. Without diluent, a larger air flux would give excessive bed temperatures causing rock melting and potential closure to gas flow. In experimental retorts, another problem of excessive temperatures is potential damage to metal walls and in-situ sensors. No advantage is seen to using recycled off-gas as a combustion gas diluent. Inert diluents (e.g. nitrogen or steam) may be necessary for process control, but the fuel values in the off-gas should best be used for energy recovery rather than burned in the retort during recycle. Another consideration from model calculations is that the use of recycle gas containing fuel components retards the retorting rate and so is undesirable. No further recycle experiments are planned as the results of this run proved satisfactory.

  14. Enhanced Oil Recovery with Application of Enzymes

    DEFF Research Database (Denmark)

    Khusainova, Alsu

    Enzymes have recently been reported as effective enhanced oil recovery (EOR) agents. Both laboratory and field tests demonstrated significant increase in the ultimate oil production. Up to16% of additional oil was produced in the laboratory conditions and up to 269 barrels of additional oil per day...... were recovered in the field applications. The following mechanisms were claimed to be responsible for the enhancement of the oil production due to enzymes: wettability improvement of the rock surface; formation of the emulsions; reduction of oil viscosity; and removal of high molecular weight paraffins....... However, the positive effect of enzymes on oil recovery is not that obvious. In most of the studies commercial enzyme products composed of enzymes, surfactants and stabilisers were used. Application of such samples makes it difficult to assign a positive EOR effect to a certain compound, as several...

  15. Pressurized Fluidized-Bed Hydroretorting of eastern oil shales. Final report, June 1992--January 1993

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Mensinger, M.C.; Erekson, E.J.; Rue, D.M.; Lau, F.S. [Institute of Gas Technology, Chicago, IL (United States); Schultz, C.W.; Hatcher, W.E. [Alabama Univ., University, AL (United States). Mineral Resources Inst.; Parekh, B.K. [Kentucky Univ., Lexington, KY (United States). Center for Applied Energy Research; Bonner, W.P. [Tennessee Technological Univ., Cookeville, TN (United States)

    1993-03-01

    The Devonian oil shales of the Eastern United States are a significant domestic energy resource. The overall objective of the multi-year program, initiated in September 1987 by the US Department of Energy was to perform the research necessary to develop the pressurized fluidized-bed hydroretorting (PFH) process for producing oil from Eastern oil shales. The program also incorporates research on technologies in areas such as raw shale preparation, beneficiation, product separation and upgrading, and waste disposal that have the potential of improving the economics and/or environmental acceptability of recovering oil from oil shales using the PFH process. The program was divided into the following active tasks: Task 3 -- Testing of Process Improvement Concepts; Task 4 -- Beneficiation Research; Task 6 -- Environmental Data and Mitigation Analyses; and Task 9 -- Information Required for the National Environmental Policy Act. In order to accomplish all of the program objectives, tho Institute of Gas Technology (ICT), the prime contractor, worked with four other institutions: The University of Alabama/Mineral Resources Institute (MRI), the University of Alabama College of Engineering (UA), University of Kentucky Center for Applied Energy Research (UK-CAER), and Tennessee Technological University (TTU). This report presents the work performed by IGT from June 1, 1992 through January 31, 1993.

  16. Western oil-shale development: a technology assessment. Volume 6: oil-shale development in the Piceance Creek Basin and potential water-quality changes

    Energy Technology Data Exchange (ETDEWEB)

    1982-01-01

    This report brackets the stream quality changes due to pre-mining pumping activites required to prepare oil shale lease Tracts C-a and C-b for modified in situ retorting. The fluxes in groundwater discharged to the surface were identified for Tract C-b in a modeling effort by another laboratory. Assumed fluxes were used for Tract C-a. The quality of the groundwater aquifers of the Piceance Basin is assumed to be that reported in the literature. The changes are bracketed in this study by assuming all premining pumping is discharged to the surface stream. In one case, the pumped water is assumed to be of a quality like that of the upper aquifer with a relatively high quality. In the second case, the pumped water is assumed to come from the lower aquifer. Complete mixing and conservation of pollutants was assumed at sample points at the White River and at Lees Ferry of the Colorado River. A discussion of possible secondary effects of oil shale and coal mining is presented. In addition, a discussion of the uncertainties associated with the assumptions used in this study and alternative uses for the water to prevent stream contamination by oil shale development is provided.

  17. Viability of Biopolymers for Enhanced Oil Recovery

    NARCIS (Netherlands)

    Sveistrup, Marte; van Mastrigt, Frank; Norrman, Jens; Picchioni, Francesco; Paso, Kristofer

    2016-01-01

    Xanthan gum and scleroglucan are assessed as environmentally friendly enhanced oil recovery (EOR) agents. Viscometric and interfacial tension measurements show that the polysaccharides exhibit favorable viscosifying performance, robust shear tolerance, electrolyte tolerance, and moderate

  18. Hydrologic monitoring program, Rifle Oil Shale Facility Site, Colorado. Progress report

    Energy Technology Data Exchange (ETDEWEB)

    Ecker, R.M.; Walters, W.H.; Skaggs, R.L.

    1979-10-01

    A hydrologic monitoring and assessment program is being developed to investigate the hydrologic characteristics of surface and ground waters in the region of the Anvil Points, Colorado, Rifle Oil Shale Facility. The objectives of the program are to: evaluate ground-water contributions to study streams; assess contaminant transport capability of surface and ground waters; determine peak discharge magnitude and frequency relationships for use in designing possible spent oil shale disposal works; and assess the impact of specified hypothetical problems, events, or scenarios. To accomplish these objectives, seven major tasks have been identified: (1) literature review of existing studies dealing with the regional, hydrological, physiographical, geological, and climatological characteristics; (2) ground-water characterization; (3) drainage basin characteristics and channel geometry; (4) streamflow and sediment transport; (5) stream travel times; (6) analysis of spent shale disposal; and (7) support of water quality sample collection.

  19. Paleontological overview of oil shale and tar sands areas in Colorado, Utah, and Wyoming.

    Energy Technology Data Exchange (ETDEWEB)

    Murphey, P. C.; Daitch, D.; Environmental Science Division

    2009-02-11

    In August 2005, the U.S. Congress enacted the Energy Policy Act of 2005, Public Law 109-58. In Section 369 of this Act, also known as the ''Oil Shale, Tar Sands, and Other Strategic Unconventional Fuels Act of 2005,'' Congress declared that oil shale and tar sands (and other unconventional fuels) are strategically important domestic energy resources that should be developed to reduce the nation's growing dependence on oil from politically and economically unstable foreign sources. In addition, Congress declared that both research- and commercial-scale development of oil shale and tar sands should (1) be conducted in an environmentally sound manner using management practices that will minimize potential impacts, (2) occur with an emphasis on sustainability, and (3) benefit the United States while taking into account concerns of the affected states and communities. To support this declaration of policy, Congress directed the Secretary of the Interior to undertake a series of steps, several of which are directly related to the development of a commercial leasing program for oil shale and tar sands. One of these steps was the completion of a programmatic environmental impact statement (PEIS) to analyze the impacts of a commercial leasing program for oil shale and tar sands resources on public lands, with an emphasis on the most geologically prospective lands in Colorado, Utah, and Wyoming. For oil shale, the scope of the PEIS analysis includes public lands within the Green River, Washakie, Uinta, and Piceance Creek Basins. For tar sands, the scope includes Special Tar Sand Areas (STSAs) located in Utah. This paleontological resources overview report was prepared in support of the Oil Shale and Tar Sands Resource Management Plan Amendments to Address Land Use Allocations in Colorado, Utah, and Wyoming and PEIS, and it is intended to be used by Bureau of Land Management (BLM) regional paleontologists and field office staff to support future

  20. Shale Gas and Tight Oil: A Panacea for the Energy Woes of America?

    Science.gov (United States)

    Hughes, J. D.

    2012-12-01

    Shale gas has been heralded as a "game changer" in the struggle to meet America's demand for energy. The "Pickens Plan" of Texas oil and gas pioneer T.Boone Pickens suggests that gas can replace coal for much of U.S. electricity generation, and oil for, at least, truck transportation1. Industry lobby groups such as ANGA declare "that the dream of clean, abundant, home grown energy is now reality"2. In Canada, politicians in British Columbia are racing to export the virtual bounty of shale gas via LNG to Asia (despite the fact that Canadian gas production is down 16 percent from its 2001 peak). And the EIA has forecast that the U.S. will become a net exporter of gas by 20213. Similarly, recent reports from Citigroup and Harvard suggest that an oil glut is on the horizon thanks in part to the application of fracking technology to formerly inaccessible low permeability tight oil plays. The fundamentals of well costs and declines belie this optimism. Shale gas is expensive gas. In the early days it was declared that "continuous plays" like shale gas were "manufacturing operations", and that geology didn't matter. One could drill a well anywhere, it was suggested, and expect consistent production. Unfortunately, Mother Nature always has the last word, and inevitably the vast expanses of purported potential shale gas resources contracted to "core" areas, where geological conditions were optimal. The cost to produce shale gas ranges from 4.00 per thousand cubic feet (mcf) to 10.00, depending on the play. Natural gas production is a story about declines which now amount to 32% per year in the U.S. So 22 billion cubic feet per day of production now has to be replaced each year to keep overall production flat. At current prices of 2.50/mcf, industry is short about 50 billion per year in cash flow to make this happen4. As a result I expect falling production and rising prices in the near to medium term. Similarly, tight oil plays in North Dakota and Texas have been heralded

  1. CORE-BASED INTEGRATED SEDIMENTOLOGIC, STRATIGRAPHIC, AND GEOCHEMICAL ANALYSIS OF THE OIL SHALE BEARING GREEN RIVER FORMATION, UINTA BASIN, UTAH

    Energy Technology Data Exchange (ETDEWEB)

    Lauren P. Birgenheier; Michael D. Vanden Berg,

    2011-04-11

    An integrated detailed sedimentologic, stratigraphic, and geochemical study of Utah's Green River Formation has found that Lake Uinta evolved in three phases (1) a freshwater rising lake phase below the Mahogany zone, (2) an anoxic deep lake phase above the base of the Mahogany zone and (3) a hypersaline lake phase within the middle and upper R-8. This long term lake evolution was driven by tectonic basin development and the balance of sediment and water fill with the neighboring basins, as postulated by models developed from the Greater Green River Basin by Carroll and Bohacs (1999). Early Eocene abrupt global-warming events may have had significant control on deposition through the amount of sediment production and deposition rates, such that lean zones below the Mahogany zone record hyperthermal events and rich zones record periods between hyperthermals. This type of climatic control on short-term and long-term lake evolution and deposition has been previously overlooked. This geologic history contains key points relevant to oil shale development and engineering design including: (1) Stratigraphic changes in oil shale quality and composition are systematic and can be related to spatial and temporal changes in the depositional environment and basin dynamics. (2) The inorganic mineral matrix of oil shale units changes significantly from clay mineral/dolomite dominated to calcite above the base of the Mahogany zone. This variation may result in significant differences in pyrolysis products and geomechanical properties relevant to development and should be incorporated into engineering experiments. (3) This study includes a region in the Uinta Basin that would be highly prospective for application of in-situ production techniques. Stratigraphic targets for in-situ recovery techniques should extend above and below the Mahogany zone and include the upper R-6 and lower R-8.

  2. Geological settings of the protected Selisoo mire (northeastern Estonia threatened by oil shale mining

    Directory of Open Access Journals (Sweden)

    Helen Hiiemaa

    2014-05-01

    Full Text Available The protected Selisoo mire in northeastern Estonia is located above valuable oil shale resources, partly in the permitted mining area. We describe in detail the geomorphology and geological setting of the mire to understand the natural preconditions for its formation, development and preservation. We used the LiDAR-based digital elevation model for relief analysis, mapped the peat thickness with ground-penetrating radar and described the Quaternary cover through corings. Ridges, oriented perpendicular to the generally southward-sloping terrain, and shallow depressions at the surface of mineral soil have influenced mire formation and its spatio-temporal dynamics. The Quaternary cover under the mire is thin and highly variable. Therefore the mire is hydro­geologically insufficiently isolated from the limestone bedrock that is drained by the nearby oil shale mine and consequently the mining activities approaching the mire may have a negative influence on the wetland and proposed Natura 2000 site. Natura 2000 type wetlands, both protected or currently outside the nature reserves, cover a significant portion of the prospective oil shale mining areas. The distribution and resilience of those sites may significantly influence further utilization of oil shale resources.

  3. Free and sulphurized hopanoids and highly branched isoprenoids in immature lacustrine oil shales

    NARCIS (Netherlands)

    Sinninghe Damsté, J.S.; Las Heras, F.X.C. de; Grimalt, J.O.; Lopez, J.F.; Albaiges, J.; Leeuw, J.W. de

    1997-01-01

    A study of the solvent extracts of four samples from two immature oil shales from Tertiary lacustrine basins, Ribesalbes and Campins (southern European rift system), deposited under reducing conditions, has allowed the identification of S-containing hopanoids and novel highly branched isoprenoids

  4. Microbial Deterioration of Hydrocarbon Fuels from Oil Shale, Coal, and Petroleum. I. Exploratory Experiments.

    Science.gov (United States)

    1979-08-20

    Cladosporium resinae , a yeast (Candida) and a bacterium (Pseudomonas) which normally grow well in association with petroleum JP-5 were used as test organisms...microorganisms that could thrive in the presence of synthetic fuels. This endeavor produced a strain of C. resinae that grew as well with oil shale JP-5

  5. Organic geochemical characteristics of the Paleocene-Eocene oil shales in the Nallihan Region, Ankara, Turkey

    Energy Technology Data Exchange (ETDEWEB)

    Sari, Ali [Ankara University, Faculty of Engineering, Department of Geological Engineering, 06100, Tandogan, Ankara (Turkey); Aliyev, Saday Azadoglu [Ankara University, Science and Technology Research and Application Center, 06100, Tandogan, Ankara (Turkey)

    2006-08-15

    Units of Paleozoic, Mesozoic and Cenozoic age are exposed in the study area which extends along the Sakarya River by the Sarycakaya town of Eskibehir at west and Nallyhan district of Ankara at East. Paleozoic is represented with metamorphites consisting of glaucophane schist, muscovite schist and marble alternations and granites cutting them. The Mesozoic composing of Jurassic-Cretaceous Sogukcam limestones at the northern part of the area is in tectonic contact with other units. The Tertiary is characterized by the Paleocene-Eocene Kizilcay Group which consists of the Beykoy, Camalan and Lacin Formations. The Camalan Formation is composed of sandstone, limestone, oil shale and locally coal bands. In the area, as a result of intense tectonic activity by the late Eocene, sedimentary sequence that compacted within the Paleozoic metamorphic rocks were folded and fractured. The Paleocene-Eocene shales have adequate organic material content to form potential source rocks. In order to determine hydrocarbon potential of the unit, various organic geochemical analysis techniques were performed. According to pyrolysis results (TOC, S{sub 1} and S{sub 2}), the Paleocene-Eocene shales are perfect source rocks for oil. On the basis of Rock-Eval pyrolysis analyses, kerogens are Type I and Type II kerogens. Spore Color Index and T{sub max} evaluations indicate that maturity of the unit is between diagenesis and early mature oil zone and at the beginning of the oil-producing stage. Organic facies of the Paleocene-Eocene shales are A, AB and B. (author)

  6. Combustion for Enhanced Recovery of Light Oil at Medium Pressures

    NARCIS (Netherlands)

    Khoshnevis Gargar, N.

    2014-01-01

    Using conventional production methods, recovery percentages from oil reservoirs range from 5% for difficult oil to 50% for light oil in highly permeable homogeneous reservoirs. To increase the oil recovery factor, enhanced oil recovery (EOR) methods are used. We distinguish EOR that uses chemical

  7. ENHANCED OIL RECOVERY USING LOCAL ALKALINE

    African Journals Online (AJOL)

    user

    secondary recovery processes involves the injection of fluids which ... production wells [18]. Alkaline flooding is not recommended for carbonate reservoirs because of the profusion of calcium and the mixture between the alkaline chemical and the calcium ions can ... role in oil recovery from mixed – wet naturally fractured.

  8. GIS-based Geospatial Infrastructure of Water Resource Assessment for Supporting Oil Shale Development in Piceance Basin of Northwestern Colorado

    Energy Technology Data Exchange (ETDEWEB)

    Zhou, Wei [Colorado School of Mines, Golden, CO (United States) Dept. of Geology and Geological Engineering; Minnick, Matthew D [Colorado School of Mines, Golden, CO (United States) Dept. of Geology and Geological Engineering; Mattson, Earl D [Idaho National Lab. (INL), Idaho Falls, ID (United States); Geza, Mengistu [Colorado School of Mines, Golden, CO (United States) Dept. of Cilvil and Environmental Engineering; Murray, Kyle E. [Univ. of Oklahoma, Norman, OK (United States) Oklahoma Geological Survey

    2015-04-01

    Oil shale deposits of the Green River Formation (GRF) in Northwestern Colorado, Southwestern Wyoming, and Northeastern Utah may become one of the first oil shale deposits to be developed in the U.S. because of their richness, accessibility, and extensive prior characterization. Oil shale is an organic-rich fine-grained sedimentary rock that contains significant amounts of kerogen from which liquid hydrocarbons can be produced. Water is needed to retort or extract oil shale at an approximate rate of three volumes of water for every volume of oil produced. Concerns have been raised over the demand and availability of water to produce oil shale, particularly in semiarid regions where water consumption must be limited and optimized to meet demands from other sectors. The economic benefit of oil shale development in this region may have tradeoffs within the local and regional environment. Due to these potential environmental impacts of oil shale development, water usage issues need to be further studied. A basin-wide baseline for oil shale and water resource data is the foundation of the study. This paper focuses on the design and construction of a centralized geospatial infrastructure for managing a large amount of oil shale and water resource related baseline data, and for setting up the frameworks for analytical and numerical models including but not limited to three-dimensional (3D) geologic, energy resource development systems, and surface water models. Such a centralized geospatial infrastructure made it possible to directly generate model inputs from the same database and to indirectly couple the different models through inputs/outputs. Thus ensures consistency of analyses conducted by researchers from different institutions, and help decision makers to balance water budget based on the spatial distribution of the oil shale and water resources, and the spatial variations of geologic, topographic, and hydrogeological Characterization of the basin. This endeavor

  9. Reduction and phenol acid depolymerization of Western US oil shale kerogen

    Energy Technology Data Exchange (ETDEWEB)

    Solash, J.; Cronauer, D.C.; Kobylinski, T.P.

    1983-02-01

    The chemical structure of U.S. Western oil shale kerogen is not known with certainty. Many structure studies employed strong oxidants to degrade kerogen. Acidic products are isolated and analyzed. In most cases, relatively small amounts of material are analyzed. Structural inferences from analysis of small quantities (generally less than 20% of kerogen) of degraded material are apt to be misleading. The literature is in conflict regarding even basic structural features of kerogen. Yen and coworkers have used X-ray analysis to deduce that kerogens contain very little aromatic material. However, /sup 13/C CP/MAS nmr measurements show that Western kerogens are 20-30% aromatic. The structure of nitrogen containing moieties is also in doubt. It has been suggested (8) that tetrapyrroles in kerogen pyrolyze to yield pyridines, quinolines, and other classes of nitrogeneous compounds found in shale oil. No quantitative data were given. Pyrolysis of simple pyrroles was found to give low yields of pyridines. Pyridines and quinolines are the major nitrogen-containing species in distillate shale oils. The authors' approach is to attempt to degrade Western U.S. oil shale kerogen under mild conditions. There has been a report of reducing kerogen using dissolving metals. Jones and Dickert reported that treating Colorado oil shale kerogen with lithium aluminum hydride, Hl, or lithium in ethylene diamine were all ineffective in increasing kerogen solubility. Interestingly, HI has been reported to convert kukersite to 100% ether and benzene solubles. No data were reported on the possible extent of reduction with lithium in ethylene diamine. The authors report results of treating kerogen with several well-known reagents.

  10. Shale oil value enhancement research. Quarterly report, March 1 - May 31, 1994

    Energy Technology Data Exchange (ETDEWEB)

    NONE

    1994-12-31

    Activities during this quarter focused on integrating the various tasks and elements. During Phase-1, substantial effort was placed on designing and automating the identification of molecular types present in shale oil. The ability to know the molecular composition and to track a given ``target`` species through the initial concentration steps was deemed critically important to the ultimate success of the three-phase project. It has been this molecular tracking ability that clearly distinguishes the JWBA work from prior shale oil research. The major software and hardware tasks are not in place to rapidly perform these analytical efforts. Software improvements are expected as new questions arise. The existence of the major nitrogen and oxygen types in shale oil has been confirmed. Most importantly, the ability to convert higher molecular weight types to lower molecular weight types was preliminarily confirmed in the present quarter. This is significant because it confirms earlier hypothesis that values are found though out the boiling range. Potential yields of extremely high value chemicals, e.g., $1000/bbl of up to 10% by weight of the barrel remain a feasible objective. Market and economic assessment continue to show encouraging results. Markets for specialty and fine chemicals containing a nitrogen atom are expanding both in type and application. Initial discussions with pharmaceutical and agrochemical industries show a strong interest in nitrogen-based compounds. Major progress was made during this quarter in completing agreements with industry for testing of shale oil components for biological activity. Positive results of such testing will add to the previously known applications of shale oil components as pure compounds and concentrates. During this quarter, we will formulate the pilot plant strategy for Phase-11(a).

  11. Molecular characterization and comparison of shale oils generated by different pyrolysis methods using FT-ICR mass spectrometry

    Science.gov (United States)

    Jin, J.M.; Kim, S.; Birdwell, J.E.

    2011-01-01

    Fourier transform ion cyclotron resonance mass spectrometry (FT ICR-MS) was applied in the analysis of shale oils generated using two different pyrolysis systems under laboratory conditions meant to simulate surface and in situ oil shale retorting. Significant variations were observed in the shale oils, particularly the degree of conjugation of the constituent molecules. Comparison of FT ICR-MS results to standard oil characterization methods (API gravity, SARA fractionation, gas chromatography-flame ionization detection) indicated correspondence between the average Double Bond Equivalence (DBE) and asphaltene content. The results show that, based on the average DBE values and DBE distributions of the shale oils examined, highly conjugated species are enriched in samples produced under low pressure, high temperature conditions and in the presence of water.

  12. Recovery rates, enhanced oil recovery and technological limits.

    Science.gov (United States)

    Muggeridge, Ann; Cockin, Andrew; Webb, Kevin; Frampton, Harry; Collins, Ian; Moulds, Tim; Salino, Peter

    2014-01-13

    Enhanced oil recovery (EOR) techniques can significantly extend global oil reserves once oil prices are high enough to make these techniques economic. Given a broad consensus that we have entered a period of supply constraints, operators can at last plan on the assumption that the oil price is likely to remain relatively high. This, coupled with the realization that new giant fields are becoming increasingly difficult to find, is creating the conditions for extensive deployment of EOR. This paper provides a comprehensive overview of the nature, status and prospects for EOR technologies. It explains why the average oil recovery factor worldwide is only between 20% and 40%, describes the factors that contribute to these low recoveries and indicates which of those factors EOR techniques can affect. The paper then summarizes the breadth of EOR processes, the history of their application and their current status. It introduces two new EOR technologies that are beginning to be deployed and which look set to enter mainstream application. Examples of existing EOR projects in the mature oil province of the North Sea are discussed. It concludes by summarizing the future opportunities for the development and deployment of EOR.

  13. Development of Nuclear Renewable Oil Shale Systems for Flexible Electricity and Reduced Fossil Fuel Emissions

    Energy Technology Data Exchange (ETDEWEB)

    Daniel Curtis; Charles Forsberg; Humberto Garcia

    2015-05-01

    We propose the development of Nuclear Renewable Oil Shale Systems (NROSS) in northern Europe, China, and the western United States to provide large supplies of flexible, dispatchable, very-low-carbon electricity and fossil fuel production with reduced CO2 emissions. NROSS are a class of large hybrid energy systems in which base-load nuclear reactors provide the primary energy used to produce shale oil from kerogen deposits and simultaneously provide flexible, dispatchable, very-low-carbon electricity to the grid. Kerogen is solid organic matter trapped in sedimentary shale, and large reserves of this resource, called oil shale, are found in northern Europe, China, and the western United States. NROSS couples electricity generation and transportation fuel production in a single operation, reduces lifecycle carbon emissions from the fuel produced, improves revenue for the nuclear plant, and enables a major shift toward a very-low-carbon electricity grid. NROSS will require a significant development effort in the United States, where kerogen resources have never been developed on a large scale. In Europe, however, nuclear plants have been used for process heat delivery (district heating), and kerogen use is familiar in certain countries. Europe, China, and the United States all have the opportunity to use large scale NROSS development to enable major growth in renewable generation and either substantially reduce or eliminate their dependence on foreign fossil fuel supplies, accelerating their transitions to cleaner, more efficient, and more reliable energy systems.

  14. A dual-porosity model for simulating solute transport in oil shale

    Science.gov (United States)

    Glover, K.C.

    1987-01-01

    A model is described for simulating three-dimensional groundwater flow and solute transport in oil shale and associated geohydrologic units. The model treats oil shale as a dual-porosity medium by simulating flow and transport within fractures using the finite-element method. Diffusion of solute between fractures and the essentially static water of the shale matrix is simulated by including an analytical solution that acts as a source-sink term to the differential equation of solute transport. While knowledge of fracture orientation and spacing is needed to effectively use the model, it is not necessary to map the locations of individual fractures. The computer program listed in the report incorporates many of the features of previous dual-porosity models while retaining a practical approach to solving field problems. As a result the theory of solute transport is not extended in any appreciable way. The emphasis is on bringing together various aspects of solute transport theory in a manner that is particularly suited to the unusual groundwater flow and solute transport characteristics of oil shale systems. (Author 's abstract)

  15. Application des fluides supercritiques à la production d'hydrocarbures. Exploitation des gisements par récupération assistée et applications diverses : pétrole, sables, schistes, charbons Application of Supercritical Fluids to Hydrocarbon Production. Enhanced Oi Recovery and Miscellaneous Applications: Oil, Tar Sands, Shales, Coals

    Directory of Open Access Journals (Sweden)

    Behar E.

    2006-11-01

    dioxide. This article briefly describes the ranges of application and the thermodynamic mechanisms involved. Sources of available supercritical fluids in the vicinity of oil fields are quickly reviewed together with various operational problems. In addition to being used for enhanced recovery, supercritical fluids are also involved in various refining and extraction processes. The first industrial application was the process for deasphalting heavy petroleum fractions in 1956, making use of the great variations in the solvent power of a fluid in the vicinity of its critical point. This process has received revived interest in recent years because of the energy saving it entails. Likewise, oil shales, tar sands and coals, which are appreciable hydrocarbon sources for the future, are fields of potential applications for supercritical fluids. Specific processes are reviewed, most of which are undergoing pilot-plant development.

  16. Economic recovery and processing of posidonia shale in the investigation area of Schandelah. Wirtschaftliche Gewinnunug und Verwertung von Posidonienschiefer des Untersuchungsgebietes Schandelah

    Energy Technology Data Exchange (ETDEWEB)

    Kruk, H.U.; Czibulinski, U.; Schulze, R.; Harjung, J.; Frohnert, H.; Orlowski, W.; Drescher, J.; Ebert, L.; Ernst, H.; Schmitz, H.H.

    1983-07-01

    The object of the investigations, which took several years, was to test most up-to-date technologies in the fields of mining and chemical process engineering applied to posidonia shale of the Schandelah deposit type with regard to an economic recovery and processing of this primary energy source in the Braunschweig-Wolfsburg-Koenigslutter area. The results have shown that about two billion tons of oil shale can be exploited and possibly commercially utilized in this area. The importance of these results is given by the fact that in this economic domain a primary energy source with a thermal value of about 8.2 EJ has been detected, which can produce at least 100 million tons of syncrude. If this deposit is to be used for producing electrical energy it can provide about 800 TWh.

  17. Eo-Oligocene Oil Shales of the Talawi, Lubuktaruk, and Kiliranjao Areas, West Sumatra: Are they potential source rocks?

    Directory of Open Access Journals (Sweden)

    M. Iqbal

    2014-12-01

    Full Text Available DOI:10.17014/ijog.v1i3.198To anticipate the increasing energy demand, additional data and information covering unconventional fossil fuels such as oil shale must be acquired to promote the usage of alternative energy sources to crude oil. The Talawi and Lubuktaruk regions situated within intra-montane Ombilin Basin, and the Kiliranjao assumed to be a small intra montane basin are occupied by Eo-Oligocene sediments of Sangkarewang and Kiliran Formations, respectively. Field activity, geochemical screening techniques, and organic petrographic analysis, supported by SEM mode, are methods used. Most of the oil shale sequence is typically of an organically rich-succession comprising predominantly well-bedded, laminated and fissile, brownish to dark grey organic-rich shale and mudstone rocks. The exinite macerals within oil shale comprise mainly Pediastrum-lamalginite with minor cutinite, resinite, liptodetrinite, sporinite, bituminite, and rare Botryococcus-telalginite. Therefore; the oil shale deposits can be described as “lamosites”. Minor vitrinite maceral is also recognized. TOC analysis on selected shale samples corresponds to a fair up to excellent category of source rock characterization. The hydrogen index (HI for all samples shows a range of values from 207 - 864, and pyrolysis yield (PY ranges from 2.67 to 79.72 mg HC/g rock. The kerogen is suggested to be of mixed Type II and Type I autochthonous materials such as alginite, with minor allochthonous substances. Oil samples collected appear to be positioned within more oil prone rather than gas prone. Thermal maturity of the oil shales gained from Tmax value and production index (PI tends to show immature to marginally/early mature stage. A consistency in the thermal maturity level results by using both Tmax and vitrinite reflectance value is recognized. On the basis of  SEM analysis, the oil shale has undergone a late eodiagenetic process. Thereby, overall, vitrinite reflectance

  18. Biosurfactants and their role in oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    McInerney, Michael J. [University of Oklahoma (United States)

    2011-07-01

    This paper presents the role of biosurfactants in oil recovery. Types of biosurfactants include, among others, lipopeptides, rhamnolipids, sophorolipids. The process of oil recovery and the involvement of microbes are explained. The objective is to know if lipopeptide biosurfactants lower interfacial tension. Fatty acid composition is important for lipopeptide biosurfactant activity and microbial surfactants are hydrophilic and Interfacial Tension (IFT) values are high. Examples of biosurfactants with lower IFT values with mixtures are also given. An experiment was conducted to determine whether lipopeptides recovery entrapped oil or not. The procedure and experimental setup are shown. It is seen that with higher concentration of biosurfactants, the percentage of residual oil recovery is higher. Another experiment was conducted to see if biosurfactants greater than 40 mg/l can be produced in oil reservoirs. The experimental design and the analysis with the results are given. It was seen that more oil was produced. Conclusions from the study were, among other findings, that, in situ biosurfactant production and inoculation are possible.

  19. Characterization of oil shale, isolated kerogen, and post-pyrolysis residues using advanced 13 solid-state nuclear magnetic resonance spectroscopy

    Science.gov (United States)

    Cao, Xiaoyan; Birdwell, Justin E.; Chappell, Mark A.; Li, Yuan; Pignatello, Joseph J.; Mao, Jingdong

    2013-01-01

    Characterization of oil shale kerogen and organic residues remaining in postpyrolysis spent shale is critical to the understanding of the oil generation process and approaches to dealing with issues related to spent shale. The chemical structure of organic matter in raw oil shale and spent shale samples was examined in this study using advanced solid-state 13C nuclear magnetic resonance (NMR) spectroscopy. Oil shale was collected from Mahogany zone outcrops in the Piceance Basin. Five samples were analyzed: (1) raw oil shale, (2) isolated kerogen, (3) oil shale extracted with chloroform, (4) oil shale retorted in an open system at 500°C to mimic surface retorting, and (5) oil shale retorted in a closed system at 360°C to simulate in-situ retorting. The NMR methods applied included quantitative direct polarization with magic-angle spinning at 13 kHz, cross polarization with total sideband suppression, dipolar dephasing, CHn selection, 13C chemical shift anisotropy filtering, and 1H-13C long-range recoupled dipolar dephasing. The NMR results showed that, relative to the raw oil shale, (1) bitumen extraction and kerogen isolation by demineralization removed some oxygen-containing and alkyl moieties; (2) unpyrolyzed samples had low aromatic condensation; (3) oil shale pyrolysis removed aliphatic moieties, leaving behind residues enriched in aromatic carbon; and (4) oil shale retorted in an open system at 500°C contained larger aromatic clusters and more protonated aromatic moieties than oil shale retorted in a closed system at 360°C, which contained more total aromatic carbon with a wide range of cluster sizes.

  20. Recovery of waterflood residual oil

    Energy Technology Data Exchange (ETDEWEB)

    Orkiszewski, J.

    1966-03-15

    This is a method of recovering additional oil from a reservoir that has been depleted both by primary production and then by waterflooding. A bank of solvent is injected into the reservoir through an injection well. The solvent is followed with the injection of a scavenging and propelling fluid. Oil is withdrawn from the production wells. The solvent consists of a blend of liquid propane and a highly viscous distillate oil. The distillate oil has a true boiling range between 680-1,250$F and a viscosity of 200-6,000 cp at 100$F. The blend consists of 60-90% propane by volume, and the scavenging fluid can be water. (7 claims)

  1. Fundamentals of tertiary oil recovery. Pt. 1. Why tertiary recovery

    Energy Technology Data Exchange (ETDEWEB)

    Herbeck, E.F.; Heintz, R.C.; Hastings, J.R.

    1976-01-01

    Secondary recovery projects initiated annually by Atlantic Richfield Co. in the U.S. show a general trend somewhat characteristic of all U.S. producers. Why did the number of project starts decline. Simply because there was a lack of prospects for Atlantic Richfield to apply waterflooding economically. This raises the question of what is the next step to maintain U.S. oil producing rates. One answer is to recover a third crop of oil from those fields which have already undergone secondary recovery. It is becoming evident that tertiary recovery must be undertaken while the existing wells and surface equipment are still intact and usable. Very few prospects are expected to be so profitable that economics will permit redrilling of wells and replacement of surface equipment, but tertiary recovery will be applicable to many of the existing oil fields. Engineers and production personnel at all organizational levels must make an effort to recognize those fields under their supervision which are candidates for tertiary recovery applications.

  2. Retardation effect of nitrogen compounds and condensed aromatics on shale oil catalytic cracking processing and their characterization.

    Science.gov (United States)

    Li, Nan; Chen, Chen; Wang, Bin; Li, Shaojie; Yang, Chaohe; Chen, Xiaobo

    Untreated shale oil, shale oil treated with HCl aqueous solution and shale oil treated with HCl and furfural were used to do comparative experiments in fixed bed reactors. Nitrogen compounds and condensed aromatics extracted by HCl and furfural were characterized by electrospray ionization Fourier transform cyclotron resonance mass spectrometry and gas chromatography and mass spectrometry, respectively. Compared with untreated shale oil, the conversion and yield of liquid products increased considerably after removing basic nitrogen compounds by HCl extraction. Furthermore, after removing nitrogen compounds and condensed aromatics by both HCl and furfural, the conversion and yield of liquid products further increased. In addition, N 1 class species are predominant in both basic and non-basic nitrogen compounds, and they are probably indole, carbazole, cycloalkyl-carbazole, pyridine and cycloalkyl-pyridine. As for the condensed aromatics, most of them possess aromatic rings with two to three rings and zero to four carbon atom.

  3. Enzymes for Enhanced Oil Recovery (EOR)

    Energy Technology Data Exchange (ETDEWEB)

    Nasiri, Hamidreza

    2011-04-15

    Primary oil recovery by reservoir pressure depletion and secondary oil recovery by waterflooding usually result in poor displacement efficiency. As a consequence there is always some trapped oil remaining in oil reservoirs. Oil entrapment is a result of complex interactions between viscous, gravity and capillary forces. Improving recovery from hydrocarbon fields typically involves altering the relative importance of the viscous and capillary forces. The potential of many EOR methods depends on their influence on fluid/rock interactions related to wettability and fluid/fluid interactions reflected in IFT. If the method has the potential to change the interactions favorably, it may be considered for further investigation, i.e. core flooding experiment, pilot and reservoir implementation. Enzyme-proteins can be introduced as an enhanced oil recovery method to improve waterflood performance by affecting interactions at the oil-water-rock interfaces. An important part of this thesis was to investigate how selected enzymes may influence wettability and capillary forces in a crude oil-brine-rock system, and thus possibly contribute to enhanced oil recovery. To investigate further by which mechanisms selected enzyme-proteins may contribute to enhance oil recovery, groups of enzymes with different properties and catalytic functions, known to be interfacially active, were chosen to cover a wide range of possible effects. These groups include (1) Greenzyme (GZ) which is a commercial EOR enzyme and consists of enzymes and stabilizers (surfactants), (2) The Zonase group consists of two types of pure enzyme, Zonase1 and Zonase2 which are protease enzymes and whose catalytic functions are to hydrolyze (breakdown) peptide bonds, (3) The Novozyme (NZ) group consists of three types of pure enzyme, NZ2, NZ3 and NZ6 which are esterase enzymes and whose catalytic functions are to hydrolyze ester bonds, and (4) Alpha-Lactalbumin ( -La) which is an important whey protein. The effect of

  4. RESEARCH OIL RECOVERY MECHANISMS IN HEAVY OIL RESERVOIRS

    Energy Technology Data Exchange (ETDEWEB)

    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.

  5. Co-Firing Oil Shale with Coal and Other Fuels for Improved Efficiency and Multi-Pollutant Control

    Energy Technology Data Exchange (ETDEWEB)

    Robert A. Carrington; William C. Hecker; Reed Clayson

    2008-06-01

    Oil shale is an abundant, undeveloped natural resource which has natural sorbent properties, and its ash has natural cementitious properties. Oil shale may be blended with coal, biomass, municipal wastes, waste tires, or other waste feedstock materials to provide the joint benefit of adding energy content while adsorbing and removing sulfur, halides, and volatile metal pollutants, and while also reducing nitrogen oxide pollutants. Oil shale depolymerization-pyrolysis-devolatilization and sorption scoping studies indicate oil shale particle sorption rates and sorption capacity can be comparable to limestone sorbents for capture of SO2 and SO3. Additionally, kerogen released from the shale was shown to have the potential to reduce NOx emissions through the well established “reburning” chemistry similar to natural gas, fuel oil, and micronized coal. Productive mercury adsorption is also possible by the oil shale particles as a result of residual fixed-carbon and other observed mercury capture sorbent properties. Sorption properties were found to be a function particle heating rate, peak particle temperature, residence time, and gas-phase stoichmetry. High surface area sorbents with high calcium reactivity and with some adsorbent fixed/activated carbon can be produced in the corresponding reaction zones that exist in a standard pulverized-coal or in a fluidized-bed combustor.

  6. Peculiar high temperature corrosion of martensite alloy under impact of Estonian oil shale fly ash

    Energy Technology Data Exchange (ETDEWEB)

    Tallermo, H.; Klevtsov, I. [Thermal Engineering Department of Tallinn Technical University, Tallinn (Estonia)

    1998-12-31

    The superheaters` surfaces of oil shale steam boiler made of pearlitic and austenitic alloys, are subject to intensive corrosion, mainly due to presence of chlorine in external deposits. The applicability of martensitic alloys X1OCrMoVNb91 and X20CrMoV121 for superheaters is examined here and empirical equations allowing to predict alloys` corrosion resistance in the range of operational temperatures are established. Alloy X1OCrMoVNb91 is found been most perspective for superheaters of boilers firing fossil fuel that contain alkaline metals and chlorine. The abnormal dependence of corrosion resistance of martensitic alloys on temperature is revealed, namely, corrosion at 580 deg C in presence of oil shale fly ash is more intensive than at 620 deg C. (orig.) 2 refs.

  7. Method of design for vertical oil shale retorting vessels and retorting therewith

    Science.gov (United States)

    Reeves, Adam A.

    1978-01-03

    A method of designing the gas flow parameters of a vertical shaft oil shale retorting vessel involves determining the proportion of gas introduced in the bottom of the vessel and into intermediate levels in the vessel to provide for lateral distribution of gas across the vessel cross section, providing mixing with the uprising gas, and determining the limiting velocity of the gas through each nozzle. The total quantity of gas necessary for oil shale treatment in the vessel may be determined and the proportion to be injected into each level is then determined based on the velocity relation of the orifice velocity and its feeder manifold gas velocity. A limitation is placed on the velocity of gas issuing from an orifice by the nature of the solid being treated, usually physical tests of gas velocity impinging the solid.

  8. Tertiary oil recovery: potential application and constraints

    Energy Technology Data Exchange (ETDEWEB)

    Geffen, C. A.

    1978-06-01

    The technology of tertiary oil recovery methods is described and potential economic and environmental constraints to future commercial application are identified. Oil recoverable by tertiary techniques represents a domestic resource of between 11- and 42-billion barrels. Estimates of additional oil supplies from tertiary methods by the year 2000 range from 1 to 8 million barrels per day, depending on the price of oil and the rate of technological development. The principal constraints to large-scale application of tertiary methods at the present time include environmental, economic and technological concerns. Regulatory action associated with the Clean Air Act Amendments of 1977 currently delay the expansion of thermal recovery operations in California and may discourage future projects. The high production costs of tertiary projects also hamper process implementation. Further testing and research is necessary to develop the technology of tertiary recovery methods and prove these techniques successful on a field-wide scale. To enable tertiary oil recovery to play a significant role in augmenting domestic energy supplies, further research and development is necessary. More accurate methods of determining reservoir structure and residual oil saturations are required, as well as means for assuring the technical feasibility and success of a tertiary method in different reservoir types. Technical process limitations must also be resolved. The severity of potential environmental impacts and constraints identified in this report should be determined. These concerns include the air pollutant emissions from steam generation in thermal processes; acceptable methods of brine disposal; damage due to runoff or accidental discharge of oil-rich chemicals into surface waters; the impacts of fluid injection on deep aquifers and the prevailing geological structure; and an adequate supply of high quality fresh water.

  9. Research on Oil Recovery Mechanisms in Heavy Oil Reservoirs

    Energy Technology Data Exchange (ETDEWEB)

    Louis M. Castanier; William E. Brigham

    1998-03-31

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

  10. New pitches with enhanced graphitization ability obtained from Moroccan oil shales

    Energy Technology Data Exchange (ETDEWEB)

    Abourriche, A.; Oumam, M.; Mouhssim, A.; Dahiri, M.; Hannache, H. [Laboratoire des Materiaux Thermostructuraux, Faculte des Sciences Ben Mminutes or feetsik, B.P. 7955, Casablanca (Morocco); Chollon, G.; Pailler, R.; Naslain, R. [Laboratoire des Composites Thermostructuraux, UMR 5801, CNRS-CEA-SNECMA-Universite Bordeaux I, Domaine Universitaire, 3 Allee de la Boetie, F-33600 Pessac (France); Birot, M.; Pillot, J.-P. [Laboratoire de Chimie Organique et Organometallique, UMR 5802, CNRS-Universite Bordeaux I, 351 cours de la Liberation, F-33405 Talence Cedex (France)

    2004-06-01

    New pitches were obtained from the extraction of Moroccan oil shales. Their pyrolysis was studied in the temperature range of 1100-2800C by Raman spectroscopy and X-ray diffraction. The graphitization degree of the resulting carbon was tightly dependent on the composition of the pitch. Moreover, it was shown that phenol was a suitable extraction solvent to produce graphitizable carbon at relatively low temperature (T{>=}1800C)

  11. Separation and identification of petroporphyrins extracted from the oil shales of Tarfaya: geochemical study

    Energy Technology Data Exchange (ETDEWEB)

    Doukkali, A.; Saoiabi, A.; Zrineh, A.; Hamad, M.; Ferhat, M.; Barbe, J.M.; Guilard, R. [Universite Mohammed V Agdal, Rabat (Morocco). Laboratoire de Chimie Physique Generale, Faculte des Sciences de Rabat

    2002-03-01

    Vanadyl and nickel porphyrins were isolated from the oil shales of Tarfaya (Morocco) by extraction followed by column chromatography. The ratios and characteristics of these porphyrin complexes were essentially obtained on the basis of UV-visible and mass spectrometry data. Geochemical information could be drawn from these data. The nature and the contents of the metals coordinated and non-coordinated to porphyrin systems were also determined in this study. 30 refs., 3 figs., 3 tabs.

  12. Shale problems and water-based drilling fluid optimisation in the Hassi Messaoud Algerian oil field

    OpenAIRE

    Khodja, Mohamed; Canselier, Jean-Paul; Bergaya, Faiza; Fourar, Karim; Khodja, Malika; Cohaut, Nathalie; Benmounah, Abdelbaki,

    2010-01-01

    Drilling fluid formulation and properties play a fundamental role in drilling operations. Clay minerals behave initially as a beneficial rheological adjuvant in drilling muds. Nevertheless, the contamination of oil reservoirs by clay minerals present in the drilled geological formation (shales) may generate major problems during drilling as plug formation. In this context, our study deals with the optimisation of drilling conditions in the Hassi Messaoud Algerian field. The mineralogical hete...

  13. Procedure for calculating estimated ultimate recoveries of wells in the Mississippian Barnett Shale, Bend Arch–Fort Worth Basin Province of north-central Texas

    Science.gov (United States)

    Leathers-Miller, Heidi M.

    2017-11-28

    In 2015, the U.S. Geological Survey published an assessment of technically recoverable continuous oil and gas resources of the Mississippian Barnett Shale in the Bend Arch–Fort Worth Basin Province of north-central Texas. Of the two assessment units involved in the overall assessment, one included a roughly equal number of oil wells and gas wells as classified by the U.S. Geological Survey’s standard of gas wells having production greater than or equal to 20,000 cubic feet of gas per barrel of oil and oil wells having production less than 20,000 cubic feet of gas per barrel of oil. As a result, estimated ultimate recoveries (EURs) were calculated for both oil wells and gas wells in one of the assessment units. Generally, only gas EURs or only oil EURs are calculated for an assessment unit. These EURs were calculated with data from IHS MarkitTM using DeclinePlus software in the Harmony interface and were a major component of the quantitative resource assessment. The calculated mean EURs ranged from 235 to 2,078 million cubic feet of gas and 21 to 39 thousand barrels of oil for various subsets of wells.

  14. Recovery of water and minerals from shale gas produced water by membrane distillation crystallization.

    Science.gov (United States)

    Kim, Junghyun; Kim, Jungwon; Hong, Seungkwan

    2017-11-08

    Shale gas produced water (SGPW) treatment imposes greater technical challenges because of its high concentration of various contaminants. Membrane distillation crystallization (MDC) has a great potential to manage SGPW since it is capable of recovering both water and minerals at high rates, up to near a zero liquid discharge (ZLD) condition. To evaluate the feasibility of MDC for SGPW treatment, MDC performance indicators, such as water recovery rate, solid production rate (SPR) and specific energy consumption (SEC), were systematically investigated, to our knowledge for the first time, by using actual SGPW from Eagle Ford Shale (USA). The main operating parameters including feed cross-flow velocity (CFV) and crystallization temperature (TCr) were optimized by performing a series of MDC experiments. The results reported that water and minerals were effectively recovered with 84% of recovery rate and 2.72 kg/m2day of SPR under respective optimal operating conditions. Furthermore, the scale mechanism was firstly identified as limiting factor for MDC performance degradation. Lastly, SEC of MDC was estimated to be as low as 28.2 kWh/m3 under ideal optimal operating conditions. Our experimental observations demonstrated that MDC could sustainably and effectively recover water and mineral with low energy consumption from SGPW by optimizing operating condition. Copyright © 2017 Elsevier Ltd. All rights reserved.

  15. Determination of sulfur anions in spent oil shale leachates by ion chromatography

    Energy Technology Data Exchange (ETDEWEB)

    Niss, N.D.

    1989-07-01

    The leaching and transport of chemical constituents from spent oil shale disposal areas is an area of environmental concern at the present time. Sulfur-containing compounds are prevalent in spent oil shales and have the potential to leach into aqueous systems surrounding disposal sites. Computer modeling has been used in recent years to predict the transport of species in an aqueous environment. The quality of model predictions, however, depends on the validation steps taken in comparing model predictions with laboratory data on ion speciation. Further, the quality of the validation step depends on the reliability of laboratory methods in generating ion speciation data. The purpose of this study was to develop methods to separate and quantify sulfur-containing anions in spent oil shale leachates by suppressed ion chromatography. The anions studied were S{sup 2{minus}} (sulfide), SO{sup 2{minus}}{sub 3} (sulfite), SO{sup 2{minus}}{sub 4} (sulfate), SCN{sup {minus}} (thiocyanate), S{sub 2}O{sup 2{minus}}{sub 3} (thiosulfate), and S{sub 4}O{sup 2{minus}}{sub 6} (tetrathionate). After the separations were developed, a series of method-challenging experiments were performed to test the reliability of the methods and assure the development of an analytically sound product. 24 refs., 7 figs., 5 tabs.

  16. Carbon Isotope Analyses of Individual Hydrocarbon Molecules in Bituminous Coal, Oil Shale and Murchison Meteorite

    Directory of Open Access Journals (Sweden)

    Kyoungsook Kim

    1998-06-01

    Full Text Available To study the origin of organic matter in meteorite, terrestrial rocks which contain organic compounds similar to the ones found in carbonaceous chondrites are studied and compared with Murchison meteorite. Hydrocarbon molecules were extracted by benzene and methanol from bituminous coal and oil shale and the extracts were partitioned into aliphatic, aromatic, and polar fractions by silica gel column chromatography. Carbon isotopic ratios in each fractions were analysed by GC-C-IRMS. Molecular compound identifications were carried by GC-MS Engine. Bituminous coal and oil shale show the organic compound composition similar to that of meteorite. Oil shale has a wide range of δ(13C, -20.1%_0 - -54.4%_0 compared to bituminous coal, -25.2%_0 - -34.3%_0. Delta values of several molecular compounds in two terrestrial samples are different. They show several distinct distributions in isotopic ratios compared to those of meteorite; Murchison meteorite has a range of δ(13C from -13%_0 to +30%_0. These results provide interpretation for the source and the formation condition of each rock, in particular alteration and migration processes of organic matter. Especially, they show an important clue whether some hydrocarbon molecules observed in meteorite are indigenous or not.

  17. Potential impact of tertiary oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Kastrop, J.E.

    1975-11-01

    Tertiary oil recovery is America's energy ace-in-the-hole and the technology developed here over the past decade could well offer the rest of the world a big incremental boost in its future oil supplies. While U.S. producers are carefully engineering fields that have finished secondary phases of oil production, international operators are commencing pressure maintenance projects by water and gas injection, the first stage of improved oil recovery. Oil recovery authorities who have dealt with the problem for decades estimate that from 25 to 50 billion bbl could be recovered by relatively new sophisticated processes initially developed in the research laboratory and tested in the field. There are 4 basic processes that indicate promise of commercial applications. These are (1) hydrocarbon miscible which includes high-pressure gas drive, rich gas or LPG driven by gas; (2) carbon dioxide miscible with CO/sub 2/ driven by gas or water; (3) chemical flooding, such as surfactant, micellar slugs driven by an aqueous polymer solution; and (4) thermal processes.

  18. Research on oil recovery mechanisms in heavy oil reservoirs

    Energy Technology Data Exchange (ETDEWEB)

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

    2000-03-16

    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.

  19. A field laboratory for improved oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    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.

  20. Polar constituents of a shale oil: comparative composition with other fossil-derived liquids

    Energy Technology Data Exchange (ETDEWEB)

    Rubin, I. B.; Goeckner, N. A.; Clark, B. R.

    1979-01-01

    Similarities and differences in the polar portions of a variety of types of fossil fuel oils including oil from shale, from several coal liquefaction processes and from a mixture of natural petroleum crudes are described. Samples were fractionated by acid/base distribution as well as by gel partition chromatography which was then followed by acid/base distribution and adsorption chromatography. One subfraction of particular interest was that obtained from the hydrophilic fraction after gel partition chromatography, extracted into a neutral subfraction, and then eluted from an alumina column by methanol. This subfraction was not gas chromatographable, and was partially characterized by elemental analysis, NMR spectroscopy and infrared spectrophotometry.

  1. Class I cultural resource overview for oil shale and tar sands areas in Colorado, Utah and Wyoming.

    Energy Technology Data Exchange (ETDEWEB)

    O' Rourke, D.; Kullen, D.; Gierek, L.; Wescott, K.; Greby, M.; Anast, G.; Nesta, M.; Walston, L.; Tate, R.; Azzarello, A.; Vinikour, B.; Van Lonkhuyzen, B.; Quinn, J.; Yuen, R.; Environmental Science Division

    2007-11-01

    In August 2005, the U.S. Congress enacted the Energy Policy Act of 2005, Public Law 109-58. In Section 369 of this Act, also known as the 'Oil Shale, Tar Sands, and Other Strategic Unconventional Fuels Act of 2005', Congress declared that oil shale and tar sands (and other unconventional fuels) are strategically important domestic energy resources that should be developed to reduce the nation's growing dependence on oil from politically and economically unstable foreign sources. The Bureau of Land Management (BLM) is developing a Programmatic Environmental Impact Statement (PEIS) to evaluate alternatives for establishing commercial oil shale and tar sands leasing programs in Colorado, Wyoming, and Utah. This PEIS evaluates the potential impacts of alternatives identifying BLM-administered lands as available for application for commercial leasing of oil shale resources within the three states and of tar sands resources within Utah. The scope of the analysis of the PEIS also includes an assessment of the potential effects of future commercial leasing. This Class I cultural resources study is in support of the Draft Oil Shale and Tar Sands Resource Management Plan Amendments to Address Land Use Allocations in Colorado, Utah, and Wyoming and Programmatic Environmental Impact Statement and is an attempt to synthesize archaeological data covering the most geologically prospective lands for oil shale and tar sands in Colorado, Utah, and Wyoming. This report is based solely on geographic information system (GIS) data held by the Colorado, Utah, and Wyoming State Historic Preservation Offices (SHPOs). The GIS data include the information that the BLM has provided to the SHPOs. The primary purpose of the Class I cultural resources overview is to provide information on the affected environment for the PEIS. Furthermore, this report provides recommendations to support planning decisions and the management of cultural resources that could be impacted by future

  2. Ecological risks of shale oil and gas development to wildlife, aquatic resources and their habitats.

    Science.gov (United States)

    Brittingham, Margaret C; Maloney, Kelly O; Farag, Aïda M; Harper, David D; Bowen, Zachary H

    2014-10-07

    Technological advances in hydraulic fracturing and horizontal drilling have led to the exploration and exploitation of shale oil and gas both nationally and internationally. Extensive development of shale resources has occurred within the United States over the past decade, yet full build out is not expected to occur for years. Moreover, countries across the globe have large shale resources and are beginning to explore extraction of these resources. Extraction of shale resources is a multistep process that includes site identification, well pad and infrastructure development, well drilling, high-volume hydraulic fracturing and production; each with its own propensity to affect associated ecosystems. Some potential effects, for example from well pad, road and pipeline development, will likely be similar to other anthropogenic activities like conventional gas drilling, land clearing, exurban and agricultural development and surface mining (e.g., habitat fragmentation and sedimentation). Therefore, we can use the large body of literature available on the ecological effects of these activities to estimate potential effects from shale development on nearby ecosystems. However, other effects, such as accidental release of wastewaters, are novel to the shale gas extraction process making it harder to predict potential outcomes. Here, we review current knowledge of the effects of high-volume hydraulic fracturing coupled with horizontal drilling on terrestrial and aquatic ecosystems in the contiguous United States, an area that includes 20 shale plays many of which have experienced extensive development over the past decade. We conclude that species and habitats most at risk are ones where there is an extensive overlap between a species range or habitat type and one of the shale plays (leading to high vulnerability) coupled with intrinsic characteristics such as limited range, small population size, specialized habitat requirements, and high sensitivity to disturbance

  3. Ecological risks of shale oil and gas development to wildlife, aquatic resources and their habitats

    Science.gov (United States)

    Brittingham, Margaret C.; Maloney, Kelly O.; Farag, Aïda M.; Harper, David D.; Bowen, Zachary H.

    2014-01-01

    Technological advances in hydraulic fracturing and horizontal drilling have led to the exploration and exploitation of shale oil and gas both nationally and internationally. Extensive development of shale resources has occurred within the United States over the past decade, yet full build out is not expected to occur for years. Moreover, countries across the globe have large shale resources and are beginning to explore extraction of these resources. Extraction of shale resources is a multistep process that includes site identification, well pad and infrastructure development, well drilling, high-volume hydraulic fracturing and production; each with its own propensity to affect associated ecosystems. Some potential effects, for example from well pad, road and pipeline development, will likely be similar to other anthropogenic activities like conventional gas drilling, land clearing, exurban and agricultural development and surface mining (e.g., habitat fragmentation and sedimentation). Therefore, we can use the large body of literature available on the ecological effects of these activities to estimate potential effects from shale development on nearby ecosystems. However, other effects, such as accidental release of wastewaters, are novel to the shale gas extraction process making it harder to predict potential outcomes. Here, we review current knowledge of the effects of high-volume hydraulic fracturing coupled with horizontal drilling on terrestrial and aquatic ecosystems in the contiguous United States, an area that includes 20 shale plays many of which have experienced extensive development over the past decade. We conclude that species and habitats most at risk are ones where there is an extensive overlap between a species range or habitat type and one of the shale plays (leading to high vulnerability) coupled with intrinsic characteristics such as limited range, small population size, specialized habitat requirements, and high sensitivity to disturbance

  4. Structure Segmentation and Transfer Faults in the Marcellus Shale, Clearfield County, Pennsylvania: Implications for Gas Recovery Efficiency and Risk Assessment Using 3D Seismic Attribute Analysis

    Science.gov (United States)

    Roberts, Emily D.

    The Marcellus Shale has become an important unconventional gas reservoir in the oil and gas industry. Fractures within this organic-rich black shale serve as an important component of porosity and permeability useful in enhancing production. Horizontal drilling is the primary approach for extracting hydrocarbons in the Marcellus Shale. Typically, wells are drilled perpendicular to natural fractures in an attempt to intersect fractures for effective hydraulic stimulation. If the fractures are contained within the shale, then hydraulic fracturing can enhance permeability by further breaking the already weakened rock. However, natural fractures can affect hydraulic stimulations by absorbing and/or redirecting the energy away from the wellbore, causing a decreased efficiency in gas recovery, as has been the case for the Clearfield County, Pennsylvania study area. Estimating appropriate distances away from faults and fractures, which may limit hydrocarbon recovery, is essential to reducing the risk of injection fluid migration along these faults. In an attempt to mitigate the negative influences of natural fractures on hydrocarbon extraction within the Marcellus Shale, fractures were analyzed through the aid of both traditional and advanced seismic attributes including variance, curvature, ant tracking, and waveform model regression. Through the integration of well log interpretations and seismic data, a detailed assessment of structural discontinuities that may decrease the recovery efficiency of hydrocarbons was conducted. High-quality 3D seismic data in Central Pennsylvania show regional folds and thrusts above the major detachment interval of the Salina Salt. In addition to the regional detachment folds and thrusts, cross-regional, northwest-trending lineaments were mapped. These lineaments may pose a threat to hydrocarbon productivity and recovery efficiency due to faults and fractures acting as paths of least resistance for induced hydraulic stimulation fluids

  5. Remotely Activated Microcapsules for Oil Recovery Treatments

    DEFF Research Database (Denmark)

    Mazurek, Malgorzata Natalia

    -off treatments are extensively investigated, though currently applied materials still suffer from some disadvantages. The main drawback is lack of control over the setting of plugs in the fracture, and this may cause blocking of the injection well and the formation of the plug before placing the material......Water-flooding is a commonly used oil recovery method in mature reservoirs, because injected water enhances oil sweep efficiency and leads to increased oil production. Due to the occurrence of fractures in water-flooded reservoirs, excessive water production is observed. Hence, water shut...... in the fracture. Secondly, only a few developed materials prevent from blocking oil-rich pores, and yet they are not able to create a permanent plug, as they do not form a covalently bonded structure. The aim of the project is to design a novel plugging material which can block fractures without affecting...

  6. 78 FR 18547 - Oil Shale Management-General

    Science.gov (United States)

    2013-03-27

    ... that contain oil or gas that can be produced by hydraulic fracturing. All known technologies to convert... Lease Sale Process As an alternative to publishing a proposed notice of sale, the BLM specifically seeks comments on a possible alternative procedure that would be modeled after a provision in the Federal coal...

  7. HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS

    Energy Technology Data Exchange (ETDEWEB)

    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.

  8. Implementation of an anisotropic mechanical model for shale in Geodyn

    Energy Technology Data Exchange (ETDEWEB)

    Attia, A; Vorobiev, O; Walsh, S

    2015-05-15

    The purpose of this report is to present the implementation of a shale model in the Geodyn code, based on published rock material models and properties that can help a petroleum engineer in his design of various strategies for oil/gas recovery from shale rock formation.

  9. Effect of mineral matter and phenol in supercritical extraction of oil shale with toluene

    Energy Technology Data Exchange (ETDEWEB)

    Abourriche, A.; Ouman, M.; Ichcho, S.; Hannache, H. [Universite Hassan II, Lab. des Materiaux Thermostructuraux, Faculte des Sciences Ben M' Sik, Casablanca (Morocco); Pailler, R.; Naslain, R. [Laboratoire des Composites Thermostructuraux (LCTS), 33 - Pessac (France); Birot, M.; Pillot, J.P. [Bordeaux-1 Univ., Lab. de Chimie Organique et Organometallique, UMR 5802 CNRS, 33 - Talence (France)

    2005-03-01

    In the present work, Tarfaya oil shale was subjected to supercritical toluene extraction. The experimental results obtained show clearly that the mineral matter and phenol have a significant effect on the yield and the composition of the obtained oil. The yield and the composition of oil obtained by toluene+phenol extraction were markedly different from that obtained by toluene. Higher yield and maturation of the obtained oil of the toluene+phenol extraction indicate that the phenol not only acts as an extraction solvent but also reacts with the molecules from kerogen. This can be explained by the presence of a very reactive O-H group able to react with the majority of the kerogen functions.

  10. HEAVY AND THERMAL OIL RECOVERY PRODUCTION MECHANISMS

    Energy Technology Data Exchange (ETDEWEB)

    Anthony R. Kovscek

    2003-01-01

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

  11. Enhanced oil recovery projects data base

    Energy Technology Data Exchange (ETDEWEB)

    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.

  12. Nano- porous proppants for shale oil and gas production

    OpenAIRE

    Ottestad, Eirik

    2014-01-01

    Over the last decade a rapid increase in utilization of unconventional reservoirs ha occurred due to advances in horizontal drilling and multi-stage fracturing technology. Reservoirs that earlier were far beyond commercial reach are today producing oil and gas in competitive manner. The share of energy provided form unconventional reservoirs is projected to keep growing relative to conventional energy sources in the years to come. Proppants are essential component in hydraulic fracturing oper...

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  14. Investigation of the geokinetics horizontal in situ oil shale retorting process. Quarterly report, January, February, March 1981

    Energy Technology Data Exchange (ETDEWEB)

    Hutchinson, D.L.

    1981-05-01

    Retort No. 23 has been heavily instrumented and was ignited on March 16, 1981. A total of 6588 barrels of shale oil have been recovered from Retort No. 24 to date; 6057 barrels of oil were recovered during the quarter, an average of 65 barrels per day. Approximately 4909 barrels of shale oil were shipped by tanker truck to the WESRECO refinery in Salt Lake City, Utah, during the quarter. Drilling of re-entry process and instrumentation wells on Retort No. 25 was completed. A post-burn core sampling program for Retort No. 18 was developed and implemented.

  15. Optimization of huff-n-puff gas injection in shale oil reservoirs

    Directory of Open Access Journals (Sweden)

    James J. Sheng

    2017-12-01

    Full Text Available Earlier studies show that huff-n-puff injection is preferred to continuous gas flooding to improve liquid oil production in shale oil reservoirs. Compared to gas flooding, huff-n-puff has more operational parameters to optimize so that liquid oil production can be maximized. This paper is to discuss the optimum huff-n-puff times, number of cycles and soaking time under practical operational and reservoir conditions. The operational and reservoir conditions dictate the maximum injection and production rates, and the maximum injection pressure and minimum production pressure.The numerical simulation results and discussions show that the optimum huff time is so long that the pressure near the wellbore reaches the set maximum injection pressure during the huff period; and the optimum puff time is the time required for the pressure near the wellbore to reach the set minimum production pressure during the puff period. The benefits of soaking may not compensate the loss in injection and production due to the time lost in the soaking period. Therefore, soaking may not be necessary during the huff-n-puff gas injection in shale oil reservoirs. The number of huff-n-puff cycles is determined when an economic rate cut-off is reached.

  16. Recovery of Vanadium from H2SO4-HF Acidic Leaching Solution of Black Shale by Solvent Extraction and Precipitation

    OpenAIRE

    Xingbin Li; Chang Wei; Zhigan Deng; Cunxiong Li; Gang Fan; Minting Li; Hui Huang

    2016-01-01

    The recovery of vanadium from sulfuric and hydrofluoric mixed acid solutions generated by the direct leaching of black shale was investigated using solvent extraction and precipitation methods. The process consisted of reduction, solvent extraction, and stripping, followed by precipitation and calcination to yield vanadium pentoxide. The influence of various operating parameters on the extraction and recovery of vanadium was studied. Vanadium (IV) was selectively extracted using a mixture of ...

  17. Development and application of a permit information system for shale oil (PERMISSO). Final report appendix: summary sheets of regulations required for oil shale development, June 1978--May 1979

    Energy Technology Data Exchange (ETDEWEB)

    1979-07-01

    This appendix is comprised of summaries of various governmental permits, licenses and other approvals required for oil shale development. The summaries were completed during the period June--October 1978, and are current as of July 1, 1978, although more recent authority was cited in some cases. One of the major purposes of Phase II of the project will be to update these summaries as statutes and regulations are added, changed or eliminated. This updating will be particularly important in the case of environmental permits and approvals. Many legislative and regulatory changes affecting environmental requirements are pending at this time and will alter many of the summaries herein. In addition, many regulatory proposals have been or likely will be challenged in the courts. When such conflicts are resolved further changes may be in order.

  18. Influence of site-specific geology on oil shale fragmentation experiments at the Colony Mine, Garfield County, Colorado

    Energy Technology Data Exchange (ETDEWEB)

    Ray, J.M.; Harper, M.D.; Craig, J.L.; Edwards, C.L.

    1982-01-01

    The Los Alamos National Laboratory executed 19 intermediate scale cratering experiments in oil shale at the Colony Mine in Garfield County, Colorado. These experiments have led to a better understanding of fracture characteristics and fragmentation of in situ oil shale by use of a conventional high explosive. Geologic site characterization included detailed mapping, coring, and sample analyses. Site-specific geology was observed to be a major influence on the resulting crater geometry. The joint patterns at the experimental site frequently defined the final crater symmetry. Secondary influences included vugs, lithology changes, and grade fluctuations in the local stratigraphy. Most experiments, in both the rib and floor, were conducted to obtain data to investigate the fragmentation results within the craters. The rubble was screened for fragment-size distributions. Geologic features in proximity to the explosive charge had minimal effect on the rubble due to the overpowering effect of the detonation. However, these same features became more influential on the fracture and rubble characteristics with greater distances from the shothole. Postshot cores revealed a direct relationship between the grade of the oil shale and its susceptibility to fracturing. The Colony Mine experiments have demonstrated the significant role of geology in high explosive/oil shale interaction. It is probable that this role will have to be considered for larger applications to blast patterns and potential problems in retort stability in the future of oil shale development.

  19. "Smart" Multifunctional Polymers for Enhanced Oil Recovery

    Energy Technology Data Exchange (ETDEWEB)

    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.

  20. Energy Intensity and Greenhouse Gas Emissions from Oil Production in the Eagle Ford Shale

    Energy Technology Data Exchange (ETDEWEB)

    Yeh, Sonia; Ghandi, Abbas; Scanlon, Bridget R.; Brandt, Adam R.; Cai, Hao; Wang, Michael Q.; Vafi, Kourosh; Reedy, Robert C.

    2017-01-30

    A rapid increase in horizontal drilling and hydraulic fracturing in shale and “tight” formations that began around 2000 has resulted in record increases in oil and natural gas production in the U.S. This study examines energy consumption and greenhouse gas (GHG) emissions from crude oil and natural gas produced from ~8,200 wells in the Eagle Ford Shale in southern Texas from 2009 to 2013. Our system boundary includes processes from primary exploration wells to the refinery entrance gate (henceforth well-to-refinery or WTR). The Eagle Ford includes four distinct production zones—black oil (BO), volatile oil (VO), condensate (C), and dry gas (G) zones—with average monthly gas-to-liquids ratios (thousand cubic feet per barrel—Mcf/bbl) varying from 0.91 in the BO zone to 13.9 in the G zone. Total energy consumed in drilling, extracting, processing, and operating an Eagle Ford well is ~1.5% of the energy content of the produced crude and gas in the BO and VO zones, compared with 2.2% in the C and G zones. On average, the WTR GHG emissions of gasoline, diesel, and jet fuel derived from crude oil produced in the BO and VO zones in the Eagle Ford play are 4.3, 5.0, and 5.1 gCO2e/MJ, respectively. Comparing with other known conventional and unconventional crude production where upstream GHG emissions are in the range 5.9–30 gCO2e/MJ, oil production in the Eagle Ford has lower WTR GHG emissions.

  1. Predicted costs of environmental controls for a commercial oil shale industry. Volume 1. An engineering analysis

    Energy Technology Data Exchange (ETDEWEB)

    Nevens, T.D.; Culbertson, W.J. Jr.; Wallace, J.R.; Taylor, G.C.; Jovanovich, A.P.; Prien, C.H.; Hicks, R.E.; Probstein, R.F.; Domahidy, G.

    1979-07-01

    The pollution control costs for a commercial oil shale industry were determined in a joint effort by Denver Research Institute, Water Purification Associates of Cambridge, and Stone and Webster Engineering of Boston and Denver. Four commercial oil shale processes were considered. The results in terms of cost per barrel of syncrude oil are predicted to be as follows: Paraho Process, $0.67 to $1.01; TOSCO II Process, $1.43 to $1.91; MIS Process, $2.02 to $3.03; and MIS/Lurgi-Ruhrgas Process, $1.68 to $2.43. Alternative pollution control equipment and integrated pollution control strategies were considered and optimal systems selected for each full-scale plant. A detailed inventory of equipment (along with the rationale for selection), a detailed description of control strategies, itemized costs and predicted emission levels are presented for each process. Capital and operating cost data are converted to a cost per barrel basis using detailed economic evaluation procedures. Ranges of cost are determined using a subjective self-assessment of uncertainty approach. An accepted methodology for probability encoding was used, and cost ranges are presented as subjective probability distributions. Volume I presents the detailed engineering results. Volume II presents the detailed analysis of uncertainty in the predicted costs.

  2. A Study of the Effect of Relative Permeability and Residual Oil Saturation on Oil Recovery

    OpenAIRE

    Ediriweera, Mahesh Priyankara; Halvorsen, Britt

    2015-01-01

    The depletion of oil production and the low recovery rate are the major challenges faced in oil production. Several studies have shown that considerable amount of oil still remains in the reservoir after the well shutdown. Heavy oil reservoirs occupy more than two third of globally oil reserves. The recovery factor and the lifetime of a well in heavy oil reservoirs is strongly affected by reservoir properties as permeability and porosity, residual oil saturation and the time of water breakthr...

  3. Industrial hygiene monitoring needs for the coal conversion and oil shale industries. Study group report

    Energy Technology Data Exchange (ETDEWEB)

    White, Otto; Morris, Samuel; Cessario, Thomas R.; Baier, Edward; Brief, Richard; Corn, Morton; Ettinger, Harry; Fraser, David; Lippman, Morton; Sharkey, Andrew

    1979-11-01

    Conclusions of a study group organized to assess the need for research and development of instrumentation for monitoring occupational exposures in the coal conversion and oil shale industries are reported. Research and development requirements for assessing potentially hazardous exposures are reviewed. Hazardous substances are classified in the following four categories: those which are immediately hazardous to life and health; high risk, but not immediately hazardous; moderate risk and not immediately hazardous; and short-term, nonroutine high hazards. Specific research recommendations are made in the following areas: personal monitors for gases; nitrogen compounds; aerosols; metals; fibers and dust; surface contamination; skin contamination; analytical development; industrial hygiene surveys;research; and, bioassays. (JGB)

  4. Oil-shale gasification for obtaining of gas for synthesis of aliphatic hydrocarbons

    Energy Technology Data Exchange (ETDEWEB)

    Strizhakova, Yu. [Samara State Univ. (Russian Federation); Avakyan, T.; Lapidus, A.L. [I.M. Gubkin Russian State Univ. of Oil and Gas, Moscow (Russian Federation)

    2011-07-01

    Nowadays, the problem of qualified usage of solid fossil fuels as raw materials for obtaining of motor fuels and chemical products is becoming increasingly important. Gasification with further processing of gaseous products is a one of possible ways of their use. Production of synthesis gas with H{sub 2}/CO ratio equal 2 is possible by gasification of oil-shale. This gas is converted into the mixture of hydrocarbons over cobalt catalyst at temperature from 160 to 210 C at atmospheric pressure. The hydrocarbons can be used as motor, including diesel, or reactive fuel. (orig.)

  5. Treatment of multivariate environmental and health problems associated with oil shale technology

    Energy Technology Data Exchange (ETDEWEB)

    Kland, M.J.

    1980-07-01

    A statistical matrix approach for solving complex environmental problems involving oil shale mining and processing is presented. Four methods are described: quantitative structure-activity and molecular connectivity relationships (QSAR,MC); factor analysis (FA); and pattern recognition (PR). QSAR and MC are useful in the prediction of toxic behavior for individual members of a class of compounds for which SAR data are already available. The methods of FA and PR have both been applied to data derived from structure-activity relationships (SAR), and PR techniques have also been used with connectivity functions. Each method is evaluated and the scope of their application is defined. (DMC)

  6. A Novel Energy-Efficient Pyrolysis Process: Self-pyrolysis of Oil Shale Triggered by Topochemical Heat in a Horizontal Fixed Bed

    Science.gov (United States)

    Sun, You-Hong; Bai, Feng-Tian; Lü, Xiao-Shu; Li, Qiang; Liu, Yu-Min; Guo, Ming-Yi; Guo, Wei; Liu, Bao-Chang

    2015-01-01

    This paper proposes a novel energy-efficient oil shale pyrolysis process triggered by a topochemical reaction that can be applied in horizontal oil shale formations. The process starts by feeding preheated air to oil shale to initiate a topochemical reaction and the onset of self-pyrolysis. As the temperature in the virgin oil shale increases (to 250–300°C), the hot air can be replaced by ambient-temperature air, allowing heat to be released by internal topochemical reactions to complete the pyrolysis. The propagation of fronts formed in this process, the temperature evolution, and the reaction mechanism of oil shale pyrolysis in porous media are discussed and compared with those in a traditional oxygen-free process. The results show that the self-pyrolysis of oil shale can be achieved with the proposed method without any need for external heat. The results also verify that fractured oil shale may be more suitable for underground retorting. Moreover, the gas and liquid products from this method were characterised, and a highly instrumented experimental device designed specifically for this process is described. This study can serve as a reference for new ideas on oil shale in situ pyrolysis processes. PMID:25656294

  7. Proceedings of the symposium on assessing the industrial hygiene monitoring needs for the coal conversion and oil shale industries

    Energy Technology Data Exchange (ETDEWEB)

    White, O. Jr. (ed.)

    1979-03-01

    This work was supported by the United States Department of Energy, Division of Biomedical and Environmental Research, Analysis and Assessment Program, through the Safety and Environmental Protection Division at Brookhaven National Laboratory. The symposium program included presentations centering around the themes: Recognition of Occupational Health Monitoring Requirements for the Coal Conversion and Oil Shale Industries and Status of Dosimetry Technology for Occupational Health Monitoring for the Coal Conversion and Oil Shale Industries. Sixteen papers have been entered individually into EDB and ERA; six had been entered previously from other sources. (LTN)

  8. Long-Term Acid-Generating and Metal Leaching Potential of a Sub-Arctic Oil Shale

    Directory of Open Access Journals (Sweden)

    Kathryn A. Mumford

    2014-04-01

    Full Text Available Shales are increasingly being exploited for oil and unconventional gas. Exploitation of sub-arctic oil shales requires the creation of gravel pads to elevate workings above the heaving effects of ground ice. These gravel pads can potentially generate acidic leachate, which can enhance the mobility of metals from the shale. To examine this potential, pyrite-bearing shale originating from sub-Arctic gravel pad sites were subjected to leaching tests for 600 days at initial pH values ranging from 2 to 5, to simulate potential real world conditions. At set times over the 600 day experiment, pH, oxidation reduction potential (ORP, dissolved oxygen and temperature were recorded and small liquid samples withdrawn and analysed for elemental concentrations using total reflection X-ray fluorescence spectrometry (TRXRF. Six of eight shale samples were found to be acid generating, with pH declining and ORP becoming increasingly positive after 100 days. Two of the eight shale samples produced increasingly alkaline leachate conditions with relatively low ORP after 100 days, indicating an inbuilt buffering capacity. By 600 days the buffering capacity of all samples had been consumed and all leachate samples were acidic. TRXRF analyses demonstrated significant potential for the leaching of S, Fe, Ni, Cu, Zn and Mn with greatest concentrations found in reaction vessels with most acidic pH and highest ORP.

  9. Reservoir characterization and enhanced oil recovery research

    Energy Technology Data Exchange (ETDEWEB)

    Lake, L.W.; Pope, G.A.; Schechter, R.S.

    1992-03-01

    The research in this annual report falls into three tasks each dealing with a different aspect of enhanced oil recovery. The first task strives to develop procedures for accurately modeling reservoirs for use as input to numerical simulation flow models. This action describes how we have used a detail characterization of an outcrop to provide insights into what features are important to fluid flow modeling. The second task deals with scaling-up and modeling chemical and solvent EOR processes. In a sense this task is the natural extension of task 1 and, in fact, one of the subtasks uses many of the same statistical procedures for insight into the effects of viscous fingering and heterogeneity. The final task involves surfactants and their interactions with carbon dioxide and reservoir minerals. This research deals primarily with phenomena observed when aqueous surfactant solutions are injected into oil reservoirs.

  10. Mixed surfactant systems for enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Llave, F.M.; Gall, B.L.; Noll, L.A.

    1990-12-01

    The results of an evaluation of mixed surfactant systems for enhanced oil recovery are described. Several surfactant combinations have been studied. These include alkyl aryl sulfonates as primary surfactants and carboxymethylated ethoxylated (CME) surfactants and ethoxylated sulfonates (ES) as secondary surfactants. The ethoxylated surfactants increase the salinity tolerance of the primary surfactants and, in theory, allow tailoring of the surfactant system to match selected reservoir conditions. The experiments conducted included interfacial tension (IFT) measurements, phase behavior measurements, adsorption and/or chromatographic separation of mixed surfactant systems, measurements of solution properties such as the critical micelle concentration (CMC) of surfactant mixtures, and crude oil displacement experiments. The effects of temperature, surfactant concentration, salinity, presence of divalent ions, hydrocarbon type, and component proportions in the mixed surfactant combinations, and injection strategies on the performance potential of the targeted surfactant/hydrocarbon systems were studied. 40 refs., 37 figs., 8 tabs.

  11. Copper fertilization to prevent molybdenosis on retorted oil shale disposal piles

    Energy Technology Data Exchange (ETDEWEB)

    Stark, J.M. (Univ. of California, Berkeley (USA)); Redente, E.F. (Colorado State Univ., Fort Collins (USA))

    Plants growing on retorted oil shale disposal piles often have Mo concentrations high enough (> 8 mg kg{sup {minus}1}) and Cu/Mo ratios low enough (< 2.0) to cause molybdenosis in grazing ruminants. High Mo concentrations are present in some plant species in spite of 90 cm of topsoil cover. Copper sulfate was broadcast at rates of 0, 8, 16, and 32 kg Cu ha{sup {minus}1} on plots with 30 and 90 cm of topsoil over Paraho retorted oil shale to determine if Cu fertilization can increase Cu/Mo ratios in plants so that molybdenosis is no longer a hazard. Of the plant species studied winterfat (Eurotia lanata (Pursh) Moquin), northern sweetvetch (Hedysarum boreale Nutt.), alfalfa (Medicago sativa L.), native grasses (Agropyron smithii Rydb., A. inerme (Scribn. and Smith) Rydb., A. dasystachium, (Hook.) Scribn. and Poa ampla Merr.), and introduced grasses (A. desertorum (Fisch.) Schult., A. intermedium (Host Beauv.), and Bromus biebersteinii Roem. and Schult.), all except alfalfa showed increased tissue Cu concentrations during the first growing season. Because of high Mo concentrations, however, only winterfat under high fertilization rates developed Cu/Mo ratios sufficient to prevent molybdenosis (i.e., > 2.0). By the end of the second growing season, increases in Cu concentrations due to fertilization had declined approximately 30%. These results indicate that although Cu fertilization can be used for short-term improvements in Cu/Mo ratios, it should not be relied upon as the sole technique for preventing molybdenosis on retorted shale disposal piles. Instead, maximum feasible topsoil thicknesses should be used and plant species known to concentrate Mo should be eliminated from seeding mixtures.

  12. Electrokinetics in oil recovery. Progress report 2

    Energy Technology Data Exchange (ETDEWEB)

    Moeller Nielsen, C.; Laursen, S. [DTU, Fysisk-Kemisk Inst. (Denmark); Jensen, A.B.; Reffstrup, J. [DTU, Lab. for Energiteknik (Denmark); Springer, N. [GEUS, Kerneanalyse Lab. (Denmark)

    1996-03-01

    The elaborate definitions of the different types of phenomenological coefficients of use in studies of complicated transport processes are developed. These constitute the basis for discussing experimental results of the electrokinetics experiments. Temperature dependence of the electric transport coefficients was determined in the range from laboratory temperature to reservoir temperature. The results are compared with calculated temperature dependences obtained by using simple theories and literature data of solution properties. Seemingly the temperature dependence of solution conductivity dominates the picture. Simple Helmholtz-Smoluchowski-Poisson-Boltzmann theory cannot account for the experimental findings. To test the applicability of the scheme of linear equations to describe the flow in the measurement cell, simultaneous application of a pressure difference and a voltage was studied. The results are reasonably satisfying. The linear approach with constant coefficients is found to be appropriate for small flows. The influence of plug treatment was investigated in a series of flushing experiments. Different kinds of oil and water flushing procedures were carried out as were flushings with different solvents. A steady-state of the oil displacement process seems to be reproducible. Some treatments do not influence the permeability but change the electric coefficients. Thus there are changes which cannot be detected by permeability measurements. The two-phase flow experiments were made to show the influence of applying an electric current to a plug in which spontaneous imbibition takes place. Evidently the electrokinetics lowers the residual oil saturation and increases the oil recovery rate. (EG) 13 refs.

  13. Tracer monitoring of enhanced oil recovery projects

    Directory of Open Access Journals (Sweden)

    Kleven R.

    2013-05-01

    Full Text Available In enhanced oil recovery (EOR, chemicals are injected into the oil reservoir, either to increase macroscopic sweep efficiency, or to reduce remaining oil saturation in swept zones. Tracers can be used to identify reservoirs that are specifically suited for EOR operations. Injection of a selection of partitioning tracers, combined with frequent sample analysis of produced fluids, provides information suited for estimation of residual oil saturation. Tracers can also be used to evaluate and optimize the application of EOR chemicals in the reservoir. Suitable tracers will follow the EOR chemicals and assist in evaluation of retention, degradation or trapping. In addition to field applications, tracers also have a large potential as a tool to perform mechanistic studies of EOR chemicals in laboratory experiments. By labelling EOR chemicals with radioactive isotopes of elements such as H, C and S, detailed studies of transport mechanisms can be carried out. Co-injection of labelled compounds in dynamic flooding experiments in porous media will give information about retention or separation of the unique compounds constituting the chemical formulation. Separation of such compounds may be detrimental to obtaining the EOR effect expected. The paper gives new information of specific methods, and discusses current status for use of tracers in EOR operations.

  14. Assessment of Appalachian basin oil and gas resources: Devonian gas shales of the Devonian Shale-Middle and Upper Paleozoic Total Petroleum System: Chapter G.9 in Coal and petroleum resources in the Appalachian basin: distribution, geologic framework, and geochemical character

    Science.gov (United States)

    Milici, Robert C.; Swezey, Christopher S.; Ruppert, Leslie F.; Ryder, Robert T.

    2014-01-01

    This report presents the results of a U.S. Geological Survey (USGS) assessment of the technically recoverable undiscovered natural gas resources in Devonian shale in the Appalachian Basin Petroleum Province of the eastern United States. These results are part of the USGS assessment in 2002 of the technically recoverable undiscovered oil and gas resources of the province. This report does not use the results of a 2011 USGS assessment of the Devonian Marcellus Shale because the area considered in the 2011 assessment is much greater than the area of the Marcellus Shale described in this report. The USGS assessment in 2002 was based on the identification of six total petroleum systems, which include strata that range in age from Cambrian to Pennsylvanian. The Devonian gas shales described in this report are within the Devonian Shale-Middle and Upper Paleozoic Total Petroleum System, which extends generally from New York to Tennessee. This total petroleum system is divided into ten assessment units (plays), four of which are classified as conventional and six as continuous. The Devonian shales described in this report make up four of these continuous assessment units. The assessment results are reported as fully risked fractiles (F95, F50, F5, and the mean); the fractiles indicate the probability of recovery of the assessment amount. The products reported are oil, gas, and natural gas liquids. The mean estimates for technically recoverable undiscovered hydrocarbons in the four gas shale assessment units are 12,195.53 billion cubic feet (12.20 trillion cubic feet) of gas and 158.91 million barrels of natural gas liquids

  15. Effect of drilling fluid systems and temperature on oil mist and vapour levels generated from shale shaker.

    Science.gov (United States)

    Steinsvåg, Kjersti; Galea, Karen S; Krüger, Kirsti; Peikli, Vegard; Sánchez-Jiménez, Araceli; Sætvedt, Esther; Searl, Alison; Cherrie, John W; van Tongeren, Martie

    2011-05-01

    Workers in the drilling section of the offshore petroleum industry are exposed to air pollutants generated by drilling fluids. Oil mist and oil vapour concentrations have been measured in the drilling fluid processing areas for decades; however, little work has been carried out to investigate exposure determinants such as drilling fluid viscosity and temperature. A study was undertaken to investigate the effect of two different oil-based drilling fluid systems and their temperature on oil mist, oil vapour, and total volatile organic compounds (TVOC) levels in a simulated shale shaker room at a purpose-built test centre. Oil mist and oil vapour concentrations were sampled simultaneously using a sampling arrangement consisting of a Millipore closed cassette loaded with glass fibre and cellulose acetate filters attached to a backup charcoal tube. TVOCs were measured by a PhoCheck photo-ionization detector direct reading instrument. Concentrations of oil mist, oil vapour, and TVOC in the atmosphere surrounding the shale shaker were assessed during three separate test periods. Two oil-based drilling fluids, denoted 'System 2.0' and 'System 3.5', containing base oils with a viscosity of 2.0 and 3.3-3.7 mm(2) s(-1) at 40°C, respectively, were used at temperatures ranging from 40 to 75°C. In general, the System 2.0 yielded low oil mist levels, but high oil vapour concentrations, while the opposite was found for the System 3.5. Statistical significant differences between the drilling fluid systems were found for oil mist (P = 0.025),vapour (P levels. Oil vapour levels at the test facility exceeded the Norwegian oil vapour occupational exposure limit (OEL) of 30 mg m(-3) when the drilling fluid temperature was ≥50°C. The practice of testing compliance of oil vapour exposure from drilling fluids systems containing base oils with viscosity of ≤2.0 mm(2) s(-1) at 40°C against the Norwegian oil vapour OEL is questioned since these base oils are very similar to white

  16. Environmental regulations handbook for enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    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.

  17. Synthesis of nucleated glass-ceramics using oil shale fly ash.

    Science.gov (United States)

    Luan, Jingde; Li, Aimin; Su, Tong; Cui, Xiaobo

    2010-01-15

    Nucleated glass-ceramics materials were produced from oil shale fly ash obtained from Huadian thermal power plant in China with the addition of analytic reagent CaO. On basis of differential thermal analysis (DTA) results, the nucleation and crystallization temperature of two parent glass samples with different alkalinity (Ak=m(CaO)/m(SiO(2)) were identified as Tn(1)=810 degrees C, Tc(1)=956 degrees C and Tn(2)=824 degrees C, Tc(2)=966 degrees C, respectively. X-ray diffraction (XRD) analysis of the produced nucleated glass-ceramics materials revealed that there was a coexistence phenomenon of multi-crystalline phase and the main crystalline phase was anorthite ([Ca,Na][AI,Si](2)Si(2)O(8)). The microstructure of the glass-ceramics materials was examined by scanning electron microscope (SEM). SEM observation indicated that there was an increase in the quantity of sphere-shaped crystals when crystallization time increased. Furthermore, the increase of alkalinity caused more amorphous phase occurring in glass-ceramics materials. Through the tests of physical and mechanical properties, the glass-ceramics materials with more crystalline phase and fine microstructure had high density, fine performance of resisting compression (328.92 MPa) and negligible water absorption. Through chemical resistance tests, the glass-ceramics samples showed strong corrosion resistance. Overall results indicated that it was a feasible attempt to produce nucleated glass-ceramics materials for building and decorative materials from oil shale fly ash.

  18. {sup 13}C NMR and EPR spectroscopic evaluation of oil shale mined soil recuperation

    Energy Technology Data Exchange (ETDEWEB)

    Santos, J.V. dos, E-mail: mangrich@ufpr.br [Universidade Federal do Parana (UFPR), Curitiba, PR (Brazil); Mangrich, A.S. [Instituto Nacional de Ciencia e Tecnologia: Energia e Ambiente, Salvador, BA (Brazil); Pereira, B.F. [EMBRAPA Clima Temperado, Pelotas, RS (Brazil); Pillon, C.N. [EMBRAPA Clima Temperado, Pelotas, RS (Brazil). Estacao Experimental Cascata; Novotny, E.H. [EMBRAPA Solos, Rio de Janeiro, RJ (Brazil); Bonagamba, T.J. [Universidade de Sao Paulo (USP), Sao Carlos, SP (Brazil). Instituto de Fisica; Abbt-Braun, G.; Frimmel, F.H. [Engler-Bunte-Institut, Universitaet Karlsruhe, TH (Germany)

    2013-02-15

    In this work, native forest soil (NFS) organic matter (SOM) sample and SOM samples from a neighboring forest soil area of an oil shale mine which is being rehabilitated for thirty years (RFS) were analyzed. X-band electron paramagnetic resonance (EPR) and solid-state {sup 13}C nuclear magnetic resonance (NMR) spectroscopies were used to evaluate the soil reclamation of the Brazilian oil shale mining process. Two-dimensional heterospectral correlation studies of the results obtained from EPRand {sup 13}C NMR were used to obtain information about SOM structures and their interactions with residual paramagnetic metal ion. The signal of the residual metallic oxycation, VO{sup 2+} correlated positively with uronic acid-type hydrophilic organic structures, determined from the {sup 13}C NMR spectra, and correlated negatively with the organic free radical (OFR) signal associated with oxygen atoms (g = 2.0042). The hydrophobic aromatic structures correlate positively with the EPR OFR signal associated with carbon atoms (g = 2.0022). The data from the two spectroscopic magnetic techniques show that the used recuperation process is effective. (author)

  19. Method for explosive expansion toward horizontal free faces for forming an in situ oil shale retort

    Science.gov (United States)

    Ricketts, Thomas E.

    1980-01-01

    Formation is excavated from within a retort site in formation containing oil shale for forming a plurality of vertically spaced apart voids extending horizontally across different levels of the retort site, leaving a separate zone of unfragmented formation between each pair of adjacent voids. Explosive is placed in each zone, and such explosive is detonated in a single round for forming an in situ retort containing a fragmented permeable mass of formation particles containing oil shale. The same amount of formation is explosively expanded upwardly and downwardly toward each void. A horizontal void excavated at a production level has a smaller horizontal cross-sectional area than a void excavated at a lower level of the retort site immediately above the production level void. Explosive in a first group of vertical blast holes is detonated for explosively expanding formation downwardly toward the lower void, and explosive in a second group of vertical blast holes is detonated in the same round for explosively expanding formation upwardly toward the lower void and downwardly toward the production level void for forming a generally T-shaped bottom of the fragmented mass.

  20. Source characterization studies at the Paraho semiworks oil shale retort. [Redistribution of trace and major elements

    Energy Technology Data Exchange (ETDEWEB)

    Fruchter, J.S.; Wilkerson, C.L.; Evans, J.C.; Sanders, R.W.; Abel, K.W.

    1979-05-01

    In order to determine the redistribution of trace and major elements and species during aboveground oil shale retorting, a comprehensive program was carried out for the sampling and analysis of feedstock, products, effluents, and ambient particulates from the Paraho Semiworks Retort. Samples were obtained during two periods in 1977 when the retort was operating in the direct mode. The data were used to construct mass balances for 31 trace and major elements in various effluents, including the offgas. The computed mass balances indicated that approx. 1% or greater fractions of the As, Co, Hg, N, Ni, S, and Se were released during retorting and redistributed to the product oil, retort water, or product offgas. The fraction released for these seven elements ranged from approx. 1% for Co and Ni to 50 to 60% for Hg and N. Approximately 20% of the S and 5% each of the As and Se were released. Ambient aerosols were found to be elevated near the retorting facility and associated crushing and retorted shale disposal sites. Approximately 50% of these particles were in the respirable range (< 5 ..mu..m). The elevated dust loadings are presented very local, as indicated by relatively low aerosol loadings at background sites 100 to 200 m away. State-of-the-art dust control measures were not employed. 15 figures, 19 tables.

  1. The photoluminescence properties of tri-colour silicoaluminate phosphors prepared from oil shale ash

    Science.gov (United States)

    Zhang, Hui; Song, Yanhua; Sheng, Ye; Zheng, Keyan; Ding, Shizhou; Yuan, Bo; Xu, Xuechun; Zou, Haifeng

    2015-09-01

    In this paper, high value-added tri-colour phosphors Ba0.96Mg1.88Si2O7:0.02Eu2+, 0.02Dy3+, 0.12Mn2+; CaSr0.995SiO4:0.005Eu2+ and Ba0.91MgAl10O17:0.09Eu2+ were prepared using the white carbon black (hereinafter referred to as WCB) and alumina extracted from oil shale ash as raw materials. The structure and luminescence properties of the samples were characterized by X-ray diffraction (XRD) and photoluminescent spectra. The results show that the red and green phosphors synthesized by WCB exhibited much weaker emission than the phosphors synthesized by pure chemical reagent silica, which is mainly due to the high content of iron in the WCB. After purifying the WCB under laboratory conditions, the luminescence properties were improved and close to that of pure chemical reagent. By comparing with the emission of the samples synthesized with chemical reagents, the results show that the products extracted from oil shale ash can be applied to synthesize luminescent materials which have potential applications in white-light ultraviolet (UV)-LED field.

  2. Groundwater flow model of the Estonian oil shale mining area towards to innovative system

    Energy Technology Data Exchange (ETDEWEB)

    Lind, H. [Tallinn Univ. of Technology (Estonia). Dept. of Mining

    2010-07-01

    Changes in the Estonian groundwater regime are anticipated as oil shale deposits are mined. This paper described a dynamic groundwater flow model used to develop a 3-D groundwater elevation map of the Estonian oil shale mining area. The model was used to provide preliminary estimations of water inflow into the working underground mine areas. The model included 9 closed underground mines, 5 active mine sites, and 2 small open-cast sites. The closed mine sites were filled with water flowing in from the working mine sites. New mines and dewatering programs are planned for the future. A database from observation wells installed within the Keila-Kukruse aquifer was used to extract outputs and determine time steps. The model included 35 pumping stations from the active mine sites. The hydraulic properties for each model layer were defined in 4 model zones. Results of the model showed higher water in-flows from the closed underground sites than earlier predictions had anticipated. 9 refs., 1 tab., 4 figs.

  3. Combustion of municipal solid wastes with oil shale in a circulating fluidized bed. Final report

    Energy Technology Data Exchange (ETDEWEB)

    NONE

    1996-06-30

    The problem addressed by our invention is that of municipal solid waste utilization. The dimensions of the problem can be visualized by the common comparison that the average individual in America creates in five years time an amount of solid waste equivalent in weight to the Statue of Liberty. The combustible portion of the more than 11 billion tons of solid waste (including municipal solid waste) produced in the United States each year, if converted into useful energy, could provide 32 quads per year of badly needed domestic energy, or more than one-third of our annual energy consumption. Conversion efficiency and many other factors make such a production level unrealistic, but it is clear that we are dealing with a very significant potential resource. This report describes research pertaining to the co-combustion of oil shale with solid municipal wastes in a circulating fluidized bed. The oil shale adds significant fuel content and also constituents that can possible produce a useful cementitious ash.

  4. Design, fabrication, operation and Aspen simulation of oil shale pyrolysis and biomass gasification process using a moving bed downdraft reactor

    Science.gov (United States)

    Golpour, Hassan

    Energy is the major facilitator of the modern life. Every developed and developing economy requires access to advanced sources of energy to support its growth and prosperity. Declining worldwide crude oil reserves and increasing energy needs has focused attention on developing existing unconventional fossil fuels like oil shale and renewable resources such as biomass. Sustainable, renewable and reliable resources of domestically produced biomass comparing to wind and solar energy is a sensible motivation to establish a small-scale power plant using biomass as feed to supply electricity demand and heat for rural development. The work in Paper I focuses on the possibility of water pollution from spent oil shale which should be studied before any significant commercial production is attempted. In Paper II, the proposed Aspen models for oil shale pyrolysis is to identify the key process parameters for the reactor and optimize the rate of production of syncrude from oil shale. The work in Paper III focuses on (1) Design and operation of a vertical downdraft reactor, (2) Establishing an optimum operating methodology and parameters to maximize syngas production through process testing. Finally in Paper IV, a proposed Aspen model for biomass gasification simulates a real biomass gasification system discussed in Paper III.

  5. Black shale source rocks and oil generation in the Cambrian and Ordovician of the central Appalachian Basin, USA

    Science.gov (United States)

    Ryder, R.T.; Burruss, R.C.; Hatch, J.R.

    1998-01-01

    Nearly 600 million bbl of oil (MMBO) and 1 to 1.5 trillion ft3 (tcf) of gas have been produced from Cambrian and Ordovician reservoirs (carbonate and sandstone) in the Ohio part of the Appalachian basin and on adjoining arches in Ohio, Indiana, and Ontario, Canada. Most of the oil and gas is concentrated in the giant Lima-Indiana field on the Findlay and Kankakee arches and in small fields distributed along the Knox unconformity. Based on new geochemical analyses of oils, potential source rocks, bitumen extracts, and previously published geochemical data, we conclude that the oils in both groups of fields originated from Middle and Upper Ordovician blcak shale (Utica and Antes shales) in the Appalachian basin. Moroever, we suggest that approximately 300 MMBO and many trillions of cubic feet of gas in the Lower Silurian Clinton sands of eastern Ohio originated in the same source rocks. Oils from the Cambrian and Ordovician reservoirs have similar saturated hydrocarbon compositions, biomarker distributions, and carbon isotope signatures. Regional variations in the oils are attributed to differences in thermal maturation rather than to differences in source. Total organic carbon content, genetic potential, regional extent, and bitument extract geochemistry identify the balck shale of the Utica and Antes shales as the most plausible source of the oils. Other Cambrian and Ordovician shale and carbonate units, such as the Wells Creek formation, which rests on the Knox unconformity, and the Rome Formation and Conasauga Group in the Rome trough, are considered to be only local petroleum sources. Tmax, CAI, and pyrolysis yields from drill-hole cuttings and core indicate that the Utica Shale in eastern and central Ohio is mature with respect to oil generation. Burial, thermal, and hydrocarbon-generation history models suggest that much of the oil was generated from the Utica-Antes source in the late Paleozoic during the Alleghanian orogeny. A pervasive fracture network

  6. Microbial enhancement of oil recovery: Recent advances

    Energy Technology Data Exchange (ETDEWEB)

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

    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. Characterisation of Tertiary Catalan lacustrine oil shales: Discovery of extremely organic sulphur-rich type I kerogens

    NARCIS (Netherlands)

    Sinninghe Damsté, J.S.; Las Heras, F.X.C. de; Bergen, P.F. van; Leeuw, J.W. de

    1993-01-01

    The kerogens of three Tertiary Catalan lacustrine oil shales were analyzed by light microscopy, flash pyrolysis-gas chromatography-mass spectrometry, and bulk composition methods (elemental analysis, Rock Eval pyrolysis). Two of the three kerogens (Ribesalbes and Campins) are extremely rich in

  8. Assessment of undiscovered continuous oil resources in the Wolfcamp shale of the Midland Basin, Permian Basin Province, Texas, 2016

    Science.gov (United States)

    Gaswirth, Stephanie B.; Marra, Kristen R.; Lillis, Paul G.; Mercier, Tracey J.; Leathers-Miller, Heidi M.; Schenk, Christopher J.; Klett, Timothy R.; Le, Phuong A.; Tennyson, Marilyn E.; Hawkins, Sarah J.; Brownfield, Michael E.; Pitman, Janet K.; Finn, Thomas M.

    2016-11-15

    Using a geology-based assessment methodology, the U.S. Geological Survey assessed technically recoverable mean resources of 20 billion barrels of oil and 16 trillion cubic feet of gas in the Wolfcamp shale in the Midland Basin part of the Permian Basin Province, Texas.

  9. Assessment of continuous oil resources in the Wolfcamp shale of the Midland Basin, Permian Basin Province, Texas, 2016

    Science.gov (United States)

    Gaswirth, Stephanie B.

    2017-03-06

    The U.S. Geological Survey completed a geology-based assessment of undiscovered, technically recoverable continuous petroleum resources in the Wolfcamp shale in the Midland Basin part of the Permian Basin Province of west Texas. This is the first U.S. Geological Survey evaluation of continuous resources in the Wolfcamp shale in the Midland Basin. Since the 1980s, the Wolfcamp shale in the Midland Basin has been part of the “Wolfberry” play. This play has traditionally been developed using vertical wells that are completed and stimulated in multiple productive stratigraphic intervals that include the Wolfcamp shale and overlying Spraberry Formation. Since the shift to horizontal wells targeting the organic-rich shale of the Wolfcamp, more than 3,000 horizontal wells have been drilled and completed in the Midland Basin Wolfcamp section. The U.S. Geological Survey assessed technically recoverable mean resources of 20 billion barrels of oil and 16 trillion cubic feet of associated gas in the Wolfcamp shale in the Midland Basin.

  10. Minimum bed parameters for in situ processing of oil shale. Third quarterly report, April 1-June 30, 1980

    Energy Technology Data Exchange (ETDEWEB)

    Tyner, C. E.

    1980-11-01

    Oil shale retort runs 028 (16% void) and 029 (7% void), composed of competent shale blocks plus shale rubble, were completed. Retort 028, processed with air at a flux of 0.017 kg/sub air//m/sup 2/ /sub shale/.second, had peak temperatures of 700/sup 0/C, a retorting rate of 1.1 m/day, and a yield of 82% FA. Retort 029, processed with air at a flux of 0.027 kg/sub air//m/sup 2//sub shale/.second, had peak temperatures of 750/sup 0/C, a retorting rate of 1.6 m/day, and a yield of 75% FA. Comparisons of retort model calculations with experimental data from previous retort run 027 (16% void, air flux of .029 kg/sub air//m/sup 2//sub shale/.second were good; observed experimental yield was 95% FA, calculated yield, 92.8%; experimental retorting rates varied from 9.5 to 8.9 cm/h, calculated rates from 10.3 to 10.0 cm/h; observed local heating rates ranged from 29 to 14/sup 0/C/h, calculated heating rates from 20 to 16/sup 0/C/h; and observed peak temperatures ranged from 815 to 825/sup 0/C, calculated from 820 to 825/sup 0/C.

  11. Effects of the addition of oil shale ash and coal ash on physic-chemical properties of CPJ45 cement

    Directory of Open Access Journals (Sweden)

    Nabih K.

    2014-04-01

    Full Text Available We focused our research on recycling industrial wastes, fly ash (F.A, bottom ash (B.A and oil shale ash (S.A in cement production. The study concerns physico-chemical characterization of these products and the influence of their addition on the mechanical proprieties of the CPJ45 cement. XRF allowed us to rank the three additives used according to their contents on major oxides. Coal ashes belong to the class F, and thus possess poozzolanic properties and oil shale ash belongs to the class C and possesses hydraulic and poozolanic properties. The crystalline phases constituting each ash were analysed by XRD. We observe in bottom ash the presence of quartz and mullite. The same crystals are found in fly ash with hematite and magnetite. Oil shale ash is composed of quartz, anhydrite, gehlenite, wollastonite and periclase. The microstructures of fly ash and bottom ash were studied using SEM. The bottom ash was composed respectively of fine particles that are generally irregularly shaped, their dimensions are between 5 and 28μm and of big particles(300 μm. The EDX analysis coupled with an electronic microscope provided some information about the major elements that constitute our samples. The dehydrations of anhydrous and three days hydrated cement were examined by DSC. For hydrated cements we noticed endothermic peaks related to the dehydration of CSH, CH and decomposition of carbonates. The study of the mechanical properties of CPJ45 cement by adding different proportions of fly ash, bottom ash and oil shale ash helped clarifying the percentage of ash that leaded to improve the 28 days mechanical strength. The results show that the cements studied have their maximum mechanical resistance with the addition at 7% of fly ash or 10% of oil shale ash.

  12. Enhanced oil recovery using local alkaline | Akpoturi | Nigerian ...

    African Journals Online (AJOL)

    Improvement in productivity is one of the Oil and Gas industry's biggest challenges. About 60% of crude Oil still lay trapped in the reservoir even after primary and secondary recovery process have been completed, hence the need for a method that further improves recovery. In this study, flooding experiment was conducted ...

  13. Oil shales and tar sands: a bibliography. Supplement 2, Parts 1 and 2

    Energy Technology Data Exchange (ETDEWEB)

    Grissom, M.C. (ed.)

    1984-07-01

    This bibliography includes 4715 citations arranged in the broad subject categories: reserves and exploration; site geology and hydrology; drilling, fracturing, and mining; oil production, recovery, and refining; properties and composition; direct uses and by-products; health and safety; marketing and economics; waste research and management; environmental aspects; regulations; and general. There are corporate, author, subject, contract number, and report number indexes.

  14. Method oil shale pollutant sorption/NO.sub.x reburning multi-pollutant control

    Science.gov (United States)

    Boardman, Richard D [Idaho Falls, ID; Carrington, Robert A [Idaho Falls, ID

    2008-06-10

    A method of decreasing pollutants produced in a combustion process. The method comprises combusting coal in a combustion chamber to produce at least one pollutant selected from the group consisting of a nitrogen-containing pollutant, sulfuric acid, sulfur trioxide, carbonyl sulfide, carbon disulfide, chlorine, hydroiodic acid, iodine, hydrofluoric acid, fluorine, hydrobromic acid, bromine, phosphoric acid, phosphorous pentaoxide, elemental mercury, and mercuric chloride. Oil shale particles are introduced into the combustion chamber and are combusted to produce sorbent particulates and a reductant. The at least one pollutant is contacted with at least one of the sorbent particulates and the reductant to decrease an amount of the at least one pollutant in the combustion chamber. The reductant may chemically reduce the at least one pollutant to a benign species. The sorbent particulates may adsorb or absorb the at least one pollutant. A combustion chamber that produces decreased pollutants in a combustion process is also disclosed.

  15. Steam pyrolysis of shale oil vacuum distillates for petrochemical intermediates production

    Energy Technology Data Exchange (ETDEWEB)

    Smith, P.D.; Dickson, P.F.; Yesavage, V.F.

    1978-03-01

    Vacuum distillations of shale oil may be worthwhile since it produces a good steam pyrolysis feedstock. Maximum ethylene yield was 28.8% for the simulated in situ distillate and 22.6% for the Tosco II distillate. Yields are as good or better than those obtainable from conventional feedstocks. Severity of cracking is increased by increasing the residence time and temperature. The effect of steam to hydrocarbon ratio cannot be determined from the data. Trends observed with increasing severity were: (a) ethylene yield rises to a maximum, then slowly decreases; (b) propylene and butadiene yields continually decrease; (c) methane and hydrogen yields increase; (d) weight percent solids increased. Short residence times, in general, give the highest yields of valuable components. 2 tables, 4 figs.

  16. Rehabilitation potential and practices of Colorado oil shale lands. Progress report, June 1, 1976--May 31, 1977

    Energy Technology Data Exchange (ETDEWEB)

    Sims, P.L.

    1977-02-01

    Substantial progress has been made towards implementing all of the prescribed studies and satisfying the stated objectives since the Oil Shale Rehabilitation Project was actively initiated in June 1976. Concurrent with implementation, research objectives were substantively defined and supplemented without distracting or departing from the original purpose. Current studies are designed to fill voids in the present status of knowledge regarding lands disturbed by an impending oil shale industry in Colorado. The efforts of all contributing investigators have therefore been integrated and directed toward the goal of developing methodologies requisite for restoring diverse and complex ecosystems which will require only a minimal amount of maintenance or input of scarce resources. An intensive study site southeast of the Oil Shale Tract C-a has been obtained through a Cooperative Agreement with the Bureau of Land Management. Following this agreement, most subprojects were initiated at the intensive site. Additional programs will be implemented as spent shale becomes available this summer. Studies conducted principally in the laboratory and greenhouse, such as the microbiological and plant genetic studies, have achieved significant results.

  17. Assessment of environmental health and safety issues associated with the commercialization of unconventional gas recovery: Devonian shale

    Energy Technology Data Exchange (ETDEWEB)

    1981-09-01

    The purpose of this study is to identify and examine potential public health and safety issues and the potential environmental impacts from recovery of natural gas from Devonian age shale. This document will serve as background data and information for planners within the government to assist in development of our new energy technologies in a timely and environmentally sound manner. This report describes the resource and the DOE eastern gas shales project in Section 2. Section 3 describes the new and developing recovery technologies associated with Devonian shale. An assessment of the environment, health and safety impacts associated with a typical fields is presented in Section 4. The typical field for this assessment occupies ten square miles and is developed on a 40-acre spacing (that is, there is a well in each 40-acre grid). This field thus has a total of 160 wells. Finally, Section 5 presents the conclusions and recommendations. A reference list is provided to give a greater plant. Based on the estimated plant cost and the various cases of operating income, an economic analysis was performed employing a profitability index criterion of discounted cash flow to determine an interest rate of return on the plant investment.

  18. Alkaline flooding for enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Gittler, W.E.

    1983-09-01

    There are over 12 active projects of varying size using one of 3 major types of alkaline agents. These include sodium silicate, caustic soda, and soda ash. Among the largest pilots currently is the THUMS project in the Wilmington field, California. Plans called for the injection of a 4% weight concentration of sodium orthosilicate over a 60% PV. Through the first 3 yr, over 27 million bbl of chemicals have been injected. Gulf Oil is operating several alkaline floods, one of which is located off shore in the Quarantine Bay field, Louisiana. In this pilot, sodium hydroxide in a weight concentration of 5 to 12% is being injected. Belco Petroleum Corp. has reported that their pilot operating in the Isenhour Unit in Wyoming is using a .5% weight concentration of soda ash in conjunction with a polymer. Other uses for alkaline agents in chemical flooding include the use of silicate as a preflush or sacrificial agent in micellar/polymer and surfactant recovery systems. In addition, caustic has been tested in the surface-mixed caustic emulsion process while orthosilicate has been tested in a recovery method known as mobility-controlled caustic floods.

  19. Improving Energy Efficiency In Thermal Oil Recovery Surface Facilities

    Energy Technology Data Exchange (ETDEWEB)

    Murthy Nadella, Narayana

    2010-09-15

    Thermal oil recovery methods such as Cyclic Steam Stimulation (CSS), Steam Assisted Gravity Drainage (SAGD) and In-situ Combustion are being used for recovering heavy oil and bitumen. These processes expend energy to recover oil. The process design of the surface facilities requires optimization to improve the efficiency of oil recovery by minimizing the energy consumption per barrel of oil produced. Optimization involves minimizing external energy use by heat integration. This paper discusses the unit processes and design methodology considering thermodynamic energy requirements and heat integration methods to improve energy efficiency in the surface facilities. A design case study is presented.

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  1. Polymeric surfactants for enhanced oil recovery : A review

    NARCIS (Netherlands)

    Raffa, Patrizio; Broekhuis, Antonius A.; Picchioni, Francesco

    Chemical enhanced oil recovery (EOR) is surely a topic of interest, as conventional oil resources become more scarce and the necessity of exploiting heavy and unconventional oils increases. EOR methods based on polymer flooding, surfactant-polymer flooding and alkali-surfactant-polymer flooding are

  2. The Geopolitics of Shale Gas : The Implications of the US' Shale Gas Revolution on Intrastate Stability within Traditional Oil- and Natural Gas-Exporting Countries in the EU Neighborhood

    NARCIS (Netherlands)

    Jong, S. de; Auping, W.; Govers, J.; Peters, M.C.A.M.; Widdershoven, C.J.C.G.; Weterings, R.A.P.M.

    2014-01-01

    The US’ shale gas revolution could in the long term destabilize traditional oil- and gas exporters in the European Union (EU) neighborhood: A combination of substitution effects and greater energy efficiency, could put pressure on the price of oil, leading to fiscal difficulties in traditional

  3. Results of research and commercial production of shale oil in Bazhenov formation on Ai-Pimskoe field

    Science.gov (United States)

    Sarancha, A. V.; Shuldikova, N. S.; Mayer, A. V.; Sumin, A. N.

    2017-10-01

    A large number of articles devoted to Bazhenov Formation appeared in Russian scientific and technical journals, aimed at specialists in of oil and gas fields development over the last 5 – 10 years. This is due to the fact that traditional hydrocarbon resources are gradually reducing, making oil companies pay attention to shale oil; the largest deposits in the Russian Federation are in Bazhenov Formation. The main purpose of this article is to highlight results obtained during the development of Bazhenov Formation on Ai-Pimskoe field in Western Siberia.

  4. Effect of neglecting geothermal gradient on calculated oil recovery

    Science.gov (United States)

    Safari, Mehdi; Mohammadi, Majid; Sedighi, Mehdi

    2017-03-01

    Reduced recovery rate with time is a common challenge for most of the oil producing reservoirs. Water flooding is one of the most common methods used for enhanced oil recovery. Simulating water-flooding process is sometimes carried out without considering the effect of geothermal gradient, and an average temperature is assumed for all the grid blocks. However, the gradient plays a significant role on the reservoir fluid properties. So neglecting its effect might result in a large error in the calculated oil recovery results, especially for the thick reservoirs, which in theory can show significant variations in temperature with depth. In this paper, first, advancing the waterfront during injection into a geothermal oil reservoir is discussed. Then, the performance of considering either an average temperature or gradient temperature, are considered and compared with each other. The results suggest that assuming a fixed average reservoir temperature with no geothermal gradient, can lead to a pronounced error for calculated oil recovery.

  5. Enhanced oil recovery by CO{sub 2} injection

    Energy Technology Data Exchange (ETDEWEB)

    Moctezuma Berthier, Andres E. [Instituto Mexicano del Petroleo, Mexico, D.F. (Mexico)

    2008-07-15

    Firstly are presented some basic concepts on the enhanced oil recovery; then a description is made of where the oil deposits in Mexico are located; comments are made over what has been done in Mexico in terms of enhanced oil recovery, the projects of the Instituto Mexicano del Petroleo that have dealt with the subject of enhanced oil recovery, and finally an approach is presented towards the problem of oil recovery using CO{sub 2}. [Spanish] Primeramente se presentan unos conceptos basicos sobre la recuperacion mejorada de petroleo; luego se hace una descripcion de donde se encuentran los yacimientos de petroleo en Mexico; se comenta sobre que se ha hecho en Mexico en terminos de recuperacion mejorada de petroleo; se mencionan los proyectos del Instituto Mexicano del Petroleo que han abordado el tema de la recuperacion mejorada del petroleo y por ultimo se presenta un enfoque hacia el problema de la recuperacion del petroleo usando CO{sub 2}.

  6. Microbial enhanced oil recovery: Entering the log phase

    Energy Technology Data Exchange (ETDEWEB)

    Bryant, R.S.

    1995-12-31

    Microbial enhanced oil recovery (MEOR) technology has advanced internationally since 1980 from a laboratory-based evaluation of microbial processes to field applications. In order to adequately support the decline in oil production in certain areas, research on cost-effective technologies such as microbial enhanced oil recovery processes must focus on both near-term and long-term applications. Many marginal wells are desperately in need of an inexpensive improved oil recovery technology today that can assist producers in order to prevent their abandonment. Microbial enhanced waterflooding technology has also been shown to be an economically feasible technology in the United States. Complementary environmental research and development will also be required to address any potential environmental impacts of microbial processes. In 1995 at this conference, the goal is to further document and promote microbial processes for improved oil recovery and related technology for solving environmental problems.

  7. SURFACTANT BASED ENHANCED OIL RECOVERY AND FOAM MOBILITY CONTROL

    Energy Technology Data Exchange (ETDEWEB)

    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.

  8. [Application of wavelet transform and neural network in the near-infrared spectrum analysis of oil shale].

    Science.gov (United States)

    Li, Su-Yi; Ji, Yan-Ju; Liu, Wei-Yu; Wang, Zhi-Hong

    2013-04-01

    In the present study, an innovative method is proposed, employing both wavelet transform and neural network, to analyze the near-infrared spectrum data in oil shale survey. The method entails using db8 wavelet at 3 levels decomposition to process raw data, using the transformed data as the input matrix, and creating the model through neural network. To verify the validity of the method, this study analyzes 30 synthesized oil shale samples, in which 20 samples are randomly selected for network training, the other 10 for model prediction, and uses the full spectrum and the wavelet transformed spectrum to carry out 10 network models, respectively. Results show that the mean speed of the full spectrum neural network modeling is 570.33 seconds, and the predicted residual sum of squares (PRESS) and correlation coefficient of prediction are 0.006 012 and 0.843 75, respectively. In contrast, the mean speed of the wavelet network modeling method is 3.15 seconds, and the mean PRESS and correlation coefficient of prediction are 0.002 048 and 0.953 19, respectively. These results demonstrate that the wavelet neural network modeling method is significantly superior to the full spectrum neural network modeling method. This study not only provides a new method for more efficient and accurate detection of the oil content of oil shale, but also indicates the potential for applying wavelet transform and neutral network in broad near-infrared spectrum analysis.

  9. Millimeter-scale concentration gradients of hydrocarbons in Archean shales: Live-oil escape or fingerprint of contamination?

    Science.gov (United States)

    Brocks, Jochen J.

    2011-06-01

    Archean shales from the Pilbara in Western Australia contain biomarkers that have been interpreted as evidence for the existence of cyanobacteria and eukaryotes 2.7 billion years (Ga) ago, with far reaching implications for the evolution of Earth's early biosphere. To re-evaluate the provenance of the biomarkers, this study determined the spatial distribution of hydrocarbons in the original drill core material. Rock samples were cut into millimeter-thick slices, and the molecular content of each slice was analyzed. In core from the Hamersley Group (˜2.5 Ga), C contamination model), and leaching of indigenous hydrocarbons out of host shales driven by pressure release after drilling ('live-oil' effect). To test these models, the hydrocarbon distributions in the Archean shales are compared with artificially contaminated rocks as well as younger mudstones where leaching of live-oil had been observed. The results show that chromatographic phenomena associated with live-oil escape and contaminant diffusion have strong effects on molecular ratios and maturity parameters, potentially with broad implications for oil-source rock correlation studies and paleoenvironmental interpretations. For the Archean shales, the live-oil effect is consistent with some of the observed patterns, but only the contamination model fully explains the complex chromatographic fingerprints. Therefore, the biomarkers in the Pilbara samples have an anthropogenic origin, and previous conclusions about the origin of eukaryotes and oxygenic photosynthesis based on these samples are not valid. However, the study also identified indigenous molecules. The spatial distribution of particular aromatic hydrocarbons suggests they are syngenetic. Although devoid of biological information, these aromatics now represent the oldest known clearly-indigenous terrestrial liquid hydrocarbons.

  10. Deliberating the perceived risks, benefits, and societal implications of shale gas and oil extraction by hydraulic fracturing in the US and UK

    Science.gov (United States)

    Thomas, Merryn; Partridge, Tristan; Harthorn, Barbara Herr; Pidgeon, Nick

    2017-04-01

    Shale gas and oil production in the US has increased rapidly in the past decade, while interest in prospective development has also arisen in the UK. In both countries, shale resources and the method of their extraction (hydraulic fracturing, or 'fracking') have been met with opposition amid concerns about impacts on water, greenhouse gas emissions, and health effects. Here we report the findings of a qualitative, cross-national deliberation study of public perceptions of shale development in UK and US locations not yet subject to extensive shale development. When presented with a carefully calibrated range of risks and benefits, participants' discourse focused on risks or doubts about benefits, and potential impacts were viewed as inequitably distributed. Participants drew on direct, place-based experiences as well as national contexts in deliberating shale development. These findings suggest that shale gas development already evokes a similar 'signature' of risk across the US and UK.

  11. Enhanced oil recovery with modified nonionic surfactants

    Energy Technology Data Exchange (ETDEWEB)

    Capelle, A.; Littmann, W.

    1982-01-01

    Practically all work on chemical flooding, both in the laboratory and in the field, has been focused on petroleum sulphonates. However, as soon as the concentration of electrolyes, especially of divalent ions, exceeds a critical value, the use of this class of anionic surfactants becomes troublesome. Some of the difficulties may be overcome by the use of additives, preferably ether sulphates or ether sulphonates. Hence, the favourable properties of nonionic substances, such as excellent stability to electrolytes, have been combined with those of anionics, and thus the so-called modified nonionics are available for chemical flooding. These products offer the possibility of chemical adaption to the reservoir conditions, are very stable toward electrolytes, and their solubility does not depend on the temperature. The latter is a drawback of nonionic products (cloud point). The modified nonionics are essentially anionics based on ethene oxide derivatives of alcohols or alkylphenols, with subsequent incorporation of sulphate, sulphonate, carboxyl or phosphate groups. On the basis of the reservoir conditions, crude oil properties, and reservoir water, various processes have been screened for enhanced oil recovery in the Velebit reservoir. It was decided to simultaneously inject modified nonionic surfactants and polymers. In part of the reservoir, this process will be tested in two stages in a line drive with several injection wells and production wells. The total area is about 20,000 m/sup 3/. The first stage involves water flooding of about half the area, in order to collect additional data on the reservoir. During the second stage, simultaneous injection of surfactants and polymers will take place. The reservoir is described, and possible EOR processes, the flooding concept and selection of chemicals are discussed.

  12. Enhanced recovery of conventional crude oils with flue gas

    Science.gov (United States)

    Shokoya, Olawale Surajudeen

    Flue gas injection is becoming more attractive as a feasible and environmentally friendly process for improving oil recovery from conventional oil reservoirs. When obtained from surface sources, the flue gas process has an added advantage of reducing carbon dioxide (CO2), a greenhouse gas, from being vented into the atmosphere. Flue gas can also be generated in situ by the spontaneous ignition of oil when air, a readily available gas, is injected into high temperature, high pressure conventional oil reservoirs. The availability of flue gas and/or air and the observed high oil recovery potential make the flue gas process an economically attractive process. The oil recovery potential from conventional oil reservoirs by flue gas injection, the displacement mechanism, and the effect of oil composition on these parameters were studied in the laboratory with three flue gas compositions having 0%, 16%, and 30% CO2 content and two recombined conventional crude oils (oils A and B) obtained from two different reservoirs. The oils were displaced by the flue gases in a 2.44 m (8 ft.) long, 5.1 cm (2 in.) diameter Berea sandstone core at irreducible brine saturation as well as in a 18.288m (60 ft.) long slim tube. These studies were conducted at reservoir pressures ranging from 17.62 MPa to 41.58 MPa and temperatures of 116°C and 80.6°C, corresponding to the respective reservoir temperature of the oils studied. Experimental coreflood results show that oil A recovery increases from 32.95% to 41.00% of the initial oil in place (IOIP) at 27.7 MPa as the CO 2 content in the flue gas increases from 0% to 30%. The recovery also increase with pressure from 32.95% to 50.94% IOIP at 0% CO2 flue gas content as the displacement pressure increases from 27.47 MPa to 41.58 MPa. Oil B recovery also increased from 45% to 50% IOIP with increase in CO 2 content in flue gas from 16% to 30% at 17.7 MPa. The results also show that conventional oil will benefit from enriched flue gas injection

  13. Shale oil value enhancement research. Quarterly report, June 1 - August 31, 1996

    Energy Technology Data Exchange (ETDEWEB)

    Bunter, J.W.; Russell, C.P.; Tsai, J.C.H.; Cogswell, D.E.; Mihamou, H.; Wright, A.D. [Bunger (James W.) and Associates, Inc., Salt Lake City, UT (United States)

    1996-12-31

    The overall objective is to develop a new technology for manufacturing valuable marketable products from shale oil. The quarter`s efforts were concentrated on (a) THDA and reaction of alkylpyridines at elevated conditions, (b) compound type analysis of kerogen oil and its derived products, (b) thermal hydrodealkylation of the > 290{degrees}C polar fraction, (c) secondary reactions of pyridinic type compounds to form marketable products, and (d) preparation of presentation to the Dawnbreaker Commercial Assistance Program. Excellent progress is being made in all cases. Our market analysis and industrial feedback indicate that the low molecular weight pyridines are the main market driving force. We are concentrating our effort toward increasing the yield of ``light`` pyridines before the end of Phase II(a). Our current laboratory set-up can only produce analytical quantity of samples, which is not sufficient for marketing purpose. However, the completion of a secondary flow THDA unit for a pilot-scale production depends on the availability of the Phase-II(b) and Phase-III funding.

  14. Naphthenic acids in groundwater overlying undeveloped shale gas and tight oil reservoirs.

    Science.gov (United States)

    Ahad, Jason M E; Pakdel, Hooshang; Lavoie, Denis; Lefebvre, René; Peru, Kerry M; Headley, John V

    2017-10-13

    The acid extractable organics (AEOs) containing naphthenic acids (NAs) in groundwater overlying undeveloped shale gas (Saint-Édouard region) and tight oil (Haldimand sector, Gaspé) reservoirs in Québec, Canada, were analysed using high resolution Orbitrap mass spectrometry and thermal conversion/elemental analysis - isotope ratio mass spectrometry. As classically defined by CnH2n+ZO2, the most abundant NAs detected in the majority of groundwater samples were straight-chain (Z = 0) or monounsaturated (Z = -2) C16 and C18 fatty acids. Several groundwater samples from both study areas, however, contained significant proportions of presumably alicyclic bicyclic NAs (i.e., Z = -4) in the C10-C18 range. These compounds may have originated from migrated waters containing a different distribution of NAs, or are the product of in situ microbial alteration of shale organic matter and petroleum. In most groundwater samples, intramolecular carbon isotope values generated by pyrolysis (δ(13)Cpyr) of AEOs were on average around 2-3‰ heavier than those generated by bulk combustion (δ(13)C) of AEOs, providing further support for microbial reworking of subsurface organic carbon. Although concentrations of AEOs were very low (<2.0 mg/L), the detection of potentially toxic bicyclic acids in groundwater overlying unconventional hydrocarbon reservoirs points to a natural background source of organic contaminants prior to any large-scale commercial hydrocarbon development. Crown Copyright © 2017. Published by Elsevier Ltd. All rights reserved.

  15. Recovery of Vanadium from H2SO4-HF Acidic Leaching Solution of Black Shale by Solvent Extraction and Precipitation

    Directory of Open Access Journals (Sweden)

    Xingbin Li

    2016-03-01

    Full Text Available The recovery of vanadium from sulfuric and hydrofluoric mixed acid solutions generated by the direct leaching of black shale was investigated using solvent extraction and precipitation methods. The process consisted of reduction, solvent extraction, and stripping, followed by precipitation and calcination to yield vanadium pentoxide. The influence of various operating parameters on the extraction and recovery of vanadium was studied. Vanadium (IV was selectively extracted using a mixture of 10% (v/v di(2-ethylhexylphosphoric acid and 5% (v/v tri-n-butylphosphate in sulfonated kerosene. Using six extraction and five stripping stages, the extraction efficiency for vanadium was 96.7% and the stripping efficiency was 99.7%. V2O5 with a purity of 99.52% was obtained by oxidation of the loaded strip solution and precipitation of ammonium polyvanadate at pH 1.8 to 2.2, followed by calcination of the dried precipitate at 550 °C for 2 h. It was concluded that the combination of solvent extraction and precipitation is an efficient method for the recovery of vanadium from a multi-element leach solution generated from black shale.

  16. Development of More Effective Biosurfactants for Enhanced Oil Recovery

    Energy Technology Data Exchange (ETDEWEB)

    McInerney, J.J.; Han, S.O.; Maudgalya, S.; Mouttaki, H.; Folmsbee, M.; Knapp, R.; Nagle, D.; Jackson, B.E.; Stuadt, M.; Frey, W.

    2003-01-16

    The objectives of this were two fold. First, core displacement studies were done to determine whether microbial processes could recover residual oil at elevated pressures. Second, the importance of biosurfactant production for the recovery of residual oil was studies. In these studies, a biosurfactant-producing, microorganisms called Bacillus licheniformis strain JF-2 was used. This bacterium produces a cyclic peptide biosurfactant that significantly reduces the interfacial tension between oil and brine (7). The use of a mutant deficient in surfactant production and a mathematical MEOR simulator were used to determine the major mechanisms of oil recovery by these two strains.

  17. Variations in Multiscale (nano to mm) Porosity in the Eagle Ford Shale as a Function of Maturity through the Oil Window

    Science.gov (United States)

    Anovitz, L. M.; Cole, D. R.; Swift, A.; Sheets, J.; Elston, H. W.; Gutierrez, M. A.; Cook, A.; Chipera, S.; Littrell, K. C.; Mildner, D. F.; Wasbrough, M.

    2013-12-01

    Porosity and permeability are key variables that link the thermal-hydrologic, geomechanical and geochemical behavior in rock systems and are thus important input parameters for transport models. Recent neutron scattering studies have indicated that the scales of pore sizes in rocks extend over many orders of magnitude from nanometer pores with huge amounts of total surface area to large open fracture systems (multiscale porosity, cf. Anovitz et al., 2009, 2011, 2013a,b). However, despite a considerable amount of effort combining conventional rock petrophysics with more sophisticated neutron scattering and electron microscopy studies, the quantitative nature of this porosity in tight gas shales, especially at smaller scales and over larger rock volumes, remains largely unknown (Clarkson, 2011). We lack a quantitative understanding of the multiscale porosity regime (i.e., pore size, shape, and volume, pore size distribution, pore connectivity, pore wall roughness) in rocks. Nor is it understood how porosity is affected by regional variation, thermal changes across the oil window, and, most critically, hydraulic fracturing operations. In order to begin to provide a quantitative understanding of porosity at nanometer to core scales in these shale formations and how it relates to gas storage and recovery we have used a combination of small and ultrasmall angle neutron scattering measurments made on the GP-SANS instrument at ORNL/HFIR, and the NG3-SANS and BT5-USANS instruments and NIST/NCNR, with SEM/BSE and X-ray Computed Tomographic imaging to analyze the pore structure of both clay and carbonate-rich samples of the Eagle Ford Shale. The Eagle Ford Shale is a late Cretaceous unit underlying much of southeast Texas and probably adjacent sections of Mexico. It outcrops in an arc from north of Austin, through San Antonio and then west towards Kinney County. It is hydrocarbon rich, and buried portions straddle the oil window. The Eagle Ford is currently one of the most

  18. Solar technology application to enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    de Leon, P.; Brown, K.C.; Margolis, J.W.; Nasr, L.H.

    1979-12-01

    One proposed near-term commercial application for solar energy technology is the use of solar energy systems to generate steam for thermal enhanced oil recovery (EOR). This report examines four aspects of solar energy employed for steam EOR. First, six solar technologies are evaluated and two - parabolic troughs and central receivers - are selected for closer study; typical systems that would meet current production requirements are proposed and costed. Second, the legal and environmental issues attending solar EOR are analyzed. Third, the petroleum producing companies' preferences and requirements are discussed. Finally, alternative means of financing solar EOR are addressed. The study concludes that within the next four to five years, conventional (fossil-fueled) thermal EOR means are much less expensive and more available than solar EOR systems, even given environmental requirements. Within 10 to 15 years, assuming specified advances in solar technologies, central receiver EOR systems will be significantly more cost-effective than parabolic trough EOR systems and will be price competitive with conventional thermal EOR systems. Important uncertainties remain (both in solar energy technologies and in how they affect the operating characteristics of petroleum reservoirs) that need resolution before definitive projections can be made.

  19. Carbon dioxide flooding as an enhanced oil recovery process

    Energy Technology Data Exchange (ETDEWEB)

    Mungan, N. (Alberta Energy Co. Ltd., AB (Canada))

    1992-11-01

    A description is presented of the state-of-the-art on carbon dioxide flooding and how it relates to recovery of heavy oils. Carbon dioxide flooding enhances recovery due to a number of mechanisms: reduction of oil viscosity, swelling of oil, vaporization of oil, miscibility effects, reduction of interfacial tension, solution gas drive, and increases in injectivity. Three types of reservoir are particularly well suited to carbon dioxide flooding: carbonate formations which may not have a high enough injectivity to make waterflooding successful; reservoirs containing undersaturated crude oils; and certain heavy oil reservoirs. A detailed description is presented of preparation for a field test, pressure-volume-temperature data for light and heavy crude oils, and a pilot testing of CO[sub 2] flooding. To the extent that it is possible, the pilot should closely represent the formation and fluid properties and the pressures that exist in the reservoir. 7 refs., 4 figs.

  20. Benzene exposure assessed by metabolite excretion in Estonian oil shale mineworkers: influence of glutathione s-transferase polymorphisms

    DEFF Research Database (Denmark)

    Sørensen, Mette; Poole, Jason; Autrup, Herman

    2004-01-01

    at an oil shale mine were compared with the excretion in workers engaged in various production assignments above ground. In addition, possible modifying effects of genetic polymorphisms in glutathione S-transferases T1 (GSTT1), M1 (GSTM1), and P1 (GSTP1) on the excretion of S-PMA and t,t-MA were......-PMA excretion were significantly higher in smokers compared with nonsmokers. Subjects carrying the GSTT1 wild-type excreted higher concentrations of S-PMA than subjects carrying the null genotype, suggesting that it is a key enzyme in the glutathione conjugation that leads to S-PMA. The results support the use...... of benzene metabolites as biomarkers for assessment of exposure at modest levels and warrant for further investigations of health risks of occupational benzene exposure in shale oil mines....

  1. Ammonia stripping, activated carbon adsorption and anaerobic biological oxidation as process combination for the treatment of oil shale wastewater.

    Science.gov (United States)

    Alexandre, Verônica M F; do Nascimento, Felipe V; Cammarota, Magali C

    2016-10-01

    Anaerobic biodegradability of oil shale wastewater was investigated after the following pretreatment sequence: ammonia stripping and activated carbon adsorption. Anaerobic biological treatment of oil shale wastewater is technically feasible after stripping at pH 11 for reducing the N-NH3 concentration, adsorption with 5 g/L of activated carbon in order to reduce recalcitrance and pH adjustment with CO2 so that the sulphate concentration in the medium remains low. After this pretreatment sequence, it was possible to submit the wastewater without dilution to an anaerobic treatment with 62.7% soluble chemical oxygen demand removal and specific methane production of 233.2 mL CH4STP/g CODremoved.

  2. Remedial processing of oil shale fly ash (OSFA) and its value-added conversion into glass-ceramics.

    Science.gov (United States)

    Zhang, Zhikun; Zhang, Lei; Li, Aimin

    2015-12-01

    Recently, various solid wastes such as sewage sludge, coal fly ash and slag have been recycled into various products such as sintered bricks, ceramics and cement concrete. Application of these recycling approaches is much better and greener than conventional landfills since it can solve the problems of storage of industrial wastes and reduce exploration of natural resources for construction materials to protect the environment. Therefore, in this study, an attempt was made to recycle oil shale fly ash (OSFA), a by-product obtained from the extracting of shale oil in the oil shale industry, into a value-added glass-ceramic material via melting and sintering method. The influence of basicity (CaO/SiO2 ratio) by adding calcium oxide on the performance of glass-ceramics was studied in terms of phase transformation, mechanical properties, chemical resistances and heavy metals leaching tests. Crystallization kinetics results showed that the increase of basicity reduced the activation energies of crystallization but did not change the crystallization mechanism. When increasing the basicity from 0.2 to 0.5, the densification of sintering body was enhanced due to the promotion of viscous flow of glass powders, and therefore the compression strength and bending strength of glass-ceramics were increased. Heavy metals leaching results indicated that the produced OSFA-based glass-ceramics could be taken as non-hazardous materials. The maximum mechanical properties of compression strength of 186 ± 3 MPa, bending strength of 78 ± 6 MPa, good chemical resistances and low heavy metals leaching concentrations showed that it could be used as a substitute material for construction applications. The proposed approach will be one of the potential sustainable solutions in reducing the storage of oil shale fly ash as well as converting it into a value-added product. Copyright © 2015 Elsevier Ltd. All rights reserved.

  3. Refining of Military Jet Fuels from Shale Oil. Volume I. Part II. Preparation of Laboratory-Scale Fuel Samples.

    Science.gov (United States)

    1982-03-01

    Sediment and Water BTU British Thermal Unit Degrees Celsius ’ C Carbon or Reteroatom Concentration Cl Methane .. C2 Ethane C3 Propane C3 Propylene...streams. The unsaturated gas plant receives gas from Section 200 and produces fuel gas, a propane /propylene stream, a mixed butane stream and a light...above, comprised the majority of the Task I effort. Pro- cessing studies were provided for the crude shale hydro- treater , FCC, cycle oil hydrotreater

  4. 17alpha/H/ hopane identified in oil shale of the Green River formation /Eocene/ by carbon-13 NMR.

    Science.gov (United States)

    Balogh, B.; Wilson, D. M.; Christiansen, P.; Burlingame, A. L.

    1973-01-01

    During an investigation of C-13 NMR shifts and the structural correspondence of pentacyclic triterpenes a C-13 NMR study was conducted on one of the most abundant components of the hexane soluble fraction of oil shale bitumen of the Green River formation. A rigorous proof was derived exclusively from C-13 NMR data for the structure of the important triterpenoid fossil molecule. It was established that the structure of the isolated triterpane was 17alpha(H) hopane.

  5. Spatial and Temporal Characteristics of Historical Oil and Gas Wells in Pennsylvania: Implications for New Shale Gas Resources.

    Science.gov (United States)

    Dilmore, Robert M; Sams, James I; Glosser, Deborah; Carter, Kristin M; Bain, Daniel J

    2015-10-20

    Recent large-scale development of oil and gas from low-permeability unconventional formations (e.g., shales, tight sands, and coal seams) has raised concern about potential environmental impacts. If left improperly sealed, legacy oil and gas wells colocated with that new development represent a potential pathway for unwanted migration of fluids (brine, drilling and stimulation fluids, oil, and gas). Uncertainty in the number, location, and abandonment state of legacy wells hinders environmental assessment of exploration and production activity. The objective of this study is to apply publicly available information on Pennsylvania oil and gas wells to better understand their potential to serve as pathways for unwanted fluid migration. This study presents a synthesis of historical reports and digital well records to provide insights into spatial and temporal trends in oil and gas development. Areas with a higher density of wells abandoned prior to the mid-20th century, when more modern well-sealing requirements took effect in Pennsylvania, and areas where conventional oil and gas production penetrated to or through intervals that may be affected by new Marcellus shale development are identified. This information may help to address questions of environmental risk related to new extraction activities.

  6. The PTRC : a world leader in enhanced heavy oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Kristoff, B.; Knudsen, R.; Asghari, K. [Petroleum Technology Research Centre, Regina, SK (Canada); Pappas, E.S. [Saskatchewan Research Council, Saskatoon, SK (Canada)

    2006-07-01

    The Petroleum Technology Research Centre (PTRC) fosters knowledge and progressive technologies to enhance the recovery of petroleum. This paper discussed the PTRC's leadership in enhanced heavy oil recovery, with particular reference to core research program such as heavy oil (post) cold flow; enhanced waterflooding; miscible/immiscible solvent injection; and near-wellbore conformance control. Other projects that were presented included a joint implementation of vapour extraction project (JIVE); and the IEA greenhouse gas (GHG) Weyburn-Midale carbon dioxide monitoring and storage project. The JIVE project will develop, demonstrate and evaluate solvent vapour extraction processes for enhanced oil recovery in heavy oil reservoirs. The GHG Weyburn-Midale project, launched in 2000, studies carbon dioxide injection and storage in partially depleted oil reservoirs. It was concluded that the PTRC continues to develop technologies to meet the world's energy requirements while mitigating both immediate and long-term environmental impacts. 4 figs.

  7. Assessing the geochemical variability of oil shale in the Attarat Um Ghudran deposit, Jordan

    Directory of Open Access Journals (Sweden)

    Margus Voolma

    2016-05-01

    Full Text Available The Cretaceous to Palaeogene oil shale (OS of Jordan is predominantly calcareous mudstone with intervals of mostly siliceous minerals, quartz and cristobalite–tridymite. Oil shale is rich in organic sulphur and trace elements. According to preliminary micropalaeontological data, the OS succession of the studied area, the south-central part of the Attarat Um Ghudran (AUG deposit in central Jordan, is of Maastrichtian age. A representative collection of 392 samples from 9 drill cores reliably characterizes the sequence of the OS seam, on average 70 m thick. The composition of AUG OS varies significantly. The major compounds CaO and SiO2 range within 3–70 wt% and 10–50 wt%, respectively, and also the contents of organic matter, MgO, P2O5, Al2O3 and S change. The concentrations of metals (especially Zn, V, Cr, Ni and Mo change many dozens of times in the cross section. The aim of our statistical analysis was to determine the most significant OS types and their positions in the OS sequence. Two multivariate statistical analysis methods, principal components analysis (PCA and hierarchical clustering of PCA groups, gave an interpretable result. Four principal components account for 88.6% of data variability. Variation in six main chemical components or groups of components is reflected in parameters of the four principal components. The component PC1 accounts for 47% of the data variance, expressing the highest correlation with organic matter, S, Cr, Cu, Ni, Zn, Mo, and PC2 accounts for 22.82% of the data variability, being strongly correlated with TiO2, Al2O3, Fe2O3, SiO2 and K2O and negatively correlated with CaO. The next two significant component groups express covariance with CaO and MgO. The applied statistical analysis proves to be a powerful tool for the interpretation of the chemically variable structure of the OS unit when using a representative enough sample collection. In the complex study of the OS unit, variation in the chemical

  8. Pressurized fluidized-bed hydroretorting of eastern oil shales. Volume 4, Task 5, Operation of PFH on beneficiated shale, Task 6, Environmental data and mitigation analyses and Task 7, Sample procurement, preparation, and characterization: Final report, September 1987--May 1991

    Energy Technology Data Exchange (ETDEWEB)

    1992-03-01

    The objective of Task 5 (Operation of Pressurized Fluidized-Bed Hydro-Retorting (PFH) on Beneficiated Shale) was to modify the PFH process to facilitate its use for fine-sized, beneficiated Eastern shales. This task was divided into 3 subtasks: Non-Reactive Testing, Reactive Testing, and Data Analysis and Correlations. The potential environment impacts of PFH processing of oil shale must be assessed throughout the development program to ensure that the appropriate technologies are in place to mitigate any adverse effects. The overall objectives of Task 6 (Environmental Data and Mitigation Analyses) were to obtain environmental data relating to PFH and shale beneficiation and to analyze the potential environmental impacts of the integrated PFH process. The task was divided into the following four subtasks. Characterization of Processed Shales (IGT), 6.2. Water Availability and Treatment Studies, 6.3. Heavy Metals Removal and 6.4. PFH Systems Analysis. The objective of Task 7 (Sample Procurement, Preparation, and Characterization) was to procure, prepare, and characterize raw and beneficiated bulk samples of Eastern oil shale for all of the experimental tasks in the program. Accomplishments for these tasks are presented.

  9. Microbial enhanced oil recovery and wettability research program

    Energy Technology Data Exchange (ETDEWEB)

    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.

  10. Enhancement of recovery of residual oil using a biosurfactant slug ...

    African Journals Online (AJOL)

    Characterization of the biosurfactant extract revealed a mixture of glycolipid and phospholipid in a ratio of 3.35:1. The irreducible water saturation (Swi) and initial residual oil saturation (Sor) of the sand-pack were 0.280 ± 0.003 and 0.373 ± 0.006, respectively. Core flooding experiment showed that an optimum oil recovery ...

  11. Effect of Brine Composition on Wettability Alteration and Oil Recovery from Oil-wet Carbonate Rocks

    Science.gov (United States)

    Purswani, P.; Karpyn, Z.

    2016-12-01

    Brine composition is known to affect the effectiveness of waterflooding during enhanced oil recovery from carbonate reservoirs. Recent studies have identified Mg2+, Ca2+ and SO42- as critical ions, responsible for incremental oil recovery via wettability alteration. To investigate the underlying mechanism of wettability alteration and, to evaluate the individual contribution of these ions towards improving oil recovery, a series of coreflooding experiments are performed. Various characterization techniques like zeta potential (ZP), drop angle analysis and inductively coupled plasma mass spectrometry (ICP MS) analysis are performed to evaluate the surface interactions taking place at the carbonate core samples, brine solution and crude oil interfaces. Total dissolved solids and electrical conductivity measurements confirm the ionic strength of the brine samples. Acid number calculations, ZP and contact angle measurements confirm the initial oil-wetting state of the core. ICP MS analysis of the effluent brine, confirm the relationship between the ionic interactions and oil recovery.

  12. High-order simulation of foam enhanced oil recovery

    NARCIS (Netherlands)

    Van der Meer, J.M.; Van Odyck, D.E.A.; Wirnsberger, P.; Jansen, J.D.

    2014-01-01

    If secondary hydrocarbon recovery methods fail because of the occurrence of gravity override or viscous fingering one can turn to an enhanced oil recovery method like the injection of foam. The generation of foam can be described by a set of partial differential equations with strongly nonlinear

  13. Microbial Enhanced Oil Recovery: 3D Simulation with Gravity Effects

    DEFF Research Database (Denmark)

    Nielsen, Sidsel Marie; Jessen, K.; Shapiro, Alexander

    2010-01-01

    Microbial enhanced oil recovery (MEOR) utilizes the activity of microorganisms, where microorganisms simultaneously grow in a reservoir and convert substrate into recovery enhancing products (usually, surfactants). In order to predict the performance of a MEOR process, a simulation tool is requir...

  14. Leaching of polycyclic aromatic hydrocarbons from oil shale processing waste deposit: a long-term field study.

    Science.gov (United States)

    Jefimova, Jekaterina; Irha, Natalya; Reinik, Janek; Kirso, Uuve; Steinnes, Eiliv

    2014-05-15

    The leaching behavior of selected polycyclic aromatic hydrocarbons (PAHs) from an oil shale processing waste deposit was monitored during 2005-2009. Samples were collected from the deposit using a special device for leachate sampling at field conditions without disturbance of the upper layers. Contents of 16 priority PAHs in leachate samples collected from aged and fresh parts of the deposit were determined by GC-MS. The sum of the detected PAHs in leachates varied significantly throughout the study period: 19-315 μg/l from aged spent shale, and 36-151 μg/l from fresh spent shale. Among the studied PAHs the low-molecular weight compounds phenanthrene, naphthalene, acenaphthylene, and anthracene predominated. Among the high-molecular weight PAHs benzo[a]anthracene and pyrene leached in the highest concentrations. A spent shale deposit is a source of PAHs that could infiltrate into the surrounding environment for a long period of time. Copyright © 2014 Elsevier B.V. All rights reserved.

  15. Laboratory methods for enhanced oil recovery core floods

    Energy Technology Data Exchange (ETDEWEB)

    Robertson, E.P.; Bala, G.A.; Thomas, C.P.

    1994-03-01

    Current research at the Idaho National Engineering Laboratory (INEL) is investigating microbially enhanced oil recovery (MEOR) systems for application to oil reservoirs. Laboratory corefloods are invaluable in developing technology necessary for a field application of MEOR. Methods used to prepare sandstone cores for experimentation, coreflooding techniques, and quantification of coreflood effluent are discussed in detail. A technique to quantify the small volumes of oil associated with laboratory core floods is described.

  16. Enhanced Oil Recovery with Surfactant Flooding

    DEFF Research Database (Denmark)

    Sandersen, Sara Bülow

    behavior inside the reservoir can be manipulated by the injection of surfactants and co-surfactants, creating advantageous conditions in order to mobilize trapped oil. Correctly designed surfactant systems together with the crude oil can create microemulsions at the interface between crude oil and water...... at constant salinity (6.56 %), constant surfactant-alcohol ratio (SAR) but with varying water-oil ratios (WOR). At all temperatures it was very clear that the effect of pressure was significant. The system changed from the two phase region, Winsor II, to the three phase region, Winsor III, as pressure...... characterization of the two crude oils using gas chromatography and SARA analysis confirmed that the heavier components in the crude oils, (in the case of the Latin American crude oil), are correlated to the observed decrease of viscosity, where the viscosity decrease may be explained from change of the shape...

  17. Efficiency of enhanced oil recovery using polymer-augmented low salinity flooding

    National Research Council Canada - National Science Library

    Almansour, Abdullah O; AlQuraishi, Abdulrahman A; AlHussinan, Saud N; AlYami, Hamdan Q

    2017-01-01

    Oil recovery from heavy oil resources has always been a challenging task. This work is aimed at investigating the recovery efficiency of polymer-augmented low salinity waterflooding in heavy oil reservoirs...

  18. Atmospheric Mercury in the Barnett Shale Area, Texas: Implications for Emissions from Oil and Gas Processing.

    Science.gov (United States)

    Lan, Xin; Talbot, Robert; Laine, Patrick; Torres, Azucena; Lefer, Barry; Flynn, James

    2015-09-01

    Atmospheric mercury emissions in the Barnett Shale area were studied by employing both stationary measurements and mobile laboratory surveys. Stationary measurements near the Engle Mountain Lake showed that the median mixing ratio of total gaseous mercury (THg) was 138 ppqv (140 ± 29 ppqv for mean ± S.D.) during the June 2011 study period. A distinct diurnal variation pattern was observed in which the highest THg levels appeared near midnight, followed by a monotonic decrease until midafternoon. The influence of oil and gas (ONG) emissions was substantial in this area, as inferred from the i-pentane/n-pentane ratio (1.17). However, few THg plumes were captured by our mobile laboratory during a ∼3700 km survey with detailed downwind measurements from 50 ONG facilities. One compressor station and one natural gas condensate processing facility were found to have significant THg emissions, with maximum THg levels of 963 and 392 ppqv, respectively, and the emissions rates were estimated to be 7.9 kg/yr and 0.3 kg/yr, respectively. Our results suggest that the majority of ONG facilities in this area are not significant sources of THg; however, it is highly likely that a small number of these facilities contribute a relatively large amount of emissions in the ONG sector.

  19. Residual shale-oil/diesel-engine operating compatibility program. Final report

    Energy Technology Data Exchange (ETDEWEB)

    Burnett, M.; Derbidge, C.; Kuby, W.; Niven, H.; Richard, R.

    1983-10-01

    As part of a DOE study to determine the effective utilization of alternate fuels in medium-speed diesel engines, a residual shale oil (RSO) was fired in an APE-Allen, 1000-rpm, 9.5-in. bore diesel engine. Various fuel injection modes were considered. Based on a fuel characterization study and go/no-go tests, it was determined that the direct firing of 100 percent RSO gave performance comparable with that using No. 2 diesel fuel; consequently, performance/endurance tests were performed using 100 percent RSO. Conclusions of this test program are: Laboratory tests showed low levels of corrosion and deposit-causing elements. Therefore, corrosion and wear of engine components, when using RSO, should be no worse than for standard diesel fuel. The high wax content of RSO requires heating for supply, handling, and injection systems. Laboratory tests showed that the cetane number of RSO was equivalent to No. 2 diesel; hence, no engine modifications should be needed to burn RSO. The engine performance on RSO was essentially similar to standard diesel fuel. The thermal efficiency was slightly lower and Bosch smoke and particulates were slightly higher, especially at low load. Soft carbon deposits, formed on injectors when using RSO, did not affect performance. The 115-hour endurance test showed no significant performance deterioration. The deposit accumulation in combustion chambers and ports was not severe but was greater than standard diesel fuel would produce. Longer endurance tests are required to fully establish this conclusion. 41 figures, 21 tables.

  20. Preparation of a novel inorganic polymer coagulant from oil shale ash

    Energy Technology Data Exchange (ETDEWEB)

    Sun Tong, E-mail: jzsuntong@sina.com [Key Laboratory of Applied Chemistry, Bohai University, Jinzhou (China); Faculty of Chemistry and Chemical Engineering, Bohai University, Jinzhou 121013 (China); Liu Lianli; Wang Lili; Zhang Yanping [Center for Science and Technology Experiment, Bohai University, Jinzhou 121013 (China)

    2011-01-30

    In this paper, a novel inorganic polymer coagulant was prepared from oil shale ash, and was adopted to treat municipal sewage. Effect of coagulants dosage on the turbidity and Chemical Oxygen Demand (COD) removal were examined. In addition, the structure and morphology of the prepared coagulants were characterized by transmission electron microscopy (TEM), X-ray diffraction (XRD) and infra-red spectra (FTIR), furthermore, the zeta potential of the sewage and the microscopic images of flocks were measured. The results indicate that the characterization and coagulation performance of the samples are affected by Al/Fe mole ratios and the type of lixiviant. The most of Fe{sup 3+} is not turned into the crystals, which means that the samples are not simple mixtures of raw materials but inorganic polymer compounds with iron, aluminum, silicon and other ions. When Al/Fe mole ratio is 0.71 or the 2HCl/H{sub 2}SO{sub 4} mole ratio of the lixiviant is 1:1, the coagulation performance of the sample is better than that of the others. The integrated analysis suggests that the entrapment, adsorption and complexation abilities play important roles in coagulation process although the charge neutralization is weak. Also, the chain-net structure and the suitable size of polymer group are favorable for the entrapment, adsorption and complexation ability of the samples.

  1. Water Usage for In-Situ Oil Shale Retorting – A Systems Dynamics Model

    Energy Technology Data Exchange (ETDEWEB)

    Earl D. Mattson; Larry Hull; Kara Cafferty

    2012-12-01

    A system dynamic model was construction to evaluate the water balance for in-situ oil shale conversion. The model is based on a systems dynamics approach and uses the Powersim Studio 9™ software package. Three phases of an insitu retort were consider; a construction phase primarily accounts for water needed for drilling and water produced during dewatering, an operation phase includes the production of water from the retorting process, and a remediation phase water to remove heat and solutes from the subsurface as well as return the ground surface to its natural state. Throughout these three phases, the water is consumed and produced. Consumption is account for through the drill process, dust control, returning the ground water to its initial level and make up water losses during the remedial flushing of the retort zone. Production of water is through the dewatering of the retort zone, and during chemical pyrolysis reaction of the kerogen conversion. The major water consumption was during the remediation of the insitu retorting zone.

  2. Evaluation of an eastern shale oil residue as an asphalt additive

    Energy Technology Data Exchange (ETDEWEB)

    Thomas, K.P.; Harnsberger, P.M.

    1995-12-19

    An evaluation of eastern shale oil (ESO) residue as an asphalt additive to reduce oxidative age-hardening and moisture susceptibility was conducted. The ESO residue, having a viscosity of 23.9 Pa{sm_bullet}s at 60{degrees}C (140{degrees}F), was blended with three different petroleum-derived asphalts, AAD-1, AAK-1, and AAM-1, that are known to be very susceptible to oxidative aging. Rheological and infrared analyses of the unaged and aged asphalts and the blends were then conducted to evaluate oxidative age-hardening. In addition, the petroleum-derived asphalts and the blends were coated onto three different aggregates, Lithonia granite (RA), a low-absorption limestone (RD), and a silicious Gulf Coast gravel (RL), and compacted into briquets. Successive freeze-thaw cycling was then conducted to evaluate the moisture susceptibility of the prepared briquets. The abbreviations used above for the asphalts and the aggregates are part of the Strategic Highway Research Program nomenclature.

  3. Preliminary feasibility studies in times of rapid cost escalation. [Oil shale and tar sand industries

    Energy Technology Data Exchange (ETDEWEB)

    Oliver, E.D.; Moll, A.J.

    1976-01-01

    Not the least of the problems delaying the development and commercialization of synthetic fuel processes has been the extraordinary escalation of cost estimates by factors of up to ten in the past eight years. This study identifies and analyzes some of the most important contributing factors that have converged in the last few years. These factors include overoptimism and ill-defined project scope in the early stages, tightening environmental controls, difficulties in obtaining raw materials and fuels, general inflationary trends, ''hyperinflation'' of the costs of critical equipment, local labor shortages, and increased times required for procurement and construction. Cost increases have been particularly dramatic for ''offsites,'' liberally defined as nonprocess related parts of projects. Case histories of oil shale and tar sand developments are analyzed. Learning curves of costs during development and commercial use are studied. The analysis suggests that the worst of the extraordinary increases (above general inflationary trends) are probably over. Criteria to judge the state of development of processes are given, and some procedures to avoid future pitfalls are suggested.

  4. Photocatalytic oxidation of phenolic compounds in wastewater from oil shale treatment

    Energy Technology Data Exchange (ETDEWEB)

    Preis, Sergei; Terentyeva, Yelena [Tallinn Technical Univ., Chemical Engineering Dept., Tallinn (Estonia); Rozkov, Aleksei [Tallinn Technical Univ., Biochemistry Dept., Tallinn (Estonia)

    1997-12-31

    Experimental research into the photooxidation of aqueous solutions and wastewaters containing phenolic compounds was undertaken. Titanium dioxide under near-UV irradiation was selected as a photocatalyst. Phenol, p-cresol, resorcinol and 5-methylresorcinol (5-MR) were chosen as model compounds for the experiments with synthetic phenolic solutions. The photooxidative treatment of phenolic solutions was found to be more effective in acidic and strongly alkaline media. No difference was found between shortwave and near-UV irradiation photooxidation abilities. Methylated phenolic substitutes (p-cresol, 5-MR) yield better to photooxidation than non-methylated compounds. The higher the irradiation intensity the lower the photooxidation efficiency. The results obtained from the experiments with model compounds were compared with the results of photooxidative purification of wastewaters produced from the thermal treatment of oil shale in Estonia. Being heavily polluted, the wastewater yields better to photooxidation when slightly diluted with potable water in a 3:1 ratio. Anatase, immobilised onto the surface of buoyant hollow glass microspheres, was less effective than when suspended in a slurry. The photooxidatively pre-treated wastewater showed better biodegradability and lower toxicity to bacteria than untreated wastewater. (Author)

  5. Numerical approach for enhanced oil recovery with surfactant flooding

    Directory of Open Access Journals (Sweden)

    Sadegh Keshtkar

    2016-03-01

    concentration and performance variable (cumulative oil recovery are studied. Finally, the comparison of oil recovery between water-flooding and surfactant-flooding was done. The results showed higher oil recovery with changes in capillary number when the partition coefficient is greater than unity. Increasing oil viscosity resulted in decreasing the oil recovery by changing in fractional flow. Moreover, it was concluded that the oil recovery was enhanced by increasing surfactant injection concentration. The oil recovery was increased when surfactant was injected to the system and this result was obtained by comparing water-flooding and surfactant-flooding.

  6. The recovery of oil from spent bleaching earth

    Energy Technology Data Exchange (ETDEWEB)

    El-Bassuoni, A.A.; Sherief, H.M.; Tayeb, A.M.; Ahmed, K.K. [Minia Univ., Minia (Egypt). Dept. of Chemical Engineering

    2000-07-01

    Four solvent based extraction methods to recover oil from spent bleached earth were presented. Spent bleaching earth is a solid waste that is generated during the processing of vegetable oils. It is removed from the oil with filters and contains approximately 25-29 per cent oil by weight. At the onset of the study, the oil entrained with the spent bleaching earth filtration was determined to be 25 per cent. Four solvents, N-hexane, carbon tetra chloride, benzene and 1,2 dichloroethane were used in this study. The per cent recovery of oil was calculated by measuring the concentration of oil by spectrophotometer. The effect of temperature on the recovery of oil and different solid:liquid ratios was also studied for the four solvents. The following four methods were used for the recovery of oil were solvent extraction, extraction with 1 per cent sodium carbonate solution, extraction with 4.5 per cent sodium dodecyl sulphite solution and boiling with 12 per cent sodium hydroxide solution. All methods gave satisfactory results indicating that the earth could be reused. 12 refs., 3 tabs.

  7. Risk assessment of human exposure to Ra-226 in oil produced water from the Bakken Shale.

    Science.gov (United States)

    Torres, Luisa; Yadav, Om Prakash; Khan, Eakalak

    2018-01-20

    Unconventional oil production in North Dakota (ND) and other states in the United States uses large amounts of water for hydraulic fracturing to stimulate oil flow. Most of the water used returns to the surface as produced water (PW) containing different constituents. Some of these contents are total dissolved solids and radionuclides. The most predominant radionuclide in PW is radium-226 (Ra-226) of which level depends on several factors including the content of certain cations. A multivariate regression model was developed to predict Ra-226 in PW from the Bakken Shale based on the levels of barium, strontium, and calcium. The simulated Ra-226 activity concentration in PW was 535 pCi/L supporting extremely limited actual data based on three PW samples from the Bakken (527, 816, and 1210 pCi/L). The simulated activity concentration was further analyzed by studying its impact in the event of a PW spill reaching a surface water body that provides drinking water, irrigation water for crops, and recreational fishing. Using food transfer factors found in the literature, the final annual effective dose rate for an adult in ND was estimated. The global average annual effective dose rate via food and drinking water is 0.30 mSv, while the predicted dose rate in this study was 0.49 mSv indicating that there is potential risk to human health in ND due to Ra-226 in PW spills. This predicted dose rate is considered the best case scenario as it is based on the simulated Ra-226 activity concentration in PW of 535 pCi/L which is close to the low end actual activity concentration of 527 pCi/L. Copyright © 2018 Elsevier B.V. All rights reserved.

  8. Irrigation experiments with produced waters from the retorting of oil shale

    Energy Technology Data Exchange (ETDEWEB)

    Hutchinson, D.L.

    1980-12-01

    The research described herein was conducted by Geokinetics to qualitatively assess the tolerance of native and certain introduced species of vegetation to irrigation with produced water from the retorting of oil shale. Two separate experiments were conducted at the Kamp Kerogen field site in Uintah County, Utah. The results indicate possible effects on vegetation that a prolonged exposure to produced water would have. The two simple experiments were initiated during the summer of 1979. It was expected that irrigation with produced water would eventually result in detrimental effects to the plants receiving it; the concentrations of boron, molybdenum, arsenic, oil and other constituents in untreated production waters are high enough to likely cause damage to plants. In one experiment a 27 foot by 27 foot plot of native vegetation was irrigated with one inch of produced water per week for five weeks using a lawn sprinkler. Grasses and shrubs within the test plot appeared to have died; germination of annual plants was greatly inhibited. In the other experiment, 30 container-grown seedlings ranging in height from 0.3 feet to 3.0 feet were transplanted. Six species of broadleaf, deciduous trees not native to the test site were represented by five seedlings each. All 30 trees received well water irrigation for one month, after which four trees of each species were irrigated with produced water for seven weeks. One tree of each species continued to receive well water throughout the experiment; only two of those trees survived the summer of 1979. All six species appeared to have been adversely affected by produced water. The horse chesnut trees were the hardiest of the species planted. Most of the 30 trees, including those irrigated with well water, did not survive the winter season.

  9. Recovery of aroma compounds from orange essential oil

    Directory of Open Access Journals (Sweden)

    Haypek E.

    2000-01-01

    Full Text Available The objective of this work was to study the recovery of aroma compounds present in the orange essential oil using experimental data from CUTRALE (a Brazilian Industry of Concentrated Orange Juice. The intention was to reproduce the industrial unit and afterwards to optimize the recovery of aroma compounds from orange essential oil by liquid-liquid extraction. The orange oil deterpenation was simulated using the commercial software PRO/II 4.0 version 1.0. The UNIFAC model was chosen for the calculation of the activity coefficients.

  10. Mobile inert gas generator for attic oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Owens, H.B. Jr.; Mosby, J.; Anson, R.H.

    1969-01-01

    Attic oil is usually defined as that oil which is trapped upstructure of the structurally highest producible well in a reservoir. If it is not economically feasible to drill a well for this oil accumulation, attic oil recovery by gas displacement is a possible secondary recovery method. The mechanics of the method are that gas is injected into the structurally highest well, the gas migrating up dip into the attic, forcing the oil downdip where it can be produced from the injection well or other wells in the reservoir. Where natural gas is in short supply or if injected gas cannot be recovered, inert gas generators for gas injection have a practical application. Oil accumulations found over and around piercement-type salt domes, such as the Bayou Des Allemands field, are usually excellent prospects for attic oil recovery by inert gas injection. After an economical comparison between recovery by natural gas or inert gas injection, it was found that the inert gas generator would be advantageous; therefore, an inert gas generator mounted on a cement barge was purchased. This study deals with this equipment which has now been in operation for one yr.

  11. Sweet spots for hydraulic fracturing oil or gas production in underexplored shales using key performance indicators: Example of the Posidonia Shale formation in the Netherlands

    NARCIS (Netherlands)

    Heege, J.H. ter; Zijp, M.H.A.A.; Nelkamp, S.

    2015-01-01

    While extensive data and experiences are available for hydraulic fracturing and hydrocarbon production from shales in the U.S.A., such a record is lacking in many underexplored shale basins worldwide. As limited data is usually available in these basins, analysis of shale prospectivity and

  12. Pyrolysis Recovery of Waste Shipping Oil Using Microwave Heating

    Directory of Open Access Journals (Sweden)

    Wan Adibah Wan Mahari

    2016-09-01

    Full Text Available This study investigated the use of microwave pyrolysis as a recovery method for waste shipping oil. The influence of different process temperatures on the yield and composition of the pyrolysis products was investigated. The use of microwave heating provided a fast heating rate (40 °C/min to heat the waste oil at 600 °C. The waste oil was pyrolyzed and decomposed to form products dominated by pyrolysis oil (up to 66 wt. % and smaller amounts of pyrolysis gases (24 wt. % and char residue (10 wt. %. The pyrolysis oil contained light C9–C30 hydrocarbons and was detected to have a calorific value of 47–48 MJ/kg which is close to those traditional liquid fuels derived from fossil fuel. The results show that microwave pyrolysis of waste shipping oil generated an oil product that could be used as a potential fuel.

  13. Laboratory Experiments on Enhanced Oil Recovery with Nitrogen Injection

    Directory of Open Access Journals (Sweden)

    S. Siregar

    2007-05-01

    Full Text Available Based on previous studies, nitrogen injection could recover oil up to 45-90% of initial reserves. Although this method has a very good ability to produce oil, sometimes the operation pressure is higher than leak off formation pressure. In this study, operation pressure used a low pressure to solve this problem under immiscible process. Objective of this study is to determine the effect of injection pressure and displacement rate on oil recovery performance of continuous one dimensional nitrogen gas injection with a slim tube apparatus. The effect of nitrogen gas-oil contact on the gas composition was investigated using Gas Chromatograph Mass Spectrometer apparatus. In the experiments, nitrogen gas was injected into an oil sample of 38.5 oAPI gravity at various rates: 20 cc/hr, 30 cc/hr and 36.66/hr under 1500 psi pressure, and then at 20 cc/hr undr 2500 psi pressure. The results showed that an increase in injection rate increased oil recovery factor. The recovery factor lies between 40-54% of original oil in place. Gas analysis before injection and at the injection outlet showed a change of composition. when oil was contacted by nitrogen, indicating that some molecular mass transfer had taken place.

  14. Assessment and control of water contamination associated with shale oil extraction and processing. Progress report, October 1, 1979-September 30, 1980

    Energy Technology Data Exchange (ETDEWEB)

    Peterson, E.J.; Henicksman, A.V.; Fox, J.P.; O' Rourke, J.A.; Wagner, P.

    1982-04-01

    The Los Alamos National Laboratory's research on assessment and control of water contamination associated with oil shale operations is directed toward the identification of potential water contamination problems and the evaluation of alternative control strategies for controlling contaminants released into the surface and underground water systems from oil-shale-related sources. Laboratory assessment activities have focused on the mineralogy, trace element concentrations in solids, and leaching characteristics of raw and spent shales from field operations and laboratory-generated spent shales. This report details the chemical, mineralogic, and solution behavior of major, minor, and trace elements in a variety of shale materials (spent shales from Occidental retort 3E at Logan Wash, raw shale from the Colony mine, and laboratory heat-treated shales generated from Colony mine raw shale). Control technology research activities have focused on the definition of control technology requirements based on assessment activities and the laboratory evaluation of alternative control strategies for mitigation of identified problems. Based on results obtained with Logan Wash materials, it appears that the overall impact of in situ processing on groundwater quality (leaching and aquifer bridging) may be less significant than previously believed. Most elements leached from MIS spent shales are already elevated in most groundwaters. Analysis indicates that solubility controls by major cations and anions will aid in mitigating water quality impacts. The exceptions include the trace elements vanadium, lead, and selenium. With respect to in situ retort leaching, process control and multistaged counterflow leaching are evaluated as alternative control strategies for mitigation of quality impacts. The results of these analyses are presented in this report.

  15. Assessment of potential shale oil and tight sandstone gas resources of the Assam, Bombay, Cauvery, and Krishna-Godavari Provinces, India, 2013

    Science.gov (United States)

    Klett, Timothy R.; Schenk, Christopher J.; Wandrey, Craig J.; Brownfield, Michael E.; Charpentier, Ronald R.; Tennyson, Marilyn E.; Gautier, Donald L.

    2014-01-01

    Using a well performance-based geologic assessment methodology, the U.S. Geological Survey estimated a technically recoverable mean volume of 62 million barrels of oil in shale oil reservoirs, and more than 3,700 billion cubic feet of gas in tight sandstone gas reservoirs in the Bombay and Krishna-Godavari Provinces of India. The term “provinces” refer to geologically defined units assessed by the USGS for the purposes of this report and carries no political or diplomatic connotation. Shale oil and tight sandstone gas reservoirs were evaluated in the Assam and Cauvery Provinces, but these reservoirs were not quantitatively assessed.

  16. Dow shale site tracer gas pressurization study. Final report. Appendix: energy from in situ processing of Antrim oil shale

    Energy Technology Data Exchange (ETDEWEB)

    Peterson, E.W.; Lagus, P.L.

    1977-10-01

    A series of tracer gas pressurization experiments were undertaken at the Dow shale site at Peck, Michigan. The study was conducted to evaluate flow communication between boreholes open to both the Antrim and False Antrim layers of the retort volume, determine permeability and porosity distributions within the retort volume, and to assess qualitatively the uniformity of the fracturing or rubblization within the retort volume. Results show that the system is non-uniform. Flow from Well No. 4 to the other wells occurs primarily through various flow channels. These channels open when the wellhead pressure approaches the overburden pressure and appear closed at lower pressures. Consequently, the system is pressure sensitive and the flow is enhanced at elevated system pressures. Flow to outlying wells, such as No. 8 and No. 10, occurred only when Well No. 3 was at an elevated pressure. When the system approached steady state, as indicated by an absence of pressure changes, the production rate was about /sup 1///sub 3/ the injection rate. Multiple tracer gas injection into Well No. 4 at various depths demonstrated conclusively that flow does occur through the Antrim formation in the vicinity of Well No. 4. The permeability and porosity found in the vicinity of Well No. 4 was k approximately 0.045 millidarcy and phi approximately = 0.1 for a radius <1.75 ft and approximately 0.001 for radii greater than 1.75 ft. The major flow from Well No. 4 is toward Well No. 3, which in turn communicates readily with Wells No. 5 and No. 6. This flow occurs as a slug flow.

  17. Rehabilitation potential and practices of Colorado oil shale lands. Progress report, June 1, 1978--May 31, 1979

    Energy Technology Data Exchange (ETDEWEB)

    Cook, C.W.

    1979-03-01

    The following document is a third-year progress report for the period June 1, 1978 to May 31, 1979. The overall objective of the project is to study the effects of seeding techniques, species mixtures, fertilizer, ecotypes, improved plant materials, mycorrhizal fungi, and soil microorganisms on the initial and final stages of reclamation obtained through seeding and subsequent succession on disturbed oil shale lands. Plant growth medias that are being used in field-established test plots include retorted shale, soil over retorted shale, subsoil materials, and surface disturbed topsoils. Because of the long-term nature of successional and ecologically oriented studies the project is just beginning to generate significant publications. Several of the studies associated with the project have some phases being conducted principally in the laboratories and greenhouses at Colorado State Univerisity. The majority of the research, however, is being conducted on a 20 hectare Intensive Study Site located near the focal points of oil shale activity in the Piceance Basin. The site is at an elevation of 2,042 m, receives approximately 30 to 55 cm of precipitation annually, and encompasses the plant communities most typical of the Piceance Basin. Most of the information contained in this report originated from the monitoring and sampling of research plots established in either the fall of 1976 or 1977. Therefore, data that have been obtained from the Intensive Study Site represent only first- or second-year results. However, many trends have been identified in thesuccessional process and the soil microorganisms and mycorrhizal studies continue to contribute significant information to the overall results. The phytosociological study has progressed to a point where field sampling is complete and the application and publication of this materials will be forthcoming in 1979.

  18. Phosphoric acid activation of Morrocan oil shale of Timahdit: Influence of the experimental conditions on yield and surface area of adsorbents

    Science.gov (United States)

    Ichcho, S.; Khouya, E.; Abourriche, A.; Ezzine, M.; Hannache, H.; Naslain, R.; Pailler, R.

    2005-03-01

    The use of Moroccan oil shale for the preparation of adsorbents by chemical activation with phosphoric acid is analysed. The results indicate that this material is promising for this application. The effect of different conditions of preparation on the yield and surface area is discussed. These parameters are H{3}PO{4}/shale weight ratio, carbonisation temperature, carbonisation time and concentration of H{3}PO{4}.

  19. Modeling of hydrologic conditions and solute movement in processed oil shale waste embankments under simulated climatic conditions. Third quarterly report, April 1993--June 1993

    Energy Technology Data Exchange (ETDEWEB)

    Reeves, T.L.; Turner, J.P.; Rangarajan, S.; Skinner, Q.D.; Hasfurther, V.

    1993-08-11

    This report presents research objectives, discusses activities, and presents technical progress for the period April 1, 1993 through June 31, 1993 on Contract No. DE-FC21-86LC11084 with the Department of Energy, Laramie Project Office. The scope of the research program and the continuation is to study interacting hydrologic, geotechnical, and chemical factors affecting the behavior and disposal of combusted processed oil shale. The research combines bench-scale testing with large scale research sufficient to describe commercial scale embankment behavior. The large scale approach was accomplished by establishing five lysimeters, each 7.3 {times} 3.0 {times} 3.0 m deep, filled with processed oil shale that has been retorted and combusted by the Lurgi-Ruhrgas (Lurgi) process. Approximately 400 tons of Lurgi processed oil shale waste was provided by Rio Blanco Oil Shale Co., Inc. (RBOSC) through a separate cooperative agreement with the University of Wyoming (UW) to carry out this study. Three of the lysimeters were established at the RBOSC Tract C-a in the Piceance Basin of Colorado. Two lysimeters were established in the Environmental Simulation Laboratory (ESL) at UW. The ESL was specifically designed and constructed so that a large range of climatic conditions could be physically applied to the processed oil shale which was filled in the lysimeter cells.

  20. Geochemical Features of Shale Hydrocarbons of the Central Part of Volga-Ural Oil and Gas Province

    Science.gov (United States)

    Nosova, Fidania F.; Pronin, Nikita V.; Plotnikova, Irina N.; Nosova, Julia G.

    2014-05-01

    This report contains the results of the studies of shale hydrocarbons from carbonate-siliceous rocks on the territory of South-Tatar arch of Volga-Ural oil and gas province of the East European Platform. The assessment of the prospects of shale hydrocarbon in Tatarstan primarily involves finding of low permeable, poor-porous shale strata that would be rich in organic matter. Basing on the analysis of the geological structure of the sedimentary cover, we can distinguish three main objects that can be considered as promising targets for the study from the point of the possible presence of shale hydrocarbons: sedimentary deposits Riphean- Vendian; Domanicoid high-carbon rocks of Devonian time; sedimentary strata in central and side areas of Kama-Kinel deflection system. The main object of this study is Domanicoid high-carbon rocks of Devonian time. They are mainly represented by dark gray, almost black bituminous limestones that are interbedded with calcareous siliceous shales and cherts. Complex studies include the following: extraction of bitumen from the rock, determination of organic carbon content, determination of the group and elemental composition of the bitumen, gas chromatographic studies of the alkanoic lube fractions of bitumoid and oil, gas chromato-mass spectrometry of the naphthenic lube fractions of bitumoid and oil, pyrolysis studies of the rock using the Rock -Eval method (before and after extraction), study of trace-element composition of the rocks and petrologen, comparison in terms of adsorbed gas and studying of the composition of adsorbed gases. Group and elemental analyses showed that hydrocarbons scattered in the samples contain mainly resinous- and asphaltene components, the share lube fraction is smaller. The terms sediment genesis changed from weakly to strongly reducing. According to the results of gas chromatography, no biodegradation processes were observed. According to biomarker indicators in the samples studied there is some certain

  1. DEVELOPMENT OF BIOSURFACTANT-MEDIATED OIL RECOVERY IN MODEL POROUS SYSTEMS AND COMPUTER SIMULATIONS OF BIOSURFACTANT-MEDIATED OIL RECOVERY

    Energy Technology Data Exchange (ETDEWEB)

    M.J. McInerney; S.K. Maudgalya; R. Knapp; M. Folmsbee

    2004-05-31

    Current technology recovers only one-third to one-half of the oil that is originally present in an oil reservoir. Entrapment of petroleum hydrocarbons by capillary forces is a major factor that limits oil recovery (1, 3, 4). Hydrocarbon displacement can occur if interfacial tension (IFT) between the hydrocarbon and aqueous phases is reduced by several orders of magnitude. Microbially-produced biosurfactants may be an economical method to recover residual hydrocarbons since they are effective at low concentrations. Previously, we showed that substantial mobilization of residual hydrocarbon from a model porous system occurs at biosurfactant concentrations made naturally by B. mojavensis strain JF-1 if a polymer and 2,3-butanediol were present (2). In this report, we include data on oil recovery from Berea sandstone experiments along with our previous data from sand pack columns in order to relate biosurfactant concentration to the fraction of oil recovered. We also investigate the effect that the JF-2 biosurfactant has on interfacial tension (IFT). The presence of a co-surfactant, 2,3-butanediol, was shown to improve oil recoveries possibly by changing the optimal salinity concentration of the formulation. The JF-2 biosurfactant lowered IFT by nearly 2 orders of magnitude compared to typical values of 28-29 mN/m. Increasing the salinity increased the IFT with or without 2,3-butanediol present. The lowest interfacial tension observed was 0.1 mN/m. Tertiary oil recovery experiments showed that biosurfactant solutions with concentrations ranging from 10 to 60 mg/l in the presence of 0.1 mM 2,3-butanediol and 1 g/l of partially hydrolyzed polyacrylamide (PHPA) recovered 10-40% of the residual oil present in Berea sandstone cores. When PHPA was used alone, about 10% of the residual oil was recovered. Thus, about 10% of the residual oil recovered in these experiments was due to the increase in viscosity of the displacing fluid. Little or no oil was recovered at

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  3. Oil recovery technology: key to future US supply

    Energy Technology Data Exchange (ETDEWEB)

    Kastrop, J.E.

    1972-12-01

    Secondary and tertiary recovery will account for over half the oil produced in the U.S. by 1980, exclusive of the North Slope. Estimates indicate that nearly 5,000,000 bopd will be produced from these oil recovery projects while total crude production in the Lower 48 will amount to just under 10,000,000 bopd. By this time, it is anticipated that North Slope oil will reach about 2,000,000 bopd. Last yr, secondary and tertiary recovery accounted for about 30% or 3,000,000 bopd in the U.S., and both will grow significantly with demand and some economic encouragement. Tertiary projects, now estimated to present a little more than 200,000 bopd, will increase to over 400,000 bopd by 1975, then to 1,000,000 bopd by 1980. The trend is shown in graphic form.

  4. Enhanced recovery of unconventional gas. Volume II. The program. [Tight gas basins; Devonian shale; coal seams; geopressured aquifers

    Energy Technology Data Exchange (ETDEWEB)

    Kuuskraa, V.A.; Brashear, J.P.; Doscher, T.M.; Elkins, L.E.

    1978-10-01

    This study was conducted to assist public decision-makers in selecting among many choices to obtain new gas supplies by addressing 2 questions: 1) how severe is the need for additional future supplies of natural gas, and what is the economic potential of providing part of future supply through enhanced recovery from unconventional natural gas resources. The study also serves to assist the DOE in designing a cost-effective R and D program to stimulate industry to recover this unconventional gas and to produce it sooner. Tight gas basins, Devonian shale, methane from coal seams, and methane from geopressured aquifers are considered. It is concluded that unconventional sources, already providing about 1 Tcf per year, could provide from 3 to 4 Tcf in 1985 and from 6 to 8 Tcf in 1990 (at $1.75 and $3.00 per Mcf, respectively). However, even with these additions to supply, gas supply is projected to remain below 1977 usage levels. (DLC)

  5. Total lead (Pb) concentration in oil shale ash samples based on correlation to isotope Pb-210 gamma-spectrometric measurements

    Energy Technology Data Exchange (ETDEWEB)

    Vaasma, T.; Kiisk, M.; Tkaczyk, A.H. [University of Tartu (Estonia); Bitjukova, L. [Tallinn University of Technology (Estonia)

    2014-07-01

    Estonian oil shale consists of organic matter and mineral material and contains various amounts of heavy metals as well as natural radionuclides (from the U-238 and Th-232 series and K-40). Previous research has shown that burning oil shale in the large power plants causes these radionuclides to become enriched in different ash fractions and be partially emitted to the atmosphere via fly ash and flue gases. The activity concentrations (Bq/kg) of these nuclides in different oil shale ash fractions vary significantly. This is influenced by the boiler parameters and combustion conditions - prevailing temperatures, pressure, ash circulating mechanisms, fly ash particle size, chemical composition of ash and coexistence of macro and micro components. As with radionuclides, various heavy metals remain concentrated in the ash fractions and are released to the atmosphere (over 20 tons of Pb per year from Estonian oil shale power plants). Lead is a heavy metal with toxic influence on the nervous system, reproductive system and different organs in human body. Depending on the exposure pathways, lead could pose a long term health hazard. Ash samples are highly heterogeneous and exhibit great variability in composition and particle size. Determining the lead concentration in ash samples by modern methods like inductively coupled plasma mass spectroscopy (ICP-MS), flame atomic absorption spectrometry (FAAS), graphite furnace atomic absorption spectroscopy (GFAAS) and other techniques often requires time consuming, multistage and complex chemical sample preparation. The list of possible methods to use is lengthy, but it is a challenge to choose a suitable one to meet measurement needs and practical considerations. The detection limits, capital costs and maintenance expenses vary between the instruments. This work presents the development of an alternative measurement technique for our oil shale ash samples. Oil shale ash was collected from different boilers using pulverized fuel

  6. USGS National Assessment of Oil and Gas Project - Shale Gas Assessment Units

    Data.gov (United States)

    U.S. Geological Survey, Department of the Interior — The U.S. Geological Survey has compiled a map of shale gas assessments in the United States that were completed by 2012, such assessments having been included as...

  7. Environmental Survey preliminary report, Naval Petroleum and Oil Shale Reserves in Colorado, Utah, and Wyoming, Casper, Wyoming

    Energy Technology Data Exchange (ETDEWEB)

    1989-02-01

    This report presents the preliminary environmental findings from the first phase of the Environmental Survey of the United States Department of Energy (DOE) Naval Petroleum and Oil Shale Reserves in Colorado, Utah, and Wyoming (NPOSR-CUW) conducted June 6 through 17, 1988. NPOSR consists of the Naval Petroleum Reserve No. 3 (NPR-3) in Wyoming, the Naval Oil Shale Reserves No. 1 and 3 (NOSR-1 and NOSR-3) in Colorado and the Naval Oil Shale Reserve No. 2 (NOSR-2) in Utah. NOSR-2 was not included in the Survey because it had not been actively exploited at the time of the on-site Survey. The Survey is being conducted by an interdisciplinary team of environmental specialists, lead and managed by the Office of Environment, Safety and Health's Office of Environmental Audit. Individual team specialists are outside experts being supplied by a private contractor. The objective of the Survey is to identify environmental problems and areas of environmental risk associated with NPOSR. The Survey covers all environmental media and all areas of environmental regulation. It is being performed in accordance with the DOE Environmental Survey Manual. This phase of the Survey involves the review of existing site environmental data, observations of the operations carried on at NPOSR and interviews with site personnel. The Survey team has developed a Sampling and Analysis Plan to assist in further assessing specific environmental problems identified at NOSR-3 during the on-site Survey. There were no findings associated with either NPR-3 or NOSR-1 that required Survey-related sampling and Analysis. The Sampling and Analysis Plan will be executed by Idaho National Engineering Laboratory. When completed, the results will be incorporated into the Environmental Survey Summary report. The Summary Report will reflect the final determinations of the NPOSR-CUW Survey and the other DOE site-specific Surveys. 110 refs., 38 figs., 24 tabs.

  8. Sampling designs for geochemical baseline studies in the Colorado oil shale region: a manual for practical application

    Energy Technology Data Exchange (ETDEWEB)

    Klusman, R. W.; Ringrose, C. D.; Candito, R. J.; Zuccaro, B.; Rutherford, D. W.; Dean, W. E.

    1980-06-01

    This manual presents a rationale for sampling designs, and results of geochemical baseline studies in the Colorado portion of the oil-shale region. The program consists of a systematic trace element study of soils, stream sediments, and plants carried out in a way to be conservative of human and financial resources and yield maximum information. Extension of this approach to other parameters, other locations, and to environmental baseline studies in general is a primary objective. A baseline for any geochemical parameter can be defined as the concentration of that parameter in a given medium such as soil, the range of its concentration, and the geographic scale of variability. In air quality studies, and to a lesser extent for plants, the temporal scale of variability must also be considered. In studies of soil, the temporal variablility does not become a factor until such time that a study is deemed necessary to evaluate whether or not there have been changes in baseline levels as a result of development. The manual is divided into five major parts. The first is a suggested sampling protocol which is presented in an outline form for guiding baseline studies in this area. The second section is background information on the physical features of the area of study, trace elements of significance occurring in oil shale, and the sample media used in these studies. The third section is concerned primarily with sampling design and its application to the geochemical studies of the oil shale region. The last sections, in the form of appendices, provide actual data and illustrate in a systematic manner, the calculations performed to obtain the various summary data. The last segment of the appendices is a more academic discussion of the geochemistry of trace elements and the parameters of importance influencing their behavior in natural systems.

  9. Shoreline oiling effects and recovery of salt marsh macroinvertebrates from the Deepwater Horizon Oil Spill.

    Science.gov (United States)

    Deis, Donald R; Fleeger, John W; Bourgoin, Stefan M; Mendelssohn, Irving A; Lin, Qianxin; Hou, Aixin

    2017-01-01

    Salt marshes in northern Barataria Bay, Louisiana, USA were oiled, sometimes heavily, in the aftermath of the Deepwater Horizon oil spill. Previous studies indicate that fiddler crabs (in the genus Uca) and the salt marsh periwinkle (Littoraria irrorata) were negatively impacted in the short term by the spill. Here, we detail longer-term effects and recovery from moderate and heavy oiling over a 3-year span, beginning 30 months after the spill. Although neither fiddler crab burrow density nor diameter differed between oiled and reference sites when combined across all sampling events, these traits differed among some individual sampling periods consistent with a pattern of lingering oiling impacts. Periwinkle density, however, increased in all oiling categories and shell-length groups during our sampling period, and periwinkle densities were consistently highest at moderately oiled sites where Spartina alterniflora aboveground biomass was highest. Periwinkle shell length linearly increased from a mean of 16.5 to 19.2 mm over the study period at reference sites. In contrast, shell lengths at moderately oiled and heavily oiled sites increased through month 48 after the spill, but then decreased. This decrease was associated with a decline in the relative abundance of large adults (shell length 21-26 mm) at oiled sites which was likely caused by chronic hydrocarbon toxicity or oil-induced effects on habitat quality or food resources. Overall, the recovery of S. alterniflora facilitated the recovery of fiddler crabs and periwinkles. However, our long-term record not only indicates that variation in periwinkle mean shell length and length-frequency distributions are sensitive indicators of the health and recovery of the marsh, but agrees with synoptic studies of vegetation and infaunal communities that full recovery of heavily oiled sites will take longer than 66 months.

  10. Shoreline oiling effects and recovery of salt marsh macroinvertebrates from the Deepwater Horizon Oil Spill

    Directory of Open Access Journals (Sweden)

    Donald R. Deis

    2017-08-01

    Full Text Available Salt marshes in northern Barataria Bay, Louisiana, USA were oiled, sometimes heavily, in the aftermath of the Deepwater Horizon oil spill. Previous studies indicate that fiddler crabs (in the genus Uca and the salt marsh periwinkle (Littoraria irrorata were negatively impacted in the short term by the spill. Here, we detail longer-term effects and recovery from moderate and heavy oiling over a 3-year span, beginning 30 months after the spill. Although neither fiddler crab burrow density nor diameter differed between oiled and reference sites when combined across all sampling events, these traits differed among some individual sampling periods consistent with a pattern of lingering oiling impacts. Periwinkle density, however, increased in all oiling categories and shell-length groups during our sampling period, and periwinkle densities were consistently highest at moderately oiled sites where Spartina alterniflora aboveground biomass was highest. Periwinkle shell length linearly increased from a mean of 16.5 to 19.2 mm over the study period at reference sites. In contrast, shell lengths at moderately oiled and heavily oiled sites increased through month 48 after the spill, but then decreased. This decrease was associated with a decline in the relative abundance of large adults (shell length 21–26 mm at oiled sites which was likely caused by chronic hydrocarbon toxicity or oil-induced effects on habitat quality or food resources. Overall, the recovery of S. alterniflora facilitated the recovery of fiddler crabs and periwinkles. However, our long-term record not only indicates that variation in periwinkle mean shell length and length-frequency distributions are sensitive indicators of the health and recovery of the marsh, but agrees with synoptic studies of vegetation and infaunal communities that full recovery of heavily oiled sites will take longer than 66 months.

  11. SURFACTANT BASED ENHANCED OIL RECOVERY AND FOAM MOBILITY CONTROL

    Energy Technology Data Exchange (ETDEWEB)

    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.

  12. Oil recovery with vinyl sulfonic acid-acrylamide copolymers

    Energy Technology Data Exchange (ETDEWEB)

    Norton, C.J.; Falk, D.O.

    1973-12-18

    An aqueous polymer flood containing sulfomethylated alkali metal vinyl sulfonate-acrylamide copolymers was proposed for use in secondary or tertiary enhanced oil recovery. The sulfonate groups on the copolymers sustain the viscosity of the flood in the presence of brine and lime. Injection of the copolymer solution into a waterflooded Berea core, produced 30.5 percent of the residual oil. It is preferred that the copolymers are partially hydrolyzed.

  13. Adsorption of uranium and thorium on new adsorbent prepared from Moroccan oil shale impregnated with phosphoric acid

    OpenAIRE

    El Hassane Khouya; Khadija Legrouri; Said Fakhi; Hassan Hannache

    2010-01-01

    Attention has been focused recently on the production of new adsorbents from Moroccan oil shale of Tarfaya (layer R3) by chemical activation with phosphoric acid and its application in wastewaters treatment. The optimal conditions for the preparation were searched and the tests of adsorption of uranium and thorium ions were affected. The best product was obtained by used of the ratio of activated agent/precursor equal 3 and activation of the mixture in air at 250°C during two hours after...

  14. Porphyrins from Messel oil shale (Eocene, Germany): Structure elucidation, geochemical and biological significance, and distribution as a function of depth

    Science.gov (United States)

    Ocampo, Rubén; Bauder, Claude; Callot, Henry J.; Albrecht, Pierre

    1992-02-01

    The extraction and isolation procedures of twenty nickel porphyrins (seven alkylporphyrins, thirteen carboxylic acids) from lacustrine Messel shale (Eocene, Germany), as well as the unequivocal structural assignments (obtained using 200 and 400 MHz nuclear magnetic resonance (NMR), nuclear Overhauser effect, mass spectrometry and total or partial synthesis of six reference compounds) are described. Ten porphyrins could be specifically correlated with biological precursors: algal chlorophyll c (4), bacteriochlorophylls d (3) and heme (3), while the remaining ones may arise from several chlorophylls. The structures of these fossil pigments mostly confirm the classical "Treibs scheme," including the origin of some porphyrins from nonchlorophyll sources. They also show that, even in a very immature sediment, deep modifications occur, including, in particular, extensive degradation of chlorophyll E ring. The composition of the porphyrin fractions of Messel oil shale was also studied as a function of depth. A porphyrin acids/alkylporphyrins ratio varying from 0.35 to 24.8 demonstrated that the apparent homogeneity of the shale is not reflected on the molecular scale. This was confirmed when the abundance of the twenty individual porphyrins of known structure was measured along the core. Significant correlations between individual porphyrins were found: fossils of bacteriochlorophylls d, homolog pairs of porphyrins (3-H/3-ethyl), etc.

  15. New technologies of enhanced oil recovery

    Directory of Open Access Journals (Sweden)

    Paweł Wojnarowski

    2006-10-01

    Full Text Available It is known from the literature that up to 27 % of oil in oilfields can be produced using primary and hydration methods. The efficiency of production can be increased by employing more advanced methods, i.e. EOR. The Polish Oil and Gas Company iwork with Polish oilfields, where currently primary methods are applied, but the Polish experiences with EOR date back to the years 1932-1987. In view of high oil prices, reconsidering EOR as a production method is economically justifiable. Therefore, it is purposeful to implement new pilot technologies, aimed at implementing new technologies, understanding accompanying phenomena, and calibrating of simulation models, including economical models for an optimal control of the oilfield exploitation. World’s new exploitation methods worked out in the last few years and suggestions for their implementation in Polish conditions are presented in the paper

  16. Pressurized fluidized-bed hydroretorting of eastern oil shales. Volume 2, Task 3, Testing of process improvement concepts: Final report, September 1987--May 1991

    Energy Technology Data Exchange (ETDEWEB)

    1992-03-01

    This final report, Volume 2, on ``Process Improvement Concepts`` presents the results of work conducted by the Institute of Gas Technology (IGT), the Illinois Institute of Technology (IIT), and the Ohio State University (OSU) to develop three novel approaches for desulfurization that have shown good potential with coal and could be cost-effective for oil shales. These are (1) In-Bed Sulfur Capture using different sorbents (IGT), (2) Electrostatic Desulfurization (IIT), and (3) Microbial Desulfurization and Denitrification (OSU and IGT). Results of work on electroseparation of shale oil and fines conducted by IIT is included in this report, as well as work conducted by IGT to evaluate the restricted pipe discharge system. The work was conducted as part of the overall program on ``Pressurized Fluidized-Bed Hydroretorting of Eastern Oil Shales.``

  17. Factors influencing successful implementation of enhanced oil recovery projects

    Directory of Open Access Journals (Sweden)

    Karović-Maričić Vesna

    2014-01-01

    Full Text Available Tertiary methods in oil production process called 'Enhanced Oil recovery methods' (EOR are mostly applied in mature oil fields with declining production trend after primary and secondary recovery methods or immediately after primary production phase. These 'Enhanced Oil Recovery' methods implies injection of gases or fluids to mobilize residual oil captured in reservoir rock due to presence of strong viscous and capillary forces and high value of interfacial tension between fluid and rock. Depending on the type of injected fluid, production mechanism, as well as an approach to implementation, EOR methods are divided into thermal methods, chemical methods, miscible/immiscible gas injection methods and other methods that so far have an experimental application. The paper analyzes the key factors influencing the successful implementation of EOR projects: phases of EOR project implementation, the price of crude oil at the world market as a criterion for the beginning and the justification for EOR process application and development of new technologies for more efficient process realization.

  18. Microbial communities in flowback water impoundments from hydraulic fracturing for recovery of shale gas.

    Science.gov (United States)

    Murali Mohan, Arvind; Hartsock, Angela; Hammack, Richard W; Vidic, Radisav D; Gregory, Kelvin B

    2013-12-01

    Hydraulic fracturing for natural gas extraction from shale produces waste brine known as flowback that is impounded at the surface prior to reuse and/or disposal. During impoundment, microbial activity can alter the fate of metals including radionuclides, give rise to odorous compounds, and result in biocorrosion that complicates water and waste management and increases production costs. Here, we describe the microbial ecology at multiple depths of three flowback impoundments from the Marcellus shale that were managed differently. 16S rRNA gene clone libraries revealed that bacterial communities in the untreated and biocide-amended impoundments were depth dependent, diverse, and most similar to species within the taxa γ-proteobacteria, α-proteobacteria, δ-proteobacteria, Clostridia, Synergistetes, Thermotogae, Spirochetes, and Bacteroidetes. The bacterial community in the pretreated and aerated impoundment was uniform with depth, less diverse, and most similar to known iodide-oxidizing bacteria in the α-proteobacteria. Archaea were identified only in the untreated and biocide-amended impoundments and were affiliated to the Methanomicrobia class. This is the first study of microbial communities in flowback water impoundments from hydraulic fracturing. The findings expand our knowledge of microbial diversity of an emergent and unexplored environment and may guide the management of flowback impoundments. © 2013 Federation of European Microbiological Societies. Published by John Wiley & Sons Ltd. All rights reserved.

  19. Analysis of non-methane hydrocarbon data from a monitoring station affected by oil and gas development in the Eagle Ford shale, Texas

    Directory of Open Access Journals (Sweden)

    Gunnar W. Schade

    2016-03-01

    Full Text Available Abstract Within the last decade, unconventional oil and gas exploration in the US has become a new source of atmospheric hydrocarbons. Although a geographically dispersed source, field measurements in and downwind of a number of shale basins demonstrate the impact exploration activities have on ambient levels of hydrocarbons. Due to concerns related to ozone production, regulatory agencies are adding monitoring stations to better understand the potential influence of emissions from areas with increased oil and gas related activities. The Eagle Ford shale in south Texas is a rapidly developing shale play producing both oil and natural gas, providing 10% and 5% of US domestic oil and gas production, respectively, in 2013. We analyzed the first year of measurements from a newly established monitoring site at its central north edge. The data reveal median ethane mixing ratios—used as a marker for oil and gas exploration related emissions—at five times its typical clean air background. Ethane mixing ratios above ten times the background occurred regularly. Saturated hydrocarbons with likely origin in oil and gas exploration explain half of the data set’s variability. They dominate OH radical reactivity at levels both similar to other shale areas and similar to Houston’s ship channel area a decade ago. Air advecting slowly across the shale area from east-southeast and southwest directions shows the most elevated hydrocarbon concentrations, and evidence is presented linking elevated alkene abundances to flaring in the shale area. A case study is presented linking high emissions from an upwind facility to hydrocarbon plumes observed at the monitor.

  20. The Devonian Marcellus Shale and Millboro Shale

    Science.gov (United States)

    Soeder, Daniel J.; Enomoto, Catherine B.; Chermak, John A.

    2014-01-01

    The recent development of unconventional oil and natural gas resources in the United States builds upon many decades of research, which included resource assessment and the development of well completion and extraction technology. The Eastern Gas Shales Project, funded by the U.S. Department of Energy in the 1980s, investigated the gas potential of organic-rich, Devonian black shales in the Appalachian, Michigan, and Illinois basins. One of these eastern shales is the Middle Devonian Marcellus Shale, which has been extensively developed for natural gas and natural gas liquids since 2007. The Marcellus is one of the basal units in a thick Devonian shale sedimentary sequence in the Appalachian basin. The Marcellus rests on the Onondaga Limestone throughout most of the basin, or on the time-equivalent Needmore Shale in the southeastern parts of the basin. Another basal unit, the Huntersville Chert, underlies the Marcellus in the southern part of the basin. The Devonian section is compressed to the south, and the Marcellus Shale, along with several overlying units, grades into the age-equivalent Millboro Shale in Virginia. The Marcellus-Millboro interval is far from a uniform slab of black rock. This field trip will examine a number of natural and engineered exposures in the vicinity of the West Virginia–Virginia state line, where participants will have the opportunity to view a variety of sedimentary facies within the shale itself, sedimentary structures, tectonic structures, fossils, overlying and underlying formations, volcaniclastic ash beds, and to view a basaltic intrusion.

  1. Recovery of light oil by air injection

    NARCIS (Netherlands)

    Khoshnevis Gargar, N.; Mailybaev, A.A.; Marchesin, D.; Bruining, J.

    2014-01-01

    In this paper we review the results of analytical, numerical and experimental studies related to air injection into porous medium containing initially light oil, water and gas at medium pressure conditions. The new combustion mechanism is described, where the process of the medium temperature

  2. CO2 flooding strategy to enhance heavy oil recovery

    Directory of Open Access Journals (Sweden)

    Tuo Huang

    2017-03-01

    For the numerical simulations study, the same oil relative permeability curve was applied to match the experimental results to all tests. Different gas relative permeability curves were obtained when the production pressure schemes are different. A much lower gas relative permeability curve and a higher critical gas saturation were achieved in the best pressure control scheme case compared to other cases. The lower gas relative permeability curve indicates that foamy oil was formed in the pressure depletion processes. Through this study, it is suggested that the pressure control scheme can be optimized in order to maximize the CO2 injection performance for enhanced heavy oil recovery.

  3. Recovery of mineral oil from waste emulsion using electrocoagulation method

    Directory of Open Access Journals (Sweden)

    Razali Mohd Najib

    2016-01-01

    Full Text Available This paper presents a research to recover mineral oil from industrial waste emulsion. This research also evaluates the standard of water produced after the oil recovery. The ecosystem could be polluted if this waste is not treated prior to discharge. The equipment needed for this experiment is power supply (generator, connecting wire and metal plate for providing the coagulant. The chosen plates were aluminium and iron plate. The power supply will be connected to the plate producing anode (positive terminal and cathode (negative terminal. Both plates are immersed into a beaker containing waste emulsion. The charge supplied by the current will cause the aluminium or ferum to dissisipate and became ions. These ions will attract the oil to flock together and float at the surface. The water will then filter by using filter paper. Electrocoagulation was done without addition of chemical thus can prevent the hazard from the chemicals. The samples was sent for oil and grease test. The optimum time needed for recovery of oil was 3 hours. The percentage recovery reach constant trend of 95% afterwards. When the power consumption increases, the percentage recovery also increases. However, the current should be lower than 0.5 ampere as it is the limit that human body can withstand. Thus, power consumption of 27.5 Watt was chosen as optimum value. The oil recovery of at power consumption at 27.5W is 96%. The best plate in the process was the aluminium pair which can recover more than ferum plate. The present work concludes the promising future for waste water treatment by usage of electrocoagulation technique.

  4. Surfactant Based Enhanced Oil Recovery and Foam Mobility Control

    Energy Technology Data Exchange (ETDEWEB)

    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.

  5. ECOLOGY SAFETY TECHNOLOGIES OF UNCONVENTIONAL OIL RESERVES RECOVERY FOR SUSTAINABLE OIL AND GAS INDUSTRY DEVELOPMENT

    Directory of Open Access Journals (Sweden)

    Viacheslav Zyrin

    2016-09-01

    Full Text Available The problem of effective technology for heavy oil recovery nowadays has a great importance, because of worsening geological conditions of the developed deposits, decreasing recovery factor, increasing the part of heavy oil. For the future sustainable development of oil producing industry the involved technologies must require energy effectiveness and ecological safety. The paper proves the enhanced oil recovery methods necessity for heavy oil deposits, highlighted thermal technologies as the most effective. But traditional thermal treatment technologies is a source of air pollutant emission, such as CO, NO etc. The calculation of emissions for traditional steam generator is provided. Besides, the paper shows the effectiveness of electrical enhanced oil recovery methods. The advantages of associated gas as a fuel for cogeneration plants is shown. The main approaches to implementation of carbon dioxide sequestration technologies in the oil and gas industry of Russia are defined. Conceptual view of СО2-EOR technologies potential within the context of sustainable development of oil and gas industry are presented. On the basis of the conducted research a number of scientific research and practical areas of the CCS technology development are revealed.

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

    Energy Technology Data Exchange (ETDEWEB)

    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

  7. Physicochemical Characterization of Oil Palm Decanter Cake (OPDC) for Residual Oil Recovery

    OpenAIRE

    Naimah Sahad; Ayub Md Som; Azhari Samsu Baharuddin; Noriznan Mokhtar; Zainuri Busu; Alawi Sulaiman

    2014-01-01

    A characterization study on oil palm decanter cakes (OPDC) was performed to gain an in-depth understanding of the material’s characteristics to aid in potential residual oil recovery. The OPDC was characterized by a high moisture content, high biodegradability, high organic content, and a nutrient-rich composition. Microscopic observation showed that the oil attachments in OPDC, and a vast majority of the droplets, were less than 50 μm in size. Furthermore, contact angle measurement revealed ...

  8. Coupled Mineral Dissolution and Precipitation Reactions in Shale-Hydraulic Fracturing Fluid Systems

    Science.gov (United States)

    Joe-Wong, C. M.; Harrison, A. L.; Thomas, D.; Dustin, M. K.; Jew, A. D.; Brown, G. E.; Maher, K.; Bargar, J.

    2015-12-01

    Hydraulic fracturing of low-permeability, hydrocarbon-rich shales has recently become an important energy source in the United States. However, hydrocarbon recovery rates are low and drop rapidly after a few months. Hydraulic fracture fluids, which contain dissolved oxygen and numerous organic additives, induce dissolution and precipitation reactions that change the porosity and permeability of the shale. To investigate these reactions, we studied the interactions of four shales (Eagle Ford, Barnett, Marcellus, and Green River) with a simulated hydraulic fracture fluid in batch reactors at 80 °C. The shales were chosen for both economic viability and chemical variety, allowing us to explore the reactivities of different components. The Eagle Ford shale is carbonate rich, and the Green River shale contains significant siderite and kerogen. The Barnett shale also has a high organic content, while the Marcellus shale has the highest fractions of clay and pyrite. Our experiments show that hydrochloric acid in the fluid promotes carbonate mineral dissolution, rapidly raising the pH from acidic to circumneutral levels for the Eagle Ford and Green River shales. Dissolution textures in the Green River shale and large cavities in the Barnett shale indicate significant mineralogical and physical changes in the reacted rock. Morphological changes are not readily apparent in the Eagle Ford and Marcellus shales. For all shales, ongoing changes to the solution Al: Si ratio suggest incongruent aluminosilicate dissolution. Siderite or pyrite dissolution occurs within days and is followed by the formation of secondary Fe precipitates in suspension and coating the walls of the reactor. However, little evidence of any coatings on shale surfaces was found. The net effect of these reactions on porosity and permeability and their influence on the long-term efficacy of oil and gas recovery after hydraulic fracturing are critical to the energy landscape of the United States.

  9. Microbial Enhanced Oil Recovery - Advanced Reservoir Simulation

    DEFF Research Database (Denmark)

    Nielsen, Sidsel Marie

    . Another effect is attachment of the bacteria to the pore walls and formation of biofilm. It leads to reduction of porosity and, under some assumptions, to increase the fraction of oil in the flow. Surfactant is our key component in order to reduce IFT. The surfactant concentration in the water phase must...... is coupled to modification of permeability. This promotes the fluid diversion mechanism. A contribution to fluid diversion mechanism is microscopic fluid diversion, which is possible to investigate in a one-dimensional system. The relative permeability for water is modified according to our modified version...... of the Kozeny-Carman equation. Bacteria only influence the water and biofilm phases directly, so the oil phase remains the same. We have assessed the effect from biofilm formation together with microscopic fluid diversion. When sufficient amount of surfactant is produced in the water phase, the effect from...

  10. Development of Bottom Oil Recovery Systems. Revised

    Science.gov (United States)

    2014-02-01

    important to have a backup unit with the same capabilities. • The heading sensor is essential for effective ROV operation. • The tending vessel can...debris/bottom type/weather effects 5. Logistics a. Equipment requirements b. Equipment availability c. Backup equipment/spares availability d...Southeast Florida Mystery Spill SE Florida HFO X 2001 T/V Baltic Carrier Baltic Sea, Denmark Intermediate fuel oil (IFO) 380 X 2002 T/V Prestige

  11. Heavy Oil Recovery Ohmsett Test Report

    Science.gov (United States)

    2012-06-01

    Denmark , with offices in Goletta, CA.  Fluorescence polarization (FP) from EIC Laboratories of Norwood, MA. For this effort, RESON refined its...validating research findings. Public and private sector entities are invited to contract the use of Ohmsett as a research center to test oil spill... Backup equipment/spares availability d. Time to get equipment on site e. Transit time – personnel and equipment f. Availability of skilled/trained

  12. Maximal oil recovery by simultaneous condensation of alkane and steam

    NARCIS (Netherlands)

    Bruining, J.; Marchesin, D.

    2007-01-01

    This paper deals with the application of steam to enhance the recovery from petroleum reservoirs. We formulate a mathematical and numerical model that simulates coinjection of volatile oil with steam into a porous rock in a one-dimensional setting. We utilize the mathematical theory of conservation

  13. Foam for Enhanced Oil Recovery : Modeling and Analytical Solutions

    NARCIS (Netherlands)

    Ashoori, E.

    2012-01-01

    Foam increases sweep in miscible- and immiscible-gas enhanced oil recovery by decreasing the mobility of gas enormously. This thesis is concerned with the simulations and analytical solutions for foam flow for the purpose of modeling foam EOR in a reservoir. For the ultimate goal of upscaling our

  14. Comblike Polyacrylamides as Flooding Agent in Enhanced Oil Recovery

    NARCIS (Netherlands)

    Wever, Diego A. Z.; Picchioni, Francesco; Broekhuis, Antonius A.

    2013-01-01

    The oil recovery from core material and a specifically designed flow cell using novel branched (comblike) polyacrylamides (PAM) has been investigated. The injectivity characteristics of the different branched PAMs were evaluated by filtration tests and core-flow experiments. The number of arms of

  15. Increased Oil Recovery Prize for work on Troll; Fikk pris for Troll-arbeid

    Energy Technology Data Exchange (ETDEWEB)

    Steensen, Anders J.

    2007-07-01

    Halliburton and Baker Hughes have developed tools that ensures increased oil recovery from the Troll platform. For this work, the companies were awarded the Increased Oil Recovery (IOR) Prize. Details on the technical principles are provided (ml)

  16. BX in-situ oil-shale project. Quarterly technical progress report, June 1, 1981-August 31, 1981

    Energy Technology Data Exchange (ETDEWEB)

    Dougan, P.M.

    1981-09-20

    June 1, 1981-August 31, 1981 was the third consecutive quarter of superheated steam injection at the BX In Situ Oil Shale Project. Injection was continuous except for the period of July 14th to August 1st when the injection was suspended during the drilling of core hole BX-37. During the quarter, 99,760 barrels of water as superheated steam were injected into Project injection wells at an average well head temperature of 752/sup 0/F and an average wellhead pressure of 1312 PSIG. During the same period, 135,469 barrels of fluid were produced from the Project production wells for a produced to injected fluid ratio of 1.36 to 1.0. Net oil production during the quarter was 38 barrels.

  17. DETERMINATION OF OPTIMAL CONTOURS OF OPEN PIT MINE DURING OIL SHALE EXPLOITATION, BY MINEX 5.2.3. PROGRAM

    Directory of Open Access Journals (Sweden)

    Miroslav Ignjatović

    2013-04-01

    Full Text Available By examination and determination of optimal solution of technological processes of exploitation and oil shale processing from Aleksinac site and with adopted technical solution and exploitation of oil shale, derived a technical solution that optimize contour of the newly defined open pit mine. In the world, this problem is solved by using a computer program that has become the established standard for quick and efficient solution for this problem. One of the computer’s program, which can be used for determination of the optimal contours of open pit mines is Minex 5.2.3. program, produced in Australia in the Surpac Minex Group Pty Ltd Company, which is applied at the Mining and Metallurgy Institute Bor (no. of licenses are SSI - 24765 and SSI - 24766. In this study, authors performed 11 optimization of deposit geo - models in Minex 5.2.3. based on the tests results, performed in a laboratory for soil mechanics of Mining and Metallurgy Institute, Bor, on samples from the site of Aleksinac deposits.

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  19. Comparing Laser Desorption Ionization and Atmospheric Pressure Photoionization Coupled to Fourier Transform Ion Cyclotron Resonance Mass Spectrometry To Characterize Shale Oils at the Molecular Level

    Science.gov (United States)

    Cho, Yunjo; Jin, Jang Mi; Witt, Matthias; Birdwell, Justin E.; Na, Jeong-Geol; Roh, Nam-Sun; Kim, Sunghwan

    2013-01-01

    Laser desorption ionization (LDI) coupled to Fourier transform ion cyclotron resonance mass spectrometry (FT-ICR MS) was used to analyze shale oils. Previous work showed that LDI is a sensitive ionization technique for assessing aromatic nitrogen compounds, and oils generated from Green River Formation oil shales are well-documented as being rich in nitrogen. The data presented here demonstrate that LDI is effective in ionizing high-double-bond-equivalent (DBE) compounds and, therefore, is a suitable method for characterizing compounds with condensed structures. Additionally, LDI generates radical cations and protonated ions concurrently, the distribution of which depends upon the molecular structures and elemental compositions, and the basicity of compounds is closely related to the generation of protonated ions. This study demonstrates that LDI FT-ICR MS is an effective ionization technique for use in the study of shale oils at the molecular level. To the best of our knowledge, this is the first time that LDI FT-ICR MS has been applied to shale oils.

  20. Role of water in hydrocarbon generation from Type-I kerogen in Mahogany oil shale of the Green River Formation

    Science.gov (United States)

    Lewan, M.D.; Roy, S.

    2011-01-01

    Hydrous and anhydrous closed-system pyrolysis experiments were conducted on a sample of Mahogany oil shale (Eocene Green River Formation) containing Type-I kerogen to determine whether the role of water had the same effect on petroleum generation as reported for Type-II kerogen in the Woodford Shale. The experiments were conducted at 330 and 350??C for 72h to determine the effects of water during kerogen decomposition to polar-rich bitumen and subsequent bitumen decomposition to hydrocarbon-rich oil. The results showed that the role of water was more significant in bitumen decomposition to oil at 350??C than in kerogen decomposition to bitumen at 330??C. At 350??C, the hydrous experiment generated 29% more total hydrocarbon product and 33% more C15+ hydrocarbons than the anhydrous experiment. This is attributed to water dissolved in the bitumen serving as a source of hydrogen to enhance thermal cracking and facilitate the expulsion of immiscible oil. In the absence of water, cross linking is enhanced in the confines of the rock, resulting in formation of pyrobitumen and molecular hydrogen. These differences are also reflected in the color and texture of the recovered rock. Despite confining liquid-water pressure being 7-9 times greater in the hydrous experiments than the confining vapor pressure in the anhydrous experiments, recovered rock from the former had a lighter color and expansion fractures parallel to the bedding fabric of the rock. The absence of these open tensile fractures in the recovered rock from the anhydrous experiments indicates that water promotes net-volume increase reactions like thermal cracking over net-volume decrease reactions like cross linking, which results in pyrobitumen. The results indicate the role of water in hydrocarbon and petroleum formation from Type-I kerogen is significant, as reported for Type-II kerogen. ?? 2010.

  1. Carbon dioxide enhanced oil recovery performance according to the literature

    Science.gov (United States)

    Olea, Ricardo A.

    2017-07-17

    IntroductionThe need to increase the efficiency of oil recovery and environmental concerns are bringing to prominence the use of carbon dioxide (CO2) as a tertiary recovery agent. Assessment of the impact of flooding with CO2 all eligible reservoirs in the United States not yet undergoing enhanced oil recovery (EOR) requires making the best possible use of the experience gained in 40 years of applications. Review of the publicly available literature has located relevant CO2-EOR information for 53 units (fields, reservoirs, pilot areas) in the United States and 17 abroad.As the world simultaneously faces an increasing concentration of CO2 in the atmosphere and a higher demand for fossil fuels, the CO2-EOR process continues to gain popularity for its efficiency as a tertiary recovery agent and for the potential for having some CO2 trapped in the subsurface as an unintended consequence of the enhanced production (Advanced Resources International and Melzer Consulting, 2009). More extensive application of CO2-EOR worldwide, however, is not making it significantly easier to predict the exact outcome of the CO2 flooding in new reservoirs. The standard approach to examine and manage risks is to analyze the intended target by conducting laboratory work, running simulation models, and, finally, gaining field experience with a pilot test. This approach, though, is not always possible. For example, assessment of the potential of CO2-EOR at the national level in a vast country such as the United States requires making forecasts based on information already available.Although many studies are proprietary, the published literature has provided reviews of CO2-EOR projects. Yet, there is always interest in updating reports and analyzing the information under new perspectives. Brock and Bryan (1989) described results obtained during the earlier days of CO2-EOR from 1972 to 1987. Most of the recovery predictions, however, were based on intended injections of 30 percent the size of

  2. Research efforts for detection and recovery of submerged oil

    Energy Technology Data Exchange (ETDEWEB)

    Hansen, K. [United States Coast Guard, Groton, CT (United States). Research and Development Center

    2009-07-01

    Submerged oil can sink and destroy shellfish and other marine populations in addition to causing closure of water intakes at industrial facilities and power plants. However, current methods to find and recover oil from spills involving submerged oil are inadequate. The underwater environment presents major challenges such as poor visibility, difficulty in tracking oil spill movement, colder temperatures, inadequate containment methods and problems with the equipment's interaction with water. This paper reported on a multi-year project launched by the Research and Development Center of the United States Coast Guard to develop a complete approach for spills of submerged oil. The project involved detection technologies and recovery methods for oil on the bottom of any body of water. Proof of concept (POC) and prototype tests of potential detection technologies were evaluated during tests at the Ohmsett facility in Leonardo, New Jersey. The technologies included sonar, laser fluorometry, real-time mass spectrometry and in-situ fluorometry. This paper described the development of a complete specification for an integrated recovery system along with a plan for future development. 9 refs., 2 tabs., 11 figs.

  3. Preliminary study of the oil shales of the Green River formation in the tri-state area of Colorado, Utah, and Wyoming to investigate their utility for disposal of radioactive waste

    Energy Technology Data Exchange (ETDEWEB)

    1975-05-01

    Results are presented of a preliminary study of the oil shales of the Green River formation in the tri-state area of Colorado, Utah, and Wyoming to investigate their utility for possible disposal of radioactive waste material. The objective of this study was to make a preliminary investigation and to obtain a broad overview of the physical and economic factors which would have an effect on the suitability of the oil shale formations for possible disposal of radioactive waste material. These physical and economic factors are discussed in sections on magnitude of the oil shales, waste disposal relations with oil mining, cavities requirements, hydrological aspects, and study requirements. (JRD)

  4. Pressurized fluidized-bed hydroretorting of Eastern oil shales -- Sulfur control. Topical report for Subtask 3.1, In-bed sulfur capture tests; Subtask 3.2, Electrostatic desulfurization; Subtask 3.3, Microbial desulfurization and denitrification

    Energy Technology Data Exchange (ETDEWEB)

    Roberts, M.J.; Abbasian, J.; Akin, C.; Lau, F.S.; Maka, A.; Mensinger, M.C.; Punwani, D.V.; Rue, D.M. [Institute of Gas Technology, Chicago, IL (United States); Gidaspow, D.; Gupta, R.; Wasan, D.T. [Illinois Inst. of Tech., Chicago, IL (United States); Pfister, R.M.: Krieger, E.J. [Ohio State Univ., Columbus, OH (United States)

    1992-05-01

    This topical report on ``Sulfur Control`` presents the results of work conducted by the Institute of Gas Technology (IGT), the Illinois Institute of Technology (IIT), and the Ohio State University (OSU) to develop three novel approaches for desulfurization that have shown good potential with coal and could be cost-effective for oil shales. These are (1) In-Bed Sulfur Capture using different sorbents (IGT), (2) Electrostatic Desulfurization (IIT), and (3) Microbial Desulfurization and Denitrification (OSU and IGT). The objective of the task on In-Bed Sulfur Capture was to determine the effectiveness of different sorbents (that is, limestone, calcined limestone, dolomite, and siderite) for capturing sulfur (as H{sub 2}S) in the reactor during hydroretorting. The objective of the task on Electrostatic Desulfurization was to determine the operating conditions necessary to achieve a high degree of sulfur removal and kerogen recovery in IIT`s electrostatic separator. The objectives of the task on Microbial Desulfurization and Denitrification were to (1) isolate microbial cultures and evaluate their ability to desulfurize and denitrify shale, (2) conduct laboratory-scale batch and continuous tests to improve and enhance microbial removal of these components, and (3) determine the effects of processing parameters, such as shale slurry concentration, solids settling characteristics, agitation rate, and pH on the process.

  5. Microfluidic Investigation of Oil Mobilization in Shale Fracture Networks at Reservoir Conditions

    Science.gov (United States)

    Porter, M. L.; Jimenez-Martinez, J.; Carey, J. W.; Viswanathan, H. S.

    2015-12-01

    Investigations of pore-scale fluid flow and transport phenomena using engineered micromodels has steadily increased in recent years. In these investigations fluid flow is restricted to two-dimensions allowing for real time visualization and quantification of complex flow and reactive transport behavior, which is difficult to obtain in other experimental systems. One drawback to these studies is the use of engineered materials that do not faithfully represent the rock properties (e.g., porosity, wettability, roughness, etc.) encountered in subsurface formations. In this work, we describe a unique high pressure (up to 1500 psi) and temperature (up to 80 °C) microfluidics experimental system in which we investigate fluid flow and transport in geo-material (e.g., shale, Portland cement, etc.) micromodels. The use of geo-material micromodels allows us to better represent fluid-rock interactions including wettability, chemical reactivity, and nano-scale porosity at conditions representative of natural subsurface environments. Here, we present experimental results in fracture systems with applications to hydrocarbon mobility in hydraulically fractured shale. Complex fracture network patterns are derived from 3D x-ray tomography images of actual fractures created in shale rock cores. We use both shale and glass micromodels, allowing for a detailed comparison between flow phenomena in the different materials. We discuss results from two-phase huff-and-puff experiments involving N2 and n-Decane, as well as three-phase displacement experiments involving supercritical CO2, brine, and n-Decane.

  6. Engineering waterfloods for improved oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Craig, F.F. Jr.

    1973-12-01

    The basis for an engineering design of a waterflood is a prediction of expected performance. The basic data required are (1) rock properties; (2) reservoir fluid characteristics; (3) overall reservoir description; and (4) a measure of the reservoir heterogeneity. These factors, together with judgment of possible flooding patterns, yield the calculated performance when used with a prediction technique. Two basic types of rock properties are (1) those influenced by the rock skeleton along; and (2) those influenced jointly by the rock and reservoir fluids. Reservoir fluid characteristics required for a prediction of reservoir performance consist primarily of oil and water viscosities at reservoir temperature and pressure. The mobility ratio is the single most important characteristic of a waterflood--a combination of rock and fluid properties.

  7. A Theoretical Investigation of the Structure and Reactivity of the Molecular Constituents of Oil Sand and Oil Shale

    Energy Technology Data Exchange (ETDEWEB)

    Parish, Carol A. [Univ. of Richmond, VA (United States)

    2016-11-28

    We used a variety of small organic models of asphaltenes to investigate the molecular mechanism for the high temperature decomposition that would take place as part of the oil refinery process. We determined that the decomposition is initiated via four different types of hydrogen migration reactions. According to the energetics of the reactions, the dominant 1,2-H shift mechanism involves two competitive product channels, namely, C2H2 + CH2CS and CS + CH3CCH. The minor channels include the formation of CS + CH2CCH2, H2S + C4H2, HCS + CH2CCH, CS + CH2CHCH, H + C4H3S, and HS + C4H3. We also investigated the alkyl substitution effect by exploring the decomposition pathways of models with alkyl arms. The energetics of such systems were very similar to that for unsubstituted model compounds, which suggests that asphaltene alkylation may not play a significant role in the decomposition of asphaltene compounds. This work was published in the Journal of Physical Chemistry A 2011, 115, 2882-2891. A MECHANISTIC STUDY OF THE 2-THIENYLMETHYL + HO2 RADICAL RECOMBINATION REACTION Radicals are molecules which contain single electrons. They are very reactive. Radical recombination reactions are important in the combustion of fuel oils. Shale oil contains radicals. We used quantum mechanics to explore the reactivity of shale oil model radical compounds. Seventeen product channels corresponding to either addition/elimination or direct hydrogen abstraction were characterized. Direct hydrogen abstraction proceeds via a weakly bonded complex, which leads to 2-methylthiophene, 2-methylene-2,3-dihydrothiophene or 2-methylene-2,5-dihydrothiophene depending upon the 2-thienylmethyl radical reaction site. The addition pathway for the two radical reactants is barrierless with the formation of three adducts, as distinguished by HO

  8. Effect of Temperature, Wettability and Relative Permeability on Oil Recovery from Oil-wet Chalk

    Directory of Open Access Journals (Sweden)

    Omid Karoussi

    2008-07-01

    Full Text Available It is customary, for convenience, to use relative permeability data produced at room temperature. This paper shows that this practice underestimates oil recovery rates and ultimate recovery from chalk rocks for high temperature reservoirs. Above a certain temperature (80°C in this work a reduction of oil recovery was observed. The reduction in oil recovery is reflected by the shift of relative permeability data towards more oil-wet at high temperature (tested here 130°C. However, both IFT and contact angle measurements indicate an increase in water wetness as temperature increases, which contradict the results obtained by relative permeability experiments. This phenomenon may be explained based on the total interaction potential, which basically consists of van der Waals attractive and short-range Born repulsive and double layer electrostatic forces. The fluid/rock interactions is shown to be dominated by the repulsive forces above 80°C, hence increase fine detachment enhancing oil trapping. In other words the indicated oil wetness by relative permeability is misleading.

  9. Landscape disturbance from unconventional and conventional oil and gas development in the Marcellus Shale region of Pennsylvania, USA

    Science.gov (United States)

    Slonecker, Terry E.; Milheim, Lesley E.

    2015-01-01

    The spatial footprint of unconventional (hydraulic fracturing) and conventional oil and gas development in the Marcellus Shale region of the State of Pennsylvania was digitized from high-resolution, ortho-rectified, digital aerial photography, from 2004 to 2010. We used these data to measure the spatial extent of oil and gas development and to assess the exposure of the extant natural resources across the landscape of the watersheds in the study area. We found that either form of development: (1) occurred in ~50% of the 930 watersheds that defined the study area; (2) was closer to streams than the recommended safe distance in ~50% of the watersheds; (3) was in some places closer to impaired streams and state-defined wildland trout streams than the recommended safe distance; (4) was within 10 upstream kilometers of surface drinking water intakes in ~45% of the watersheds that had surface drinking water intakes; (5) occurred in ~10% of state-defined exceptional value watersheds; (6) occurred in ~30% of the watersheds with resident populations defined as disproportionately exposed to pollutants; (7) tended to occur at interior forest locations; and (8) had >100 residents within 3 km for ~30% of the unconventional oil and gas development sites. Further, we found that exposure to the potential effects of landscape disturbance attributable to conventional oil and gas development was more prevalent than its unconventional counterpart.

  10. Landscape Disturbance from Unconventional and Conventional Oil and Gas Development in the Marcellus Shale Region of Pennsylvania, USA

    Directory of Open Access Journals (Sweden)

    E. Terrence Slonecker

    2015-06-01

    Full Text Available The spatial footprint of unconventional (hydraulic fracturing and conventional oil and gas development in the Marcellus Shale region of the State of Pennsylvania was digitized from high-resolution, ortho-rectified, digital aerial photography, from 2004 to 2010. We used these data to measure the spatial extent of oil and gas development and to assess the exposure of the extant natural resources across the landscape of the watersheds in the study area. We found that either form of development: (1 occurred in ~50% of the 930 watersheds that defined the study area; (2 was closer to streams than the recommended safe distance in ~50% of the watersheds; (3 was in some places closer to impaired streams and state-defined wildland trout streams than the recommended safe distance; (4 was within 10 upstream kilometers of surface drinking water intakes in ~45% of the watersheds that had surface drinking water intakes; (5 occurred in ~10% of state-defined exceptional value watersheds; (6 occurred in ~30% of the watersheds with resident populations defined as disproportionately exposed to pollutants; (7 tended to occur at interior forest locations; and (8 had >100 residents within 3 km for ~30% of the unconventional oil and gas development sites. Further, we found that exposure to the potential effects of landscape disturbance attributable to conventional oil and gas development was more prevalent than its unconventional counterpart.

  11. Discrete model for the recovery of oil from a reservoir

    Energy Technology Data Exchange (ETDEWEB)

    Vargas-Jarillo, C.

    1983-10-01

    This work simulates oil recovery by means of a molecular-type approach. The solid and liquid materials are composed of a finite number of particles, which are approximants for molecules. Porous flow is studied qualitatively under the assumption that particles of rock, oil, and the flooding flow interact with each other locally by means of a compensating Lennard-Jones potential and also are under the influence of gravity. Extensive computations are described and discussed in which initial data and parameters are varied. A comparison is made with actual physical experiments. 37 references.

  12. Enhanced oil recovery by nanoparticles injection: Modeling and simulation

    KAUST Repository

    El-Amin, Mohamed

    2013-01-01

    In the present paper, a mathematical model and numerical simulation to describe the nanoparticles-water suspension imbibes into a water-oil two-phase flow in a porous medium is introduced. We extend the model to include the negative capillary pressure and mixed relative permeabilities correlations to fit with the mixed-wet system. Also, buoyancy and capillary forces as well as Brownian diffusion are considered. Throughout this investigation, we monitor the changing of the fluids and solid properties due to addition of the nanoparticles and check for possible enhancement of the oil recovery process using numerical experiments.

  13. The role of radiogenic heat in maturation of organic matter within oil shales of Duwi formation in Quseir-Safaga District, Red Sea coastal area, Egypt

    OpenAIRE

    El Kassas, I. A. [ابراهيم علي القصاص; Khaled, K. A.

    1997-01-01

    The oil shale beds of Duwi Formation at Quseir-Safaga district in Egypt show a high content of organic matter (kerogen) and a fair pyrolysis oil yield. Kerogens of these rocks are composed mainly of marine amorphous and structured sapropelic liptinitic phytoclasts of algae with minor contribution of the humic materials. Also , these kerogens belong to the immature types I and II which are buried in the diagenesis stage of maturation. Although these kerogens are immature they show high vitrini...

  14. Influence of Oil Viscosity on Alkaline Flooding for Enhanced Heavy Oil Recovery

    Directory of Open Access Journals (Sweden)

    Yong Du

    2013-01-01

    Full Text Available Oil viscosity was studied as an important factor for alkaline flooding based on the mechanism of “water drops” flow. Alkaline flooding for two oil samples with different viscosities but similar acid numbers was compared. Besides, series flooding tests for the same oil sample were conducted at different temperatures and permeabilities. The results of flooding tests indicated that a high tertiary oil recovery could be achieved only in the low-permeability (approximately 500 mD sandpacks for the low-viscosity heavy oil (Zhuangxi, 390 mPa·s; however, the high-viscosity heavy oil (Chenzhuang, 3450 mPa·s performed well in both the low- and medium-permeability (approximately 1000 mD sandpacks. In addition, the results of flooding tests for the same oil at different temperatures also indicated that the oil viscosity put a similar effect on alkaline flooding. Therefore, oil with a high-viscosity is favorable for alkaline flooding. The microscopic flooding test indicated that the water drops produced during alkaline flooding for oils with different viscosities differed significantly in their sizes, which might influence the flow behaviors and therefore the sweep efficiencies of alkaline fluids. This study provides an evidence for the feasibility of the development of high-viscosity heavy oil using alkaline flooding.

  15. Changes in baseflow patterns in water-limited shale oil and gas regions: the Eagle Ford play

    Science.gov (United States)

    Arciniega, S.; Brena-Naranjo, J. A.; Hernández-Espriú, A.; Pedrozo-Acuña, A.

    2016-12-01

    Quantifying and analyzing the contribution of groundwater from shallow aquifers to rivers as baseflow is very important for water supply and riverine ecosystem health, especially in water-limited catchments. Baseflow depends on the water available (precipitation), vegetation (land use, water use), aquifer properties and water-table depth. In this context, human activities such as groundwater abstraction for multiple purposes can alter the relationship between aquifer storage and baseflow. In this study, we analyzed observed changes in baseflow patterns of 40 catchments located across the Eagle Ford shale gas/oil play (Texas) during the period 1986-2015. The Eagle Ford sedimentary formation is actually the largest shale oil producing region in the US with large production in shale gas. Intensive unconventional resources extraction in the Eagle Ford play started in 2009 and gas/oil production increased faster than in other plays, accompanied by a rise in groundwater consumption for HF purposes. Spatial and temporal impacts on baseflow at the Eagle Ford play derived from HF were assessed by means of different patterns such as baseflow hydrograph separation, flow-duration curves, empirical storage-discharge relationships and streamflow recession curve analysis. A comparison during different periods of water use for HF activities was performed: pre-development period (1986-2000); moderate period (2001-2008); and intensive period (2009-2015). The pre-development period was considered as a baseline and catchments located inside and outside the play area were separately analyzed. The results show negative changes on baseflow patterns during the intensive HF period that were not observed during the moderate period, especially in catchments located inside the play. These changes were also characterized by a decline on mean annual baseflow volume and shorter hydrograph recession times, that led to a shift in the streamflow regime in some catchments from perennial to

  16. Development of an Eastern Shale Oil Residue as an Asphalt Additive - Subtask 2.5: Topical report, February 1, 1994-February 1, 1995

    Energy Technology Data Exchange (ETDEWEB)

    NONE

    1997-12-31

    An evaluation of eastern shale oil as an asphalt additive to reduce oxidative age hardening and moisture susceptibility is being conducted. An eastern shale oil residue having a viscosity of 1.30 Pa`s at 60{degrees}C (140{degrees}F) was blended with three different petroleum-derived asphalts that are known to be very susceptible to oxidative aging. In addition, blends of the eastern shale oil residue and the petroleum-derived asphalts are being coated onto three different aggregates that are known to be susceptible to water stripping. The oxidative age hardening portion of this study is not complete at this time. To date, information has been obtained on the unaged samples and two of the aged petroleum-derived asphalts (AAD-1 and AAK-1). When complete, this data will include rheological data on the unaged, RTFO-aged, and the RTFO/PAV-aged samples and infrared data on the unaged and RTFO/PAV-aged samples. With respect to the rheological data, asphalt AAD-1 meets the specifications of a PG 58 asphalt while asphalt AAK-1 does not. In the latter case this indicates that AAK-1 is more appropriately evaluated at a higher temperature range. The infrared spectroscopic data obtained for the eastern shale oil residue show that it contains appreciable amounts of carbonyl and sulfoxide compound types, 0.22 absorbance units and 0. 27 moles/L, respectively. Thus, upon the addition of this residue to the three petroleum-derived asphalts the blends contain increased amounts of these functional groups relative to the petroleum-derived asphalts. This has been observed with other additives and is not considered detrimental. In addition, the data that has been collected to date indicate that the moisture susceptibility of blends of eastern shale oil residue and asphalt AAK-1 are somewhat improved when coated onto Lithonia granite.

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

    Energy Technology Data Exchange (ETDEWEB)

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

    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.

  18. Metallic nanoparticles for enhanced heavy oil recovery: promises and challenges

    OpenAIRE

    Guo, Kun; Li, Hailong; Yu, Zhixin

    2015-01-01

    With the increasing global energy demand, great attention has been focused on utilizing heavy oil and bitumen, which are potentially located ultra-deep underground and cannot be easily recovered. Numerous recovery approaches have been proposed for successful extraction of heavy hydrocarbons from ultra-deep reservoirs. However, these approached are often accompanied by high energy consumption, large amounts of wastewater generation, and undesirable environmental damage. Nanotechnology has ...

  19. Supporting technology for enhanced oil recovery - EOR thermal processes

    Energy Technology Data Exchange (ETDEWEB)

    NONE

    1995-03-01

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

  20. Rock Springs Site 12 hydraulic/explosive true in situ oil shale fracturing experiment

    Energy Technology Data Exchange (ETDEWEB)

    Parrish, R.L.; Boade, R.R.; Stevens, A.L.; Long, A. Jr.; Turner, T.F.

    1980-06-01

    The experiment plan involved the creation and characterization of three horizontal hydraulic fractures, followed by the insertion and simultaneous detonation of slurry explosive in the two lower fractures. Core analyses, wellbore logging, and airflow and /sup 85/Kr tracer tests were used for site characterization and assessment of the hydraulic and explosive fracturing. Tiltmeters, wellhead pressure and flow gages, and in-formation pressure, flow and crack-opening sensors were used to monitor hydrofracture creation and explosive insertion. Explosive detonation diagnostic data were taken with stress and time-of-arrival gages and surface and in-formation accelerometers. The post-fracturing assessments indicated that: (1) hydrofracture creation and explosive insertion and detonation were accomplished essentially as planned; (2) induced fractures were randomly distributed through the shale with no extensively fractured regions or dislocation of shale; and (3) enhancement of permeability was limited to enlargement of the explosive-filled fractures.

  1. Hydrophobically associated polymers for wettability alteration and enhanced oil recovery – Article review

    Directory of Open Access Journals (Sweden)

    A.N. El-hoshoudy

    2017-09-01

    Full Text Available Crude oil and other petroleum products are crucial to the global economy today due to increasing energy demand approximately (∼1.5% per year and significant oil remaining after primary and secondary oil recovery (∼45–55% of original oil in place, OOIP, which accelerates the development of enhanced oil recovery (EOR technologies to maximize the recovered oil amount by non-conventional methods as polymer flooding. This review discusses enhanced oil recovery methods specially polymer flooding techniques and their effects on rock wettability alteration.

  2. Screening Criteria and Considerations of Offshore Enhanced Oil Recovery

    Directory of Open Access Journals (Sweden)

    Pan-Sang Kang

    2016-01-01

    Full Text Available The application of enhanced oil recovery (EOR in offshore oil fields has received significant attention due to the potentially enormous amount of recoverable oil. However, EOR application offshore is in its very early stage due to conditions that are more complex than onshore oil fields, owing to the unique parameters present offshore. Therefore, successful EOR applications in offshore oil fields require different screening criteria than those for conventional onshore applications. A comprehensive database for onshore applications of EOR processes together with a limited offshore EOR application database are analyzed in this paper, and the important parameters for successful offshore application are incorporated into the new EOR screening criteria. In this paper, screening criteria to determine acceptable EOR processes for offshore fields, including hydrocarbon gas miscible, CO2 miscible, and polymer processes, are presented. Suggested screening criteria for these EOR processes comprise quantitative boundaries and qualitative considerations. Quantitative screening criteria are predominantly based on quantifiable data, such as oil and reservoir properties. Qualitative screening considerations mainly focus on the operational issues present offshore, including platform space constraints, limited disposal options, injectant availability, and flow assurance matters (including hydrate formation and difficulties in emulsion separation.

  3. Phosphoric acid activation of Morrocan oil shale of Timahdit: influence of the experimental conditions on yied and surface area of adsorbents

    Energy Technology Data Exchange (ETDEWEB)

    Ichcho, S.; Khouya, E.; Abourriche, A.; Ezzine, M.; Hannache, H. [Faculte des Sciences Ben M' sik, Lab. des Materiaux Thermostructuraux, Dept. de Chimie, Casablanca (Morocco); Naslain, R.; Pailler, R. [Bordeaux-1 Univ., Lab. des Composites Thermostructuraux, 33 (France)

    2005-03-01

    The use of Moroccan oil shale for the preparation of adsorbents by chemical activation with phosphoric acid is analysed. The results indicate that this material is promising for this application. The activation process produces adsorbents having a surface area higher than 300 m{sup 2}/g. The effect of different conditions of preparation on the yield and surface area is discussed. These parameters are H{sub 3}PO{sub 4}/shale weight ratio, carbonization temperature, carbonization time and concentration of H{sub 3}PO{sub 4}. (authors)

  4. On the use of sodium lignosulphonate for enhanced oil recovery

    Science.gov (United States)

    Azis, M. M.; Rachmadi, H.; Wintoko, J.; Yuliansyah, A. T.; Hasokowati, W.; Purwono, S.; Rochmadi, W.; Murachman, B.

    2017-05-01

    There has been large interest to utilize oil reservoirs in Indonesia by using Enhanced Oil Recovery (EOR) processes. Injection of surfactant as a part of chemical injection technique in EOR is known to aid the mobility and reduction in surface tension. One potential surfactant for EOR application is Sodium Lignosulphonate (SLS) which can be made from various sources particularly empty fruit bunch of oil palm and black liquor from kraft pulp production. Here, we will discuss a number of methods for SLS production which includes lignin isolation techniques and sulphonation reaction. The use of SLS alone as EOR surfactant, however, is often not feasible as the Interfacial Tension (IFT) value of SLS is typically above the order of 10-3 dyne/cm which is mandated for EOR application. Hence, brief discussion on SLS formulation screening is provided which illustrates an extensive labwork experience during the SLS development in our lab.

  5. Fermentation assisted byproduct recovery in the palm oil industry

    Energy Technology Data Exchange (ETDEWEB)

    Stanton, W.R.

    1983-05-01

    The production of palm oil from Elaeis guineensis is a leading natural product industry in Malaysia, giving rise to a number of residues, including a rich, fruity liquor from the pulp. The liquor, of which 7-10 million tonnes a year are currently produced, has some 6% organic solids, including 0.7-1.0% or more of oil which physical processing has failed to extract. Present anaerobic digestion processes exploit only the energy and fertiliser value. Methods are described in this paper for thermophilic, microbially assisted digestion for component separation and recovery, exploiting the widely used techniques for fruit juice extraction involving enzymic breakdown of starch, pectin and other cell components. Anaerobiosis and acidogenesis help protect and release residual oil, concomitantly preserving the solids against rancidity and spoilage by ensilage. The separated wet solids are nutritive (17% protein on dry matter), biologically safe and attractive to livestock. Downstream use of the liquor is aided by the thermophilic digestion. (Refs. 33).

  6. Using ethnography to monitor the community health implications of onshore unconventional oil and gas developments: examples from Pennsylvania's Marcellus Shale.

    Science.gov (United States)

    Perry, Simona L

    2013-01-01

    The ethnographer's toolbox has within it a variety of methods for describing and analyzing the everyday lives of human beings that can be useful to public health practitioners and policymakers. These methods can be employed to uncover information on some of the harder-to-monitor psychological, sociocultural, and environmental factors that may lead to chronic stress in individuals and communities. In addition, because most ethnographic research studies involve deep and long-term engagement with local communities, the information collected by ethnographic researchers can be useful in tracking long- and short-term changes in overall well-being and health. Set within an environmental justice framework, this article uses examples from ongoing ethnographic fieldwork in the Marcellus Shale gas fields of Pennsylvania to describe and justify using an ethnographic approach to monitor the psychological and sociocultural determinants of community health as they relate to unconventional oil and gas development projects in the United States.

  7. Optimizing oil recovery in the Wasson Denver unit

    Energy Technology Data Exchange (ETDEWEB)

    Mayfield, G.B.

    1973-12-01

    Optimizing oil recovery has been a combined effort of many engineering disciplines in the Shell-operated Denver unit of the Wasson San Andres field of Gaines and Yoakum counties, Texas. Rising market demand and increased oil allowables provided the impetus for full-scale infill drilling, major injection system expansion and active remedial efforts. Maintaining high producing and injection efficiency required concentrated production engineering and field operations' work. Areas of specific activity are well completions, the injection system, flood surveillance, and workovers. The Denver unit is the largest of 5 waterflood pressure maintenance projects in this field discovered in 1936. The unit currently contains 664 oil producing wells and 238 water injection wells. Production is from the Permian San Andres dolomite formation at an average total depth of 5,200 ft. Gross pay thickness is from 300 to 500 ft. Production and performance curves are shown. A graphical representation shows the completion and acid treatment program for producers and injection well to maximize oil recovery.

  8. Effects of organic wastes on water quality from processing of oil shale from the Green River Formation, Colorado, Utah, and Wyoming

    Science.gov (United States)

    Leenheer, J.A.; Noyes, T.I.

    1986-01-01

    A series of investigations were conducted during a 6-year research project to determine the nature and effects of organic wastes from processing of Green River Formation oil shale on water quality. Fifty percent of the organic compounds in two retort wastewaters were identified as various aromatic amines, mono- and dicarboxylic acids phenols, amides, alcohols, ketones, nitriles, and hydroxypyridines. Spent shales with carbonaceous coatings were found to have good sorbent properties for organic constituents of retort wastewaters. However, soils sampled adjacent to an in situ retort had only fair sorbent properties for organic constituents or retort wastewater, and application of retort wastewater caused disruption of soil structure characteristics and extracted soil organic matter constituents. Microbiological degradation of organic solutes in retort wastewaters was found to occur preferentially in hydrocarbons and fatty acid groups of compounds. Aromatic amines did not degrade and they inhibited bacterial growth where their concentrations were significant. Ammonia, aromatic amines, and thiocyanate persisted in groundwater contaminated by in situ oil shale retorting, but thiosulfate was quantitatively degraded one year after the burn. Thiocyanate was found to be the best conservative tracer for retort water discharged into groundwater. Natural organic solutes, isolated from groundwater in contact with Green River Formation oil shale and from the White River near Rangely, Colorado, were readily distinguished from organic constituents in retort wastewaters by molecular weight and chemical characteristic differences. (USGS)

  9. Simulations of Microbial-Enhanced Oil Recovery: Adsorption and Filtration

    DEFF Research Database (Denmark)

    Nielsen, Sidsel Marie; Nesterov, Igor; Shapiro, Alexander

    2014-01-01

    is introduced to study the process efficiency: the dimensionless time at which average recovery between pure water injection and maximum surfactant effect is reached. This characteristic recovery period (CRP) was studied as a function of the different MEOR parameters such as bacterial activity, filtration......In the context of microbial-enhanced oil recovery (MEOR) with injection of surfactant-producing bacteria into the reservoir, different types of bacteria attachment and growth scenarios are studied using a 1D simulator. The irreversible bacteria attachment due to filtration similar to the deep bed...... filtration (DBF) is examined along with the commonly used reversible equilibrium adsorption (REA). The characteristics of the two models are highlighted. The options for bacteria growth are the uniform growth in both phases and growth of attached bacteria only. It is found that uniform growth scenario...

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

    Energy Technology Data Exchange (ETDEWEB)

    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

  11. Water resources and shale gas/oil production in the Appalachian Basin: critical issues and evolving developments

    Science.gov (United States)

    Kappel, William M.; Williams, John H.; Szabo, Zoltan

    2013-01-01

    Unconventional natural gas and oil resources in the United States are important components of a national energy program. While the Nation seeks greater energy independence and greener sources of energy, Federal agencies with environmental responsibilities, state and local regulators and water-resource agencies, and citizens throughout areas of unconventional shale gas development have concerns about the environmental effects of high volume hydraulic fracturing (HVHF), including those in the Appalachian Basin in the northeastern United States (fig. 1). Environmental concerns posing critical challenges include the availability and use of surface water and groundwater for hydraulic fracturing; the migration of stray gas and potential effects on overlying aquifers; the potential for flowback, formation fluids, and other wastes to contaminate surface water and groundwater; and the effects from drill pads, roads, and pipeline infrastructure on land disturbance in small watersheds and headwater streams (U.S. Government Printing Office, 2012). Federal, state, regional and local agencies, along with the gas industry, are striving to use the best science and technology to develop these unconventional resources in an environmentally safe manner. Some of these concerns were addressed in U.S. Geological Survey (USGS) Fact Sheet 2009–3032 (Soeder and Kappel, 2009) about potential critical effects on water resources associated with the development of gas extraction from the Marcellus Shale of the Hamilton Group (Ver Straeten and others, 1994). Since that time, (1) the extraction process has evolved, (2) environmental awareness related to high-volume hydraulic fracturing process has increased, (3) state regulations concerning gas well drilling have been modified, and (4) the practices used by industry to obtain, transport, recover, treat, recycle, and ultimately dispose of the spent fluids and solid waste materials have evolved. This report updates and expands on Fact Sheet 2009

  12. Study of alternatives for future operations of the naval petroleum and oil shale reserves, NOSR-2, Uintah and Carbon Counties, Utah. Final report

    Energy Technology Data Exchange (ETDEWEB)

    NONE

    1996-12-01

    The US Department of Energy (DOE) has asked Gustavson Associates, Inc. to serve as an Independent Petroleum Consultant and authorized a study and recommendations regarding future development of Naval Oil Shale Reserve No. 2 (NOSR-2) in Uintah and Carbon Counties, Utah. The US owns 100% of the mineral rights and about 60% of the surface rights in NOSR-2. The Ute Indian Tribe owns the other 40% of the surface. This 88,890-acre tract was set aside as an oil shale reserve for the US Navy by an Executive Order of President Wilson in 1916. Management of NOSR-2 is the responsibility of DOE. No drilling for oil and gas has occurred on the property and no production has been established. No reserves are present, although the area is hypothesized to overlay gas resources. Mapping by the US Geological Survey and others has resulted in speculative seismic leads for structures that may or may not hold conventional oil and gas. All of the mineral rights (including oil shale) must be considered exploratory and the mineral rights must be valued accordingly. The opinion recommended to maximize value to the US is Option 4, sale of the interest of the US of all or part of NOSR-2. Evaluation of this option results in an estimated value which is more than three times greater than the next highest estimated value, for Option 2, transfer to the Department of the Interior for leasing.

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  14. Microbial polysaccharide produced from crude oil and its applicability in secondary oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Wang, X. (Chinese Academy of Sciences, Beijing, China); Wang, C.

    1980-01-01

    This paper deals with a strain of bacterium Brevibacterium viscogenes nov. sp. 74-230, which produces extracellular polysaccharide from curde oil and its fractions. The effects of ages of the inoculum, several kinds of crude oil and its fractions, and contents of crude oil on the synthesis of polysaccharide were investigated. When crude oil was used as the sole carbon source (12%, w/v) in 50 or 240 1 fermentors, 8.0 g/1 of polysaccharide was obtained. The changes of hydrocarbon components after fermentation were analysed. They indicated that the bacterium strain mainly had utilized n-alkane. The fermented gummy solution was diluted and used as a driving fluid in laboratory scale model experiments. When the injection volume corresponds to 20% of the pore volume, the secondary oil recovery was enhanced to about 9% of the initial reserves.

  15. Future Recovery of Energy and Mineral Values from Organic-Rich Shales (Summary L'avenir de la production d'énergie et de la valeur minérale des schistes riches en matière organique (résumé

    Directory of Open Access Journals (Sweden)

    Park W. C.

    2006-10-01

    Full Text Available Oil shale deposits vary significantly in their geological nature and can represent enormous reserves of low grades ores for various minerals such as alumina, sodium carbonates, molybdenum, nickel, vanadium, and uranium. The treatment of these rocks for mineral values can be economically attractive when coupled with the production of synthetic oil. Mutually shared costs for extractinq the mineral values can be favorably affected by utilizing by-products from the oil shale retorting. These can include the residual char for a carbonaceous reductant or fuel, C02 for acidification, or lime and soda ash for caustic. Conversely, an inappropriate choice of oil shale retorting conditions can substantially lower subsequent recovery of mineral values from the spent shale. The proceeding considerations will be discussed for several oil shale deposits including: 1. The Green River formation in the mid-western United States which is not only oil rich but also represents a nearly inexhaustible domestic supply of alumina and sodium carbonates and 2. The block shale of Julia Creek, Queensland, Australia, the Devonian Chattanooga shale in the United States, the Cambrian Kulm shale in Sweden, the Permian Lodeve shale in southern France, and the Paleozoic shales from Korea and USSR for energy and metal values such as molybdenum, nickel, vanadium, and uranium. La nature géologique des dépôts de schistes à huile est très variée ; ces schistes peuvent représenter des réserves énormes de minerais à faible teneur de métaux tels que l'aluminium, le molybdène, le nickel, le vanadium, l'uranium, sans oublier le carbonate de sodium. Le traitement de ces roches pour leur valeur minérale peut être attractif économiquement s'il est associé à la production d'huile synthétique. La répartition des coûts d'extraction des métaux peut être favorablement affectée en utilisant les sous-produits du traitement des schistes à huile. Ceci peut comprendre le goudron

  16. First joint SPE/DOE symposium on enhanced oil recovery, proceedings supplement

    Energy Technology Data Exchange (ETDEWEB)

    None

    1980-01-01

    The First Joint Symposium on Enhanced Oil Recovery sponsored by the Society of Petroleum Engineers and the US Department of Energy was held in Tulsa, Oklahoma. Besides the thirty-three technical papers which covered all phases of enhanced oil recovery and were published in the Proceedings, the Symposium included a session on Enhanced Oil Recovery Incentives where ten papers were presented which discussed the status of enhanced oil recovery technology, and included papers on incentive programs of the United States, Canada and Venezuela. These papers are published in this Proceedings Supplement under the following titles: Federal Government Role in enhanced Oil Recovery; Financial Realities of an Adequate Petroleum Supply; Major Technology Constraints in Enhanced Oil Recovery; Decontrol-Opportunities and Dangers; Status of EOR Technology; Impact of Federal Incentives on US Production; Canadian Incentives Program; and Heavy Oil Incentives in Venezuela.

  17. Using CO2 Prophet to estimate recovery factors for carbon dioxide enhanced oil recovery

    Science.gov (United States)

    Attanasi, Emil D.

    2017-07-17

    IntroductionThe Oil and Gas Journal’s enhanced oil recovery (EOR) survey for 2014 (Koottungal, 2014) showed that gas injection is the most frequently applied method of EOR in the United States and that carbon dioxide (CO2 ) is the most commonly used injection fluid for miscible operations. The CO2-EOR process typically follows primary and secondary (waterflood) phases of oil reservoir development. The common objective of implementing a CO2-EOR program is to produce oil that remains after the economic limit of waterflood recovery is reached. Under conditions of miscibility or multicontact miscibility, the injected CO2 partitions between the gas and liquid CO2 phases, swells the oil, and reduces the viscosity of the residual oil so that the lighter fractions of the oil vaporize and mix with the CO2 gas phase (Teletzke and others, 2005). Miscibility occurs when the reservoir pressure is at least at the minimum miscibility pressure (MMP). The MMP depends, in turn, on oil composition, impurities of the CO2 injection stream, and reservoir temperature. At pressures below the MMP, component partitioning, oil swelling, and viscosity reduction occur, but the efficiency is increasingly reduced as the pressure falls farther below the MMP. CO2-EOR processes are applied at the reservoir level, where a reservoir is defined as an underground formation containing an individual and separate pool of producible hydrocarbons that is confined by impermeable rock or water barriers and is characterized by a single natural pressure system. A field may consist of a single reservoir or multiple reservoirs that are not in communication but which may be associated with or related to a single structural or stratigraphic feature (U.S. Energy Information Administration [EIA], 2000). The purpose of modeling the CO2-EOR process is discussed along with the potential CO2-EOR predictive models. The data demands of models and the scope of the assessments require tradeoffs between reservoir

  18. Heavily Oiled Salt Marsh following the Deepwater Horizon Oil Spill, Ecological Comparisons of Shoreline Cleanup Treatments and Recovery.

    Science.gov (United States)

    Zengel, Scott; Bernik, Brittany M; Rutherford, Nicolle; Nixon, Zachary; Michel, Jacqueline

    2015-01-01

    The Deepwater Horizon oil spill affected hundreds of kilometers of coastal wetland shorelines, including salt marshes with persistent heavy oiling that required intensive shoreline "cleanup" treatment. Oiled marsh treatment involves a delicate balance among: removing oil, speeding the degradation of remaining oil, protecting wildlife, fostering habitat recovery, and not causing further ecological damage with treatment. To examine the effectiveness and ecological effects of treatment during the emergency response, oiling characteristics and ecological parameters were compared over two years among heavily oiled test plots subject to: manual treatment, mechanical treatment, natural recovery (no treatment, oiled control), as well as adjacent reference conditions. An additional experiment compared areas with and without vegetation planting following treatment. Negative effects of persistent heavy oiling on marsh vegetation, intertidal invertebrates, and shoreline erosion were observed. In areas without treatment, oiling conditions and negative effects for most marsh parameters did not considerably improve over two years. Both manual and mechanical treatment were effective at improving oiling conditions and vegetation characteristics, beginning the recovery process, though recovery was not complete by two years. Mechanical treatment had additional negative effects of mixing oil into the marsh soils and further accelerating erosion. Manual treatment appeared to strike the right balance between improving oiling and habitat conditions while not causing additional detrimental effects. However, even with these improvements, marsh periwinkle snails showed minimal signs of recovery through two years, suggesting that some ecosystem components may lag vegetation recovery. Planting following treatment quickened vegetation recovery and reduced shoreline erosion. Faced with comparable marsh oiling in the future, we would recommend manual treatment followed by planting. We caution

  19. Heavily Oiled Salt Marsh following the Deepwater Horizon Oil Spill, Ecological Comparisons of Shoreline Cleanup Treatments and Recovery.

    Directory of Open Access Journals (Sweden)

    Scott Zengel

    Full Text Available The Deepwater Horizon oil spill affected hundreds of kilometers of coastal wetland shorelines, including salt marshes with persistent heavy oiling that required intensive shoreline "cleanup" treatment. Oiled marsh treatment involves a delicate balance among: removing oil, speeding the degradation of remaining oil, protecting wildlife, fostering habitat recovery, and not causing further ecological damage with treatment. To examine the effectiveness and ecological effects of treatment during the emergency response, oiling characteristics and ecological parameters were compared over two years among heavily oiled test plots subject to: manual treatment, mechanical treatment, natural recovery (no treatment, oiled control, as well as adjacent reference conditions. An additional experiment compared areas with and without vegetation planting following treatment. Negative effects of persistent heavy oiling on marsh vegetation, intertidal invertebrates, and shoreline erosion were observed. In areas without treatment, oiling conditions and negative effects for most marsh parameters did not considerably improve over two years. Both manual and mechanical treatment were effective at improving oiling conditions and vegetation characteristics, beginning the recovery process, though recovery was not complete by two years. Mechanical treatment had additional negative effects of mixing oil into the marsh soils and further accelerating erosion. Manual treatment appeared to strike the right balance between improving oiling and habitat conditions while not causing additional detrimental effects. However, even with these improvements, marsh periwinkle snails showed minimal signs of recovery through two years, suggesting that some ecosystem components may lag vegetation recovery. Planting following treatment quickened vegetation recovery and reduced shoreline erosion. Faced with comparable marsh oiling in the future, we would recommend manual treatment followed by

  20. Refining of Military Jet Fuels from Shale Oil. Part IV. Process Computer Modeling Studies.

    Science.gov (United States)

    1982-08-01

    Thermal Units C1 Methane C2 Ethane C3 Propane C3 Propylene C4 Mixed Butanes n-C4 Normal Butane i-C4 Isobutane C4 " Butylene C5 Pentane C6...for lighter products such as fuel gas, propane , propylene, C4 ’s, and C5 1 s. For heavier stream components, a set of pseudocomponents was developed...yields rapidly rise in the crack- ing unit as hydrotreating severity in the crude shale hydro- treater is reduced. This phenomenon results in the

  1. Three approaches for estimating recovery factors in carbon dioxide enhanced oil recovery

    Science.gov (United States)

    Verma, Mahendra K.

    2017-07-17

    PrefaceThe Energy Independence and Security Act of 2007 authorized the U.S. Geological Survey (USGS) to conduct a national assessment of geologic storage resources for carbon dioxide (CO2) and requested the USGS to estimate the “potential volumes of oil and gas recoverable by injection and sequestration of industrial carbon dioxide in potential sequestration formations” (42 U.S.C. 17271(b)(4)). Geologic CO2 sequestration associated with enhanced oil recovery (EOR) using CO2 in existing hydrocarbon reservoirs has the potential to increase the U.S. hydrocarbon recoverable resource. The objective of this report is to provide detailed information on three approaches that can be used to calculate the incremental recovery factors for CO2-EOR. Therefore, the contents of this report could form an integral part of an assessment methodology that can be used to assess the sedimentary basins of the United States for the hydrocarbon recovery potential using CO2-EOR methods in conventional oil reservoirs.

  2. Microbial processes in the Athabasca Oil Sands and their potential applications in microbial enhanced oil recovery.

    Science.gov (United States)

    Harner, N K; Richardson, T L; Thompson, K A; Best, R J; Best, A S; Trevors, J T

    2011-11-01

    The Athabasca Oil Sands are located within the Western Canadian Sedimentary Basin, which covers over 140,200 km(2) of land in Alberta, Canada. The oil sands provide a unique environment for bacteria as a result of the stressors of low water availability and high hydrocarbon concentrations. Understanding the mechanisms bacteria use to tolerate these stresses may aid in our understanding of how hydrocarbon degradation has occurred over geological time, and how these processes and related tolerance mechanisms may be used in biotechnology applications such as microbial enhanced oil recovery (MEOR). The majority of research has focused on microbiology processes in oil reservoirs and oilfields; as such there is a paucity of information specific to oil sands. By studying microbial processes in oil sands there is the potential to use microbes in MEOR applications. This article reviews the microbiology of the Athabasca Oil Sands and the mechanisms bacteria use to tolerate low water and high hydrocarbon availability in oil reservoirs and oilfields, and potential applications in MEOR.

  3. Enhanced Oil Recovery from Oil-wet Carbonate Rock by Spontaneous Imbibition of Aqueous Surfactant Solutions

    Energy Technology Data Exchange (ETDEWEB)

    Standnes, Dag Chun

    2001-09-01

    The main theme of this thesis is an experimental investigation of spontaneous imbibition (SI) of aqueous cationic surfactant solution into oil-wet carbonate (chalk- and dolomite cores). The static imbibition process is believed to represent the matrix flow of oil and water in a fractured reservoir. It was known that aqueous solution of C{sub 12}-N(CH{sub 3}){sub 3}Br (C12TAB) was able to imbibe spontaneously into nearly oil-wet chalk material, but the underlying mechanism was not understood. The present work was therefore initiated, with the following objectives: (1) Put forward a hypothesis for the chemical mechanism underlying the SI of C12TAB solutions into oil-wet chalk material based on experimental data and (2) Perform screening tests of low-cost commercially available surfactants for their ability to displace oil by SI of water into oil-wet carbonate rock material. It is essential for optimal use of the surfactant in field application to have detailed knowledge about the mechanism underlying the SI process. The thesis also discusses some preliminary experimental results and suggests mechanisms for enhanced oil recovery from oil-wet carbonate rock induced by supply of thermal energy.

  4. Alkaline assisted thermal oil recovery: Kinetic and displacement studies

    Energy Technology Data Exchange (ETDEWEB)

    Saneie, S.; Yortsos, Y.C.

    1993-06-01

    This report deals with two major issues of chemical assisted flooding - the interaction of caustic, one of the proposed additives to steam flood, with the reservoir rock, and the displacement of oil by a chemical flood at elevated temperatures. A mathematical model simulating the kinetics of silica dissolution and hydroxyl ion consumption in a typical alkaline flooding environment is first developed. The model is based on the premise that dissolution occurs via hydrolysis of active sites through the formation of an intermediate complex, which is in equilibrium with the silicic acid in solution. Both static (batch) and dynamic (core flood) processes are simulated to examine the sensitivity of caustic consumption and silica dissolution to process parameters, and to determine rates of propagation of pH values. The model presented provides a quantitative description of the quartz-alkali interaction in terms of pH, salinity, ion exchange properties, temperature and contact time, which are of significant importance in the design of soluble silicate flooding processes. The modeling of an adiabatic hot waterflood assisted by the simultaneous injection of a chemical additive is next presented. The model is also applicable to the hot alkaline flooding under conditions of negligible adsorption of the generated anionic surfactant and of hydroxide adsorption being Langmuirian. The theory of generalized simple waves (coherence ) is used to develop solutions for the temperature, concentration, and oil saturation profiles, as well as the oil recovery curves. It is shown that, for Langmuir adsorption kinetics, the chemical resides in the heated region of the reservoir if its injection concentration is below a critical value, and in the unheated region if its concentration exceeds this critical value. Results for a chemical slug injection in a tertiary recovery process indicate recovery performance is maximized when chemical resides in the heated region of the reservior.

  5. Discrete model for the recovery of oil from a reservoir

    Energy Technology Data Exchange (ETDEWEB)

    Vargas-Jarillo, C.

    1983-01-01

    Simulation of oil recovery by means of a molecular type approach is proposed. This means the materials are considered to be composed of a finite number of particles, which are approximate for molecules. Porous flow is studied qualitatively under the assumption that particles of rock, oil and the flooding flow interact with each other by means of a compensating Lennard-Jones type potential. The author also considers the system to be under the influence of gravity. Equipped with the developed tools, miscible displacement in an oil reservoir is studied from various initial data. Extensive computations are described and discussed. The velocity and the rate of injection of the ingoing particles prove to be among the most important parameters that can be adjusted to increase the rate of production. It is noted also that the fingering phenomenum is readily detected. The influence of gravity is important, since it affects fingering and increases the time that the oil particles take to go out. A comparison is made with actual physical experiments.

  6. Alkaline injection for enhanced oil recovery: a status report

    Energy Technology Data Exchange (ETDEWEB)

    Mayer, E.H.; Berg, R.L.; Carmichael, J.D.; Weinbrandt, R.M.

    1983-01-01

    In the past several years, there has been renewed interest in enhanced oil recovery (EOR) by alkaline injection. Alkaline solutions also are being used as preflushes in micellar/polymer projects. Several major field tests of alkaline flooding are planned, are in progress, or recently have been completed. Considerable basic research on alkaline injection has been published recently, and more is in progress. This paper summarizes known field tests and, where available, the amount of alkali injected and the performance results. Recent laboratory work, much sponsored by the U.S. DOE, and the findings are described. Alkaline flood field test plans for new projects are summarized.

  7. Viscous fingering and channeling in chemical enhanced oil recovery

    Science.gov (United States)

    Daripa, Prabir; Dutta, Sourav

    2017-11-01

    We have developed a hybrid numerical method based on discontinuous finite element method and modified method of characteristics to compute the multiphase multicomponent fluid flow in porous media in the context of chemical enhanced oil recovery. We use this method to study the effect of various chemical components on the viscous fingering and channeling in rectilinear and radial flow configurations. We will also discuss about the efficiency of various flooding schemes based on these understandings. Time permitting, we will discuss about the effect of variable injection rates in these practical setting. U.S. National Science Foundation Grant DMS-1522782.

  8. Enhanced Oil Recovery with CO2 Capture and Sequestration

    Energy Technology Data Exchange (ETDEWEB)

    Andrei, Maria; De Simoni, Michela; Delbianco, Alberto; Cazzani, Piero; Zanibelli, Laura

    2010-09-15

    This paper presents the results of a feasibility study aimed at extending the production life of a small oilfield in Italy through EOR, employing the CO2 captured from the flue gas streams of the refinery nearby. The EOR operation allows the recovery of additional reserves while a consistent amount of the CO2 injected remains permanently stored into the reservoir. The screening process selection for EOR-CO2 and the main elements of the pilot project for the proper upstream-downstream integration will be described. Evaluation of EOR-CO2 extension to other oilfields and its effect on oil production and project's economics will be reported.

  9. Microbial enhanced oil recovery research. Final report, Annex 5

    Energy Technology Data Exchange (ETDEWEB)

    Sharma, M.M.; Gerogiou, G.

    1993-07-01

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

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

    Energy Technology Data Exchange (ETDEWEB)

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

    2003-06-01

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

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  12. Assessment of Research Needs for Oil Recovery from Heavy-Oil Sources and Tar Sands (FERWG-IIIA)

    Energy Technology Data Exchange (ETDEWEB)

    Penner, S.S.

    1982-03-01

    The Fossil Energy Research Working Group (FERWG), at the request of J.W. Mares (Assistant Secretary for Fossil Energy) and A.W. Trivelpiece (Director, Office of Energy Research), has reviewed and evaluated the U.S. programs on oil recovery from heavy oil sources and tar sands. These studies were performed in order to provide an independent assessment of research areas that affect the prospects for oil recovery from these sources. This report summarizes the findings and research recommendations of FERWG.

  13. Sulfonated phenolic material and its use in post primary oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Pardue, J. E.; Stapp, P. R.

    1984-09-04

    Sulfonated phenolic compounds as well as sulfomethylated phenolic compounds, surfactant systems containing such compound and the use of such surfactant systems in post primary oil recovery are disclosed.

  14. Play-level distributions of estimates of recovery factors for a miscible carbon dioxide enhanced oil recovery method used in oil reservoirs in the conterminous United States

    Science.gov (United States)

    Attanasi, E.D.; Freeman, P.A.

    2016-03-02

    In a U.S. Geological Survey (USGS) study, recovery-factor estimates were calculated by using a publicly available reservoir simulator (CO2 Prophet) to estimate how much oil might be recovered with the application of a miscible carbon dioxide (CO2) enhanced oil recovery (EOR) method to technically screened oil reservoirs located in onshore and State offshore areas in the conterminous United States. A recovery factor represents the percentage of an oil reservoir’s original oil in place estimated to be recoverable by the application of a miscible CO2-EOR method. The USGS estimates were calculated for 2,018 clastic and 1,681 carbonate candidate reservoirs in the “Significant Oil and Gas Fields of the United States Database” prepared by Nehring Associates, Inc. (2012).

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

    Energy Technology Data Exchange (ETDEWEB)

    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.

  16. National Assessment of Oil and Gas Project - Utica Shale Unconventional Assessment

    Data.gov (United States)

    U.S. Geological Survey, Department of the Interior — The Assessment Unit is the fundamental unit used in the National Assessment Project for the assessment of undiscovered oil and gas resources. The Assessment Unit is...

  17. A Collection of Chemical, Mineralogical, and Stable Isotopic Compositional Data for Green River Oil Shale from Depositional Center Cores in Colorado, Utah, and Wyoming

    Science.gov (United States)

    Tuttle, Michele L.W.

    2009-01-01

    For over half a century, the U.S. Geological Survey and collaborators have conducted stratigraphic and geochemical studies on the Eocene Green River Formation, which is known to contain large oil shale resources. Many of the studies were undertaken in the 1970s during the last oil shale boom. One such study analyzed the chemistry, mineralogy, and stable isotopy of the Green River Formation in the three major depositional basins: Piceance basin, Colo.; Uinta basin, Utah; and the Green River basin, Wyo. One depositional-center core from each basin was sampled and analyzed for major, minor, and trace chemistry; mineral composition and sulfide-mineral morphology; sulfur, nitrogen, and carbon forms; and stable isotopic composition (delta34S, delta15N, delta13C, and delta18O). Many of these data were published and used to support interpretative papers (see references herein). Some bulk-chemical and carbonate-isotopic data were never published and may be useful to studies that are currently exploring topics such as future oil shale development and the climate, geography, and weathering in the Eocene Epoch. These unpublished data, together with most of the U.S. Geological Survey data already published on these samples, are tabulated in this report.

  18. Pb-210 and Po-210 atmospheric releases via fly ash from oil shale-fired power plants.

    Science.gov (United States)

    Vaasma, Taavi; Loosaar, Jüri; Gyakwaa, Francis; Kiisk, Madis; Özden, Banu; Tkaczyk, Alan H

    2017-03-01

    During high temperature processes in the furnace volatile and semi-volatile elements and radionuclides are partially emitted to the environment, depending on their chemical form in the original fuel, the technological set-up of the combustion system, and the prevailing combustion conditions. Two of the world's largest oil shale-fired power plants (PPs) have been operational in Estonia from the 1960s, during which time creation of significant environmental emissions and waste containing naturally occurring radionuclides has occurred. Pb-210 and 210 Po are considered natural radionuclides with the highest emission rates from PPs and possess elevated potential radiation exposure risks to humans and the environment. These radionuclides have the highest activity concentration values in fine ash fractions, especially in fractions remaining below 2.5 μm. To determine the activity concentrations of 210 Pb and 210 Po in the PPs' outlet, sampling was conducted from boilers operating on pulverized fuel (PF) technology with novel integrated desulphurization (NID) system and bag filters as well as with electrostatic precipitators (ESPs). The 210 Pb and 210 Po activity concentrations remained around 300 Bq kg -1 for the NID system compared to 60-80 Bq kg -1 in the ESP system. The dominant ash fraction in both systems was PM2.5, constituting over 50% of the fly ash mass collected from the outlet. The authors estimate that the total atmospherically emitted activity for the modernized PPs remains dominantly below 1% of the activity that is inserted via fuel. The implementation of higher efficiency purifications systems has significantly reduced the negative effect of these PPs. Based on annually emitted fly ash and boilers' working hours, the 210 Pb and 210 Po activity released relative to energy production were up to 68.3 kBq GWh el -1 for 210 Pb and 64.6 kBq GWh el -1 for 210 Po. These values are 1 to 2 orders of magnitude lower compared to the situation in the 1980s. These

  19. Determination of Enhanced Oil Recovery Candidate Fields in the Volga-Ural Oil and Gas Region Territory

    Directory of Open Access Journals (Sweden)

    Mikhail Turbakov

    2015-10-01

    Full Text Available Most of the current Russian oil production comes from mature fields. The application of enhanced oil recovery methods on oil fields increases recovery efficiency. This article presents an analysis of the increased field development efficiency methods of the Volga-Ural oil and gas region, which allows the full and efficient development of last-stage fields with unconventional reserves and production stabilization. The selection of the optimum method for a given field is a complex procedure consisting of many stages, from collecting data about the field, through more advanced data interpretation, to working out a detailed proposal for the most efficient extraction method. In this article the instantaneous and average annual growth above wells average was taken as a performance criterion for enhanced oil recovery methods. Based on the performed analysis, it follows that candidate wells for enhanced oil recovery method use must meet the I group parameters (high values of the remaining recoverable reserves and improved reservoir properties, low water cut, obtained oil rate increase. In order to assess the possible increase in production rate after enhanced oil recovery methods hydrodynamic modeling of radial drilling, acid treatment and water-alternated-gas injection for two oil fields of the Volga-Ural oil and gas region were performed.

  20. Pressurised hot water extraction of n-alkanes and polyaromatic hydrocarbons in soil and sediment from the oil shale industry district in Estonia

    Energy Technology Data Exchange (ETDEWEB)

    Kronholm, J.; Kettunen, J.; Hartonen, K.; Riekkola, M.L. [Lab. of Analytical Chemistry, Dept. of Chemistry, Univ. of Helsinki (Finland)

    2004-07-01

    Background. Organic pollutants formed during thermal treatment of oil shale and then released from the solid waste (semi-coke) to aquatic life are a major concern in Estonia. Efficient environmentally friendly techniques are being sought for the analysis of soil and sediments for pollutants and for the clean up of contaminated areas. The altered physico-chemical properties of pressurised hot water can be exploited in the extraction of organics from solid samples. For example, the relative permittivity, hydrogen bonding ability and viscosity of water are decreased and diffusivity is increased with temperature. In addition, water is environmentally friendly, cheap, non-flammable and readily available. In small-scale or pilot-scale operations, pressurised hot water extraction (PHWE) can also be used in the purification of contaminated soil and sediments. Objective. PHWE and conventional Soxhlet extraction were applied to extract organic compounds from soil and sediment samples collected from various locations around a semi-coke mound in a mining district in northeastern Estonia. One important aim was to compare the extraction efficiencies of the two techniques. Another aim was to determine the pollutants in soil in the vicinity of the semi-coke mound and the sediments of two rivers (the Purtse river flowing to the Gulf of Finland and the Kohtla river feeding into the Purtse) and in canals between the Kohtla river and the semi-coke mound. Methods. The PHWE equipment was self-constructed and applied with temperatures of 300 and 350 C (P = ca. 200 bar). Soxhlet extraction was carried out for 20 h with dichloromethane as a solvent. All extracts were cleaned up with a silica gel column, concentrated and analysed by gas chromatography-mass spectrometry (GC-MS). Organic matter contents of the samples were determined. Results and discussion. Alkanes and polyaromatic hydrocarbons (PAHs) were the main compounds found in the GC-MS analysis after PHWE and Soxhlet extractions. In

  1. Geomechanical Study of Bakken Formation for Improved Oil Recovery

    Energy Technology Data Exchange (ETDEWEB)

    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.

  2. Development of alkaline/surfactant/polymer (ASP flooding technology for recovery of Karazhanbas oil

    Directory of Open Access Journals (Sweden)

    Birzhan Zhappasbaev

    2016-03-01

    Full Text Available The tertiary oil recovery methods like alkaline, surfactant and polymer (ASP flooding are very perspective in order to achieve the synergetic effect out of the different impacts which are caused by these chemicals, which affect oil and water filtration in the reservoir and increase oil recovery. In this communication, we consider the applicability of hydrophobically modified polyampholyte – poly(hexadecylaminocrotonatebetaine (PHDACB as ASP flooding agent for recovery of oil from Karazhanbas oilfield. As “polysoap”, the aqueous solution of PHDACB dissolved in aqueous KOH was used. This system combines the advantages of alkaline, surfactant and polymer and exhibits the synergistic effect. The laboratory results showed that the ASP flooding considerably increases the oil recovery in addition to water flooding. In perspective, the ASP flooding may substitute the steam injection and other thermal enhanced oil recovery (EOR technologies.

  3. Postischemic fish oil treatment confers task-dependent memory recovery.

    Science.gov (United States)

    de Oliveira, Janaína Nicolau; Reis, Luane Oliveira; Ferreira, Emilene Dias Fiuza; Godinho, Jacqueline; Bacarin, Cristiano Correia; Soares, Ligia Mendes; de Oliveira, Rúbia Maria Weffort; Milani, Humberto

    2017-08-01

    A series of our previous studies demonstrated that fish oil (FO), equivalent to 300mg/kg docosahexahenoic acid (DHA), facilitates memory recovery after transient, global cerebral ischemia (TGCI) in the aversive radial maze (AvRM). The present study sought to address two main issues: (i) whether the memory-protective effect of FO that has been observed in the AvRM can be replicated in the passive avoidance test (PAT) and object location test (OLT) and (ii) whether FO at doses that are lower than those used previously can also prevent TGCI-induced memory loss. In Experiment 1, naive rats were trained in the PAT, subjected to TGCI (4-vessel occlusion model), and tested for retrograde memory performance 8 and 15days after ischemia. Fish oil (300mg/kg/day DHA) was given orally for 8days. The first dose was delivered 4h postischemia. In Experiment 2, the rats were subjected to TGCI, treated with the same FO regimen, and then trained and tested in the OLT. In Experiment 3, the rats were trained in the AvRM, subjected to TGCI, administered FO (100, 200, and 300mg/kg DHA), and tested for memory performance up to 3weeks after TGCI. At the end of the behavioral tests, the brains were examined for neurodegeneration and neuroblast proliferation. All of the behavioral tests (PAT, OLT, and AvRM) were sensitive to ischemia, but only the AvRM was able to detect the memory-protective effect of FO. Ischemia-induced neurodegeneration and neuroblast proliferation were unaffected by FO treatment. These results suggest that (i) the beneficial effect of FO on memory recovery after TGCI is task-dependent, (ii) doses of FOmemory function in the radial maze, and (iii) cognitive recovery occurs in the absence of neuronal rescue and/or hippocampal neurogenesis. Copyright © 2017 Elsevier Inc. All rights reserved.

  4. Thermally-enhanced oil recovery method and apparatus

    Science.gov (United States)

    Stahl, Charles R.; Gibson, Michael A.; Knudsen, Christian W.

    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.

  5. Enhanced oil recovery chemicals from renewable wood resources

    Energy Technology Data Exchange (ETDEWEB)

    Grune, W.N.; Compere, A.L.; Griffith, W.L.; Crenshaw, J.M.

    1979-04-01

    Most of the wood pulp in the U.S. is produced by cooking, or digesting, wood chips in a chemical solution. These pulping processes have effluent streams which contain dissolved lignins, lignin breakdown products, and carbohydrates. There is a substantial economic incentive to use these materials as feedstocks for the production of high-valued micellar flood chemicals. The pulp and paper industries have practiced chemical recovery for almost a century. The largest chemical recycle processes are the internal recycle of inorganic salts for reuse in pulping. This is coupled with the use of waste organic compounds in the liquor as a fuel for directly-fired evaporation processes. Diversion of effluent and low valued streams for chemical recovery using fermentation, purification, or synthesis methods appears technically feasible in several cases. The use of new recovery processes could yield a variety of different wood-effluent based products. Some of the sugar acids in pulping liquors might be used as sequestering agents in reservoirs where there are large amounts of multivalent cations in flood brines. Fermentation production of high viscosity polymers, sequestering agents, and coagent alcohols appears worth further investigation. Tall oil acids and their derivatives can be used as surfactants in some reservoirs. Some waste constituents may adsorb preferentially on formations and thereby reduce loss of surfactants and other higher-valued chemicals.

  6. Formulation and evaluation of highway transportation fuels from shale and coal oils: project identification and evaluation of optimized alternative fuels. Second annual report, March 20, 1980-March 19, 1981. [Broadcut fuel mixtures of petroleum, shale, and coal products

    Energy Technology Data Exchange (ETDEWEB)

    Sefer, N.R.; Russell, J.A.

    1981-12-01

    Project work is reported for the formulation and testing of diesel and broadcut fuels containing components from petroleum, shale oil, and coal liquids. Formulation of most of the fuels was based on refinery modeling studies in the first year of the project. Product blends were prepared with a variety of compositions for use in this project and to distribute to other, similar research programs. Engine testing was conducted in a single-cylinder CLR engine over a range of loads and speeds. Relative performance and emissions were determined in comparison with typical petroleum diesel fuel. With the eight diesel fuels tested, it was found that well refined shale oil products show only minor differences in engine performance and emissions which are related to differences in boiling range. A less refined coal distillate can be used at low concentrations with normal engine performance and increased emissions of particulates and hydrocarbons. Higher concentrations of coal distillate degrade both performance and emissions. Broadcut fuels were tested in the same engine with variable results. All fuels showed increased fuel consumption and hydrocarbon emissions. The increase was greater with higher naphtha content or lower cetane number of the blends. Particulates and nitrogen oxides were high for blends with high 90% distillation temperatures. Operation may have been improved by modifying fuel injection. Cetane and distillation specifications may be advisable for future blends. Additional multi-cylinder and durability testing is planned using diesel fuels and broadcut fuels. Nine gasolines are scheduled for testing in the next phase of the project.

  7. Effects of in-situ oil-shale retorting on water quality near Rock Springs, Wyoming, Volume 1

    Energy Technology Data Exchange (ETDEWEB)

    Lindner-Lunsford, J.B.; Eddy, C.A.; Plafcan, M.; Lowham, H.W.

    1990-12-01

    Experimental in-situ retorting techniques (methods of extracting shale oil without mining) were used from 1969 to 1979 by the Department of Energy's (DOE) Laramie Energy Technology Center (LETC) at a test area near Rock Springs in southwestern Wyoming. The retorting experiments at site 9 have produced elevated concentrations of some contaminants in the ground water. During 1988 and 1989, the US Geological Survey, in cooperation with the US Department of Energy, conducted a site characterization study to evaluate the chemical contamination of ground water at the site. Water samples from 34 wells were analyzed; more than 70 identifiable organic compounds were detected using a combination of gas chromatography and mass spectrometry analytical methods. This report provides information that can be used to evaluate possible remedial action for the site. Remediation techniques that may be applicable include those techniques based on removing the contaminants from the aquifer and those based on immobilizing the contaminants. Before a technique is selected, the risks associated with the remedial action (including the no-action alternative) need to be assessed, and the criteria to be used for decisions regarding aquifer restoration need to be defined. 31 refs., 23 figs., 9 tabs.

  8. Holistic risk assessment of surface water contamination due to Pb-210 in oil produced water from the Bakken Shale.

    Science.gov (United States)

    Torres, Luisa; Yadav, Om Prakash; Khan, Eakalak

    2017-02-01

    A holistic risk assessment of surface water (SW) contamination due to lead-210 (Pb-210) in oil produced water (PW) from the Bakken Shale in North Dakota (ND) was conducted. Pb-210 is a relatively long-lived radionuclide and very mobile in water. Because of limited data on Pb-210, a simulation model was developed to determine its concentration based on its parent radium-226 and historical total dissolved solids levels in PW. Scenarios where PW spills could reach SW were analyzed by applying the four steps of the risk assessment process. These scenarios are: (1) storage tank overflow, (2) leakage in equipment, and (3) spills related to trucks used to transport PW. Furthermore, a survey was conducted in ND to quantify the risk perception of PW from different stakeholders. Findings from the study include a low probability of a PW spill reaching SW and simulated concentration of Pb-210 in drinking water higher than the recommended value established by the World Health Organization. Also, after including the results from the risk perception survey, the assessment indicates that the risk of contamination of the three scenarios evaluated is between medium-high to high. Copyright © 2016 Elsevier Ltd. All rights reserved.

  9. A kinetic study of the depyritization of oil shale HCl-kerogen concentrate by Thiobacillus ferrooxidans at different temperatures

    Directory of Open Access Journals (Sweden)

    OLGA CVETKOVIC

    2003-05-01

    Full Text Available The results of kinetic studies of bacterial depyritization of HCl-kerogen concentrate of Aleksinac (Serbia oil shale by the chemolithoautotrophic thionic bacteria Thiobacillus ferrooxidans under discontinuous laboratory conditions at various temperatures (0, 20, 28 and 37°C at a pH of ca. 1.5 are presented in this paper. Low pH prevents the occurrence of the precipitation of iron(III-ion hydrolysis products on the substrate particles and thereby reduces the process efficiency. Bacterial depyritization is developed as per kinetics of the first order. The activation energy which points to a successive mechanism of pyrite biooxidation, was computed from the Arrhenius plot. The biochemical kinetics indicators point to a high affinity of the bacteria toward pyrite but small values of Vmax, which are probably the result of decelerated metabolic processes due to the low pH value of the environment resp. the large difference of the pH between the external medium and the cell interior.

  10. Page 1 | i ! SFE of Chinese oil shale with water and toluene, 317 4 ...

    Indian Academy of Sciences (India)

    extracted with SC toluene than with SC water, although the total weight loss of the solid sample is almost the same, not being dependent on the solvent (toluene or water). 2) Average molecular weight and amount of the oil extracted are largest with SC toluene, followed by scwater and then Soxhlet extraction. 3) The extracts ...

  11. Unconventional shale-gas systems: The Mississippian Barnett Shale of north-central Texas as one model for thermogenic shale-gas assessment

    Science.gov (United States)

    Jarvie, D.M.; Hill, R.J.; Ruble, T.E.; Pollastro, R.M.

    2007-01-01

    Shale-gas resource plays can be distinguished by gas type and system characteristics. The Newark East gas field, located in the Fort Worth Basin, Texas, is defined by thermogenic gas production from low-porosity and low-permeability Barnett Shale. The Barnett Shale gas system, a self-contained source-reservoir system, has generated large amounts of gas in the key productive areas because of various characteristics and processes, including (1) excellent original organic richness and generation potential; (2) primary and secondary cracking of kerogen and retained oil, respectively; (3) retention of oil for cracking to gas by adsorption; (4) porosity resulting from organic matter decomposition; and (5) brittle mineralogical composition. The calculated total gas in place (GIP) based on estimated ultimate recovery that is based on production profiles and operator estimates is about 204 bcf/section (5.78 ?? 109 m3/1.73 ?? 104 m3). We estimate that the Barnett Shale has a total generation potential of about 609 bbl of oil equivalent/ac-ft or the equivalent of 3657 mcf/ac-ft (84.0 m3/m3). Assuming a thickness of 350 ft (107 m) and only sufficient hydrogen for partial cracking of retained oil to gas, a total generation potential of 820 bcf/section is estimated. Of this potential, approximately 60% was expelled, and the balance was retained for secondary cracking of oil to gas, if sufficient thermal maturity was reached. Gas storage capacity of the Barnett Shale at typical reservoir pressure, volume, and temperature conditions and 6% porosity shows a maximum storage capacity of 540 mcf/ac-ft or 159 scf/ton. Copyright ?? 2007. The American Association of Petroleum Geologists. All rights reserved.

  12. Optimization of Spore Forming Bacteria Flooding for Enhanced Oil Recovery in North Sea Chalk Reservoir

    DEFF Research Database (Denmark)

    Halim, Amalia Yunita; Nielsen, Sidsel Marie; Eliasson Lantz, Anna

    2015-01-01

    Little has been done to study microbial enhanced oil recovery (MEOR) in chalk reservoirs. The present study focused on core flooding experiments to see microbial plugging and its effect on oil recovery. A pressure tapped core holder with pressure ports at 1.2 cm, 3.8 cm, and 6.3 cm from the inlet...

  13. Precipitation of Calcite during the Deposition of Paleogene Sangkarewang Oil Shale, Ombilin Basin, West Sumatra, Indonesia

    Directory of Open Access Journals (Sweden)

    Agus Haris Widayat

    2015-09-01

    Full Text Available DOI: 10.17014/ijog.2.3.185-197Geochemical and petrographical analyses were carried out to investigate the occurrence of calcite in theformer Ombilin lacustrine lake. The study involves eight samples taken from a 56 m long drill core of Sangkarewangoil shale. Geochemical investigation showed that the samples consist of varied terrigenous input represented by Si, Al, K, and Ti, and autochthonous input represented by S, total organic carbon (TOC, and d13C of bulk organic matter. Along the drill core profile the abundance of autochthonous input decreases upwards, while that of terrigenous input oppositely increases upwards. Petrographical analysis revealed that calcite is a major mineral in the samples. In this study, the abundance of calcite could be represented by the abundance of Ca, as calcite is the only significant Ca containing mineral. Ca is abundant in the samples (8.4% in average and its concentration varies similarly with those of S, TOC, and d13C, suggesting that the element as well as calcite incorporates the autochthonous input. Thevariation of calcite abundance in the drill core profile is considered to be related with primary productivity changes during the development of the former lake. Higher primary productivity represented by more positive of d13C value(-24.8‰ during the deposition of the lower part of the drill core profile promoted the higher amount of deposited organic matter. In such environment, the supersaturation of carbonate ion in lake water was also reached and significant precipitation of authigenic calcite occurred. As the lake developed, the primary productivity decreased as indicated by more negative of d13C value (eventually -26.8‰. This condition led to the decreases of deposited organic matterand calcite in the lake sediments.

  14. Growth model for large branched three-dimensional hydraulic crack system in gas or oil shale

    Science.gov (United States)

    Chau, Viet T.

    2016-01-01

    Recent analysis of gas outflow histories at wellheads shows that the hydraulic crack spacing must be of the order of 0.1 m (rather than 1 m or 10 m). Consequently, the existing models, limited to one or several cracks, are unrealistic. The reality is 105–106 almost vertical hydraulic cracks per fracking stage. Here, we study the growth of two intersecting near-orthogonal systems of parallel hydraulic cracks spaced at 0.1 m, preferably following pre-existing rock joints. One key idea is that, to model lateral cracks branching from a primary crack wall, crack pressurization, by viscous Poiseuille-type flow, of compressible (proppant-laden) frac water must be complemented with the pressurization of a sufficient volume of micropores and microcracks by Darcy-type water diffusion into the shale, to generate tension along existing crack walls, overcoming the strength limit of the cohesive-crack or crack-band model. A second key idea is that enforcing the equilibrium of stresses in cracks, pores and water, with the generation of tension in the solid phase, requires a new three-phase medium concept, which is transitional between Biot’s two-phase medium and Terzaghi’s effective stress and introduces the loading of the solid by pressure gradients of diffusing pore water. A computer program, combining finite elements for deformation and fracture with volume elements for water flow, is developed to validate the new model. This article is part of the themed issue ‘Energy and the subsurface’. PMID:27597791

  15. Mechanisms of microbial oil recovery by Clostridium acetobutylicum and Bacillus strain JF-2

    Energy Technology Data Exchange (ETDEWEB)

    Marsh, T.L.; Zhang, X.; Knapp, R.M.; McInerney, M.J.; Sharma, P.K.; Jackson, B.E.

    1995-12-31

    Core displacement experiments at elevated pressures were conducted to determine whether microbial processes are effective under conditions that simulate those found in an actual oil reservoir. The in-situ growth of Clostridium acetobutylicum and Bacillus strain JF-2 resulted in the recovery of residual oil. About 21 and 23% of the residual oil was recovered by C. acetobutylicum and Bacillus strain JF-2, respectively. Flooding cores with cell-free culture fluids of C. acetobutylicum with and without the addition of 50 mM acetone and 100 mM butanol did not result in the recovery of residual oil. Mathematical simulations showed that the amount of gas produced by the clostridial fermentation was not showed that the amount of gas produced by the clostridial fermentation was not sufficient to recover residual oil. Oil recovery by Bacillus strain JF-2 was highly correlated to surfactant production. A biosurfactant-deficient mutant of strain JF-2 was not capable of recovering residual oil. These data show that surfactant production is an important mechanism for microbially enhanced oil recovery. The mechanism for oil recovery by C. acetobutylicum is not understood at this time, but the production of acids, solvents, or gases alone cannot explain the observed increases in oil recovery by this organism.

  16. Integrating Oil and Gas Measurement Data to Estimate Spatially-Gridded Methane Emissions in the Barnett Shale

    Science.gov (United States)

    Lyon, D. R.; Zavala Araiza, D.; Alvarez, R.; Harriss, R. C.; Palacios, V.; Lan, X.; Talbot, R. W.; Shepson, P. B.; Lavoie, T. N.; Yacovitch, T. I.; Herndon, S. C.; Marchese, A.; Zimmerle, D.; Robinson, A. L.; Hamburg, S.

    2015-12-01

    In October 2013, a dozen research teams measured methane emissions from oil and gas (O&G) and other sources in the Barnett Shale region of Texas at multiple scales ranging from bottom-up component measurements to top-down regional emission measurements. This work integrates ground- and aircraft-based measurements of site-level emissions from the campaign and a recent national study of gathering and processing facilities to construct a spatially resolved emission inventory for the Barnett Shale. Spatially referenced activity data including O&G site locations were obtained from multiple databases. O&G site emission factors were estimated with two-step Monte Carlo simulations that integrated emission rates from unbiased datasets with higher measurements obtained with targeted sampling. Emissions from other fossil and biogenic sources were estimated from reported emissions data or published emission factors. We constructed a 4 km x 4 km gridded emission inventory to estimate emissions by source category in the 25-county Barnett region. Total methane emissions in October 2013 were estimated to be 72.3 (+10.1/-8.9) Mg CH4 h-1 with 46.2 (+7.9/-6.2) from O&G sources. Fat-tail sites, which were defined as emission rates above the unbiased sampling distributions, accounted for 19% of O&G emissions but less than 2% of sites. In comparison to alternative estimates of O&G emissions based on the United States Environmental Protection Agency Greenhouse Gas Inventory, EPA Greenhouse Gas Reporting Program, and Emissions Database for Global Atmospheric Research, our custom inventory was higher by factors of 1.5, 2.7, and 4.3, respectively, similar to published ratios of top-down and bottom up estimates. Our custom inventory was higher than alternatives primarily due to more complete activity data and the inclusion of fat-tail site emissions. Gathering facilities, which accounted for 40% of our O&G emission estimate, had the largest difference from alternative inventories.

  17. Production and disposal of waste materials from gas and oil extraction from the Marcellus Shale Play in Pennsylvania

    Science.gov (United States)

    Maloney, Kelly O.; Yoxtheimer, David A.

    2012-01-01

    The increasing world demand for energy has led to an increase in the exploration and extraction of natural gas, condensate, and oil from unconventional organic-rich shale plays. However, little is known about the quantity, transport, and disposal method of wastes produced during the extraction process. We examined the quantity of waste produced by gas extraction activities from the Marcellus Shale play in Pennsylvania for 2011. The main types of wastes included drilling cuttings and fluids from vertical and horizontal drilling and fluids generated from hydraulic fracturing [i.e., flowback and brine (formation) water]. Most reported drill cuttings (98.4%) were disposed of in landfills, and there was a high amount of interstate (49.2%) and interbasin (36.7%) transport. Drilling fluids were largely reused (70.7%), with little interstate (8.5%) and interbasin (5.8%) transport. Reported flowback water was mostly reused (89.8%) or disposed of in brine or industrial waste treatment plants (8.0%) and largely remained within Pennsylvania (interstate transport was 3.1%) with little interbasin transport (2.9%). Brine water was most often reused (55.7%), followed by disposal in injection wells (26.6%), and then disposed of in brine or industrial waste treatment plants (13.8%). Of the major types of fluid waste, brine water was most often transported to other states (28.2%) and to other basins (9.8%). In 2011, 71.5% of the reported brine water, drilling fluids, and flowback was recycled: 73.1% in the first half and 69.7% in the second half of 2011. Disposal of waste to municipal sewage treatment plants decreased nearly 100% from the first half to second half of 2011. When standardized against the total amount of gas produced, all reported wastes, except flowback sands, were less in the second half than the first half of 2011. Disposal of wastes into injection disposal wells increased 129.2% from the first half to the second half of 2011; other disposal methods decreased. Some

  18. The application of microbial combination flooding oil recovery technology in heavy oil reservoir with low temperature

    Science.gov (United States)

    Li, Yongbin; Wang, Jing; Wang, Yanjun; Ju, Dengfeng; Fu, Yaxiu; Lei, Xiaoyang; Jing, Jizhe; Liu, Guiying

    2017-04-01

    HuabeiBaolige Oilfield belongs to the common heavy oil reservoirs with low temperature, which were tapped by the conventional waterflooding. The formation temperature of Baolige Oilfield is 38~58°C, and the oil viscosity of reservoir is 13.7~2000mPa•s. Thanks to the high oil-water viscosity ratio and strong heterogeneity, the small waterflooding swept volume and serious water breakthrough are caused by waterflooding fingering, causing that the workable reserve cannot be used efficiently during the oilfield development. According to the characteristic that the environment of the reservoirs is fit for the growth and reproduction of microorganism, the microbial enhanced oil recovery (MEOR) technology is used to improve oilfield development status. On the basis of continuous and further studies of MEOR, the industrialized application of MEOR has been fulfilled. By the continuous and further study, the efficient system of the combination flooding technology with oil displacement microbial fields was formed, and MEOR technologies have been enriched. All the above researches could provide technical ideas for the comprehensive treatment for similar blocks.

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

    Energy Technology Data Exchange (ETDEWEB)

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

    1995-12-31

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

  20. Microfluidic Study of Foams Flow for Enhanced Oil Recovery (EOR

    Directory of Open Access Journals (Sweden)

    Quennouz N.

    2014-05-01

    Full Text Available In this paper, we report an experimental study of foam flow in different channel geometries using microfluidic devices in the framework of Enhanced Oil Recovery (EOR. Two different processes of foam formation are studied. The first corresponds to co-injection of gas and water through a cross junction which gives rise to a monodisperse foam. The second one corresponds to the fragmentation of large bubbles by a porous media, a foam formation process simulating multiphase flows in rocks. The foam formation is completely controlled and characterized varying both the water and gas pressure applied. We also use a microdevice with two permeabilities that permits to highlight the diversion of the continuous phase in the low permeability channels. The observations are important for a better understanding of the implied phenomena in EOR as well as to determine pertinent data to feed flow simulators.

  1. Bitumen recovery from surface mined oil sands recycle water ponds

    Energy Technology Data Exchange (ETDEWEB)

    Mikula, R.J.; Munoz, V.A.; Elliott, G. L. [Natural Resources Canada, CanmetENERGY, Devon, Alberta (Canada)

    2011-07-01

    In surface mined oil sands, high bitumen recovery can be achieved but tailings have accumulated over the years. Several technologies have been proposed for recovering bitumen from tailings, but because this bitumen carries high surfactant concentrations there have been processing problems. This paper presents the application of oxidized ore characterization and processing methods to process tailings pond bitumen. Laboratory tests were carried out to characterize bitumen samples coming from four different tailings sources and tests were run with caustic additive. Results showed that high caustic additions can be applied to surfactant rich tailings pond bitumen to avoid downstream froth treatment emulsion problems; the oxidation degree should be carefully monitored. This study demonstrated that the use of caustic additive, already used for oxidized ores, can be applied to treat the bitumen recovered from tailings streams.

  2. Flow behavior of N2 huff and puff process for enhanced oil recovery in tight oil reservoirs.

    Science.gov (United States)

    Lu, Teng; Li, Zhaomin; Li, Jian; Hou, Dawei; Zhang, Dingyong

    2017-11-16

    In the present work, the potential of N2 huff and puff process to enhance the recovery of tight oil reservoir was evaluated. N2 huff and puff experiments were performed in micromodels and cores to investigate the flow behaviors of different cycles. The results showed that, in the first cycle, N2 was dispersed in the oil, forming the foamy oil flow. In the second cycle, the dispersed gas bubbles gradually coalesced into the continuous gas phase. In the third cycle, N2 was produced in the form of continuous gas phase. The results from the coreflood tests showed that, the primary recovery was only 5.32%, while the recoveries for the three N2 huff and puff cycles were 15.1%, 8.53% and 3.22%, respectively.The recovery and the pressure gradient in the first cycle were high. With the increase of huff and puff cycles, and the oil recovery and the pressure gradient rapidly decreased. The oil recovery of N2 huff and puff has been found to increase as the N2 injection pressure and the soaking time increased. These results showed that, the properly designed and controlled N2 huff and puff process can lead to enhanced recovery of tight oil reservoirs.

  3. Polymers for enhanced oil recovery: fundamentals and selection criteria.

    Science.gov (United States)

    Rellegadla, Sandeep; Prajapat, Ganshyam; Agrawal, Akhil

    2017-06-01

    With a rising population, the demand for energy has increased over the years. As per the projections, both fossil fuel and renewables will remain as major energy source (678 quadrillion BTU) till 2030 with fossil fuel contributing 78% of total energy consumption. Hence, attempts are continuously made to make fossil fuel production more sustainable and cheaper. From the past 40 years, polymer flooding has been carried out in marginal oil fields and have proved to be successful in many cases. The common expectation from polymer flooding is to obtain 50% ultimate recovery with 15 to 20% incremental recovery over secondary water flooding. Both naturally derived polymers like xanthan gum and synthetic polymers like partially hydrolyzed polyacrylamide (HPAM) have been used for this purpose. Earlier laboratory and field trials revealed that salinity and temperature are the major issues with the synthetic polymers that lead to polymer degradation and adsorption on the rock surface. Microbial degradation and concentration are major issues with naturally derived polymers leading to loss of viscosity and pore throat plugging. Earlier studies also revealed that polymer flooding is successful in the fields where oil viscosity is quite higher (up to 126 cp) than injection water due to improvement in mobility ratio during polymer flooding. The largest successful polymer flood was reported in China in 1990 where both synthetic and naturally derived polymers were used in nearly 20 projects. The implementation of these projects provides valuable suggestions for further improving the available processes in future. This paper examines the selection criteria of polymer, field characteristics that support polymer floods and recommendation to design a large producing polymer flooding.

  4. Laboratory investigation of novel oil recovery method for carbonate reservoirs

    Energy Technology Data Exchange (ETDEWEB)

    Yousef, A.A.; Al-Saleh, S.; Al-Kaabi, A.; Al-Jawfi, M. [Saudi Aramco, Riyadh (Saudi Arabia)

    2010-07-01

    This paper described a core flooding laboratory study conducted using composite rock samples from a carbonate reservoir. The aim of the study was to investigate the impact of salinity and ionic composition on oil, brine and rock interactions. Experimental parameters and procedures were designed to replicate reservoir conditions and current field injection practices. Results of the study demonstrated that alterations in the salinity and ionic composition of injected water can have a significant impact on the wettability of the rock surface. Nuclear magnetic resonance (NMR) studies confirmed that injecting different salinity slugs of seawater in carbonate core samples can cause a significant alteration in the surface charges of the rock, and lead to increased interactions with water molecules. The constant reduction of pressure drop across the composite cores with the injection of different diluted versions of water also provided proof of brine, oil and rock alterations. Results of the study indicated that the driving mechanism for waterflooding recovery processes is wettability alteration, which can be triggered by alterations in carbonate rock surface charges, and improvements in the connectivity between rock pore systems that coexist in carbonate rock samples. 41 refs., 8 tabs., 16 figs.

  5. Sensitive clay sands respond to chemical oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Nugent, G.E.; Bessenyei, Z.; Sloat, B.

    1975-11-01

    The Almy sands in the Green River Basin of northwest Wyoming contain water sensitive clays. To promote clay stabilization of the injection well bores, a long term potassium chloride soak of a week or more with a 5 percent solution and a follow-up treatment of phosphate and surfactant to coat clay surfaces was used. This stabilization treatment was followed by a slug of high molecular weight polyacrylamides, which gave a continued degree of clay stabilization by effectively insulating the clay surfaces from contact with the injection water. The nonionic polyacrylamides (10 percent anionic charge) were also used to improve volumetric sweep by permeability unification of the sand reservoirs. Following the permeability unification stage, a wettability adjustment was initiated to flood the tighter zones and promote inhibition. This flood of phosphates in the presence of very low concentrations of acrylamide was continued for the balance of flood life. The projected oil recovery efficiency of the above treatment was about 50 percent, while waterflood projects in the same area were only expected to reach 30 percent before water-oil ratios become uneconomic. A microemulsion flooding project is currently being planned for this area. It will include a brine preflush and micellar solution made up of petroleum sulfonate, phosphates, and polymer. The drive solution will be polyacrylamide.

  6. Influence of the experimental conditions on porosity and structure of adsorbents elaborated from Moroccan oil shale of Timahdit by chemical activation.

    Science.gov (United States)

    Ichcho, S; Khouya, E; Fakhi, S; Ezzine, M; Hannache, H; Pallier, R; Naslain, R

    2005-02-14

    This study records experiments undertaken to determine the suitable conditions for the use of the oil shale of Timahdit, as an adsorbent for water treatment. A simple process was proposed based on chemical activation. The preparation has been carried out by carbonization after impregnation of the precursor with phosphoric acid. The effect of different conditions of preparation on the specific surface area is discussed. These parameters are H3PO4/shale weight ratio, carbonization temperature, carbonization time and concentration of H3PO4. The properties and surface structure of the adsorbent were investigated by XPS and FT-IR. Their total surface acidity and basicity were also determined. The retention process of methylene blue (MB) by adsorbents has been studied. It was found that MHP2 and MHP7 have relatively high retention ability as compared to activated carbons.

  7. A study on the oil-based drilling cutting pyrolysis residue resource utilization by the exploration and development of shale gas.

    Science.gov (United States)

    Wang, Chao-Qiang; Jin, Ji-Zhong; Lin, Xiao-Yan; Xiong, De-Ming; Mei, Xu-Dong

    2017-07-01

    Based on the requirement of national energy conservation and environmental protection, attention has been given to building an environment-friendly and resource-saving society. Shale gas oil-based drilling cutting pyrolysis residues (ODPRs) have been used as the main research object to developing new technology which can convert the residues into a harmless and recyclable material. Using the test data of ODPR, we analyze the development prospect in the building material industry and provide a scheme to utilize this particular solid-waste efficiently. Theoretically speaking, the ODPR resource utilization such as admixture of cement, making sintered brick, and non-fired brick, by the exploration and development of Fuling shale gas is feasible.

  8. Evaluation of using Smart Water to enhance oil recovery from Norwegian Continental Shelf sandstone reservoirs.

    OpenAIRE

    Piotrowska, Natalia

    2016-01-01

    Master's thesis in Petroleum engineering. Recently, the scale of studies on smart water – one of EOR method - has increased. From decades, water flooding is one of the most used methods to increase oil recovery. However, more effective in sandstone reservoirs is injecting low salinity brine. Due to changing wettability, improved oil mobility in pores can be reached. The studies show, that the significant increase of oil recovery might be achieved. Main objective of the thesis is to answ...

  9. Alkyl polyglycoside/1-naphthol formulations. A case study of surfactant enhanced oil recovery

    Energy Technology Data Exchange (ETDEWEB)

    Iglauer, Stefan; Wu, Yongfu; Shuler, Patrick; Tang, Yongchun [California Institute of Technology, Covina, CA (United States). Div. of Chemistry and Chemical Engineering; Goddard, William A. III [California Institute of Technology, Pasadena, CA (United States). Div. of Chemistry and Chemical Engineering

    2011-03-15

    We present a case study of surfactant enhanced oil recovery using Alkyl polyglucoside/1-naphthol formulations. Alkyl polyglucosides are a green, non-toxic and renewable surfactant class synthesized out of agricultural raw materials. We measured interfacial tensions versus n-octane and viscosities of these formulations and conducted one coreflood enhanced oil recovery (EOR) experiment where we recovered 82.6 % of initial oil in place demonstrating that these formulations are efficient EOR agents. (orig.)

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

    Energy Technology Data Exchange (ETDEWEB)

    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).

  11. A Sugar-Based Gelator for Marine Oil-Spill Recovery.

    Science.gov (United States)

    Vibhute, Amol M; Muvvala, Venkatanarayana; Sureshan, Kana M

    2016-06-27

    Marine oil spills constitute an environmental disaster with severe adverse effects on the economy and ecosystem. Phase-selective organogelators (PSOGs), molecules that can congeal oil selectively from oil-water mixtures, have been proposed to be useful for oil-spill recovery. However, a major drawback lies in the mode of application of the PSOG to an oil spill spread over a large area. The proposed method of using carrier solvents is impractical for various reasons. Direct application of the PSOG as a solid, although it would be ideal, is unknown, presumably owing to poor dispersion of the solid through the oil. We have designed five cheap and easy-to-make glucose-derived PSOGs that disperse in the oil phase uniformly when applied as a fine powder. These gelators were shown to selectively congeal many oils, including crude oil, from oil-water mixtures to form stable gels, which is an essential property for efficient oil-spill recovery. We have demonstrated that these PSOGs can be applied aerially as a solid powder onto a mixture of crude oil and sea water and the congealed oil can then be scooped out. Our innovative mode of application and low cost of the PSOG offers a practical solution to oil-spill recovery. © 2016 WILEY-VCH Verlag GmbH & Co. KGaA, Weinheim.

  12. 26 CFR 1.43-4 - Qualified enhanced oil recovery costs.

    Science.gov (United States)

    2010-04-01

    ... injectant expense that is a qualified enhanced oil recovery cost. The storage tanks X acquires to store the... storage tanks that Z will use solely to store the crude oil that is produced from the enhanced oil... steam to be injected in connection with the cyclic steam project, and purchases storage tanks to store...

  13. 26 CFR 1.43-1 - The enhanced oil recovery credit-general rules.

    Science.gov (United States)

    2010-04-01

    ... mineral interest in a property, incurs $100 of qualified enhanced oil recovery costs. The reference price.... E's credit for 1992 determined without regard to the phase-out for crude oil price increases is $15... determined without regard to the phase-out for crude oil price increases is $15 ($100 × 15%). In determining...

  14. Surfactant Based Enhanced Oil Recovery and Foam Mobility Control

    Energy Technology Data Exchange (ETDEWEB)

    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

  15. Effects of smectite on the oil-expulsion efficiency of the Kreyenhagen Shale, San Joaquin Basin, California, based on hydrous-pyrolysis experiments

    Science.gov (United States)

    Lewan, Michael D.; Dolan, Michael P.; Curtis, John B.

    2014-01-01

    The amount of oil that maturing source rocks expel is expressed as their expulsion efficiency, which is usually stated in milligrams of expelled oil per gram of original total organic carbon (TOCO). Oil-expulsion efficiency can be determined by heating thermally immature source rocks in the presence of liquid water (i.e., hydrous pyrolysis) at temperatures between 350°C and 365°C for 72 hr. This pyrolysis method generates oil that is compositionally similar to natural crude oil and expels it by processes operative in the subsurface. Consequently, hydrous pyrolysis provides a means to determine oil-expulsion efficiencies and the rock properties that influence them. Smectite in source rocks has previously been considered to promote oil generation and expulsion and is the focus of this hydrous-pyrolysis study involving a representative sample of smectite-rich source rock from the Eocene Kreyenhagen Shale in the San Joaquin Basin of California. Smectite is the major clay mineral (31 wt. %) in this thermally immature sample, which contains 9.4 wt. % total organic carbon (TOC) comprised of type II kerogen. Compared to other immature source rocks that lack smectite as their major clay mineral, the expulsion efficiency of the Kreyenhagen Shale was significantly lower. The expulsion efficiency of the Kreyenhagen whole rock was reduced 88% compared to that of its isolated kerogen. This significant reduction is attributed to bitumen impregnating the smectite interlayers in addition to the rock matrix. Within the interlayers, much of the bitumen is converted to pyrobitumen through crosslinking instead of oil through thermal cracking. As a result, smectite does not promote oil generation but inhibits it. Bitumen impregnation of the rock matrix and smectite interlayers results in the rock pore system changing from water wet to bitumen wet. This change prevents potassium ion (K+) transfer and dissolution and precipitation reactions needed for the conversion of smectite to

  16. Developments in production of synthetic fuels out of Estonian shale

    Energy Technology Data Exchange (ETDEWEB)

    Aarna, Indrek

    2010-09-15

    Estonia is still the world leader in utilization of oil shale. Enefit has cooperated with Outotec to develop a new generation of solid heat carrier technology - Enefit280, which is more efficient, environmentally friendlier and has higher unit capacity. Breakeven price of oil produced in Enefit280 process is competitive with conventional oils. The new technology has advantages that allow easy adaptation to other oil shales around the world. Hydrotreated shale oil liquids have similar properties to crude oil cuts. Design for a shale oil hydrotreater unit can use process concepts, hardware components, and catalysts commercially proven in petroleum refining services.

  17. Impacts on oil recovery from capillary pressure and capillary heterogeneities

    Energy Technology Data Exchange (ETDEWEB)

    Bognoe, Thomas

    2008-07-01

    The main conclusions drawn from this thesis are; 7 scientific papers are published on a broad variety of subjects, and describes in detail the experiments and research treated in this thesis. Scientific research has been performed, investigating the subjects of capillary pressure and capillary heterogeneities from different angles. This thesis discusses the findings in this study and aims to illustrate the benefits of the results obtained for further development of other experiments, and/or even the industrial benefits in field development. The methods for wettability alteration have developed throughout the work. From producing heterogeneous wettability alterations, the methods have improved to giving both radial and lateral uniform wettability alterations, which also remains unaltered throughout the duration of the experimental work. The alteration of wettability is dependent on initial water saturation, flow rate, aging time and crude oil composition. Capillary pressure and relative permeability curves have been measured for core plugs at different wettabilities using conventional centrifuge methods. The trends observed are mostly consistent with theory. The production mechanisms of strongly and moderately water wet chalk has been investigated. At strongly water wet conditions in fractured chalk; the flow is governed by capillary forces, showing strong impact from the fractures. At moderately water wet conditions, the impact of the fractures are absent, and a dispersed water front is observed during the displacement. The oil recovery is about the same, at the two wettabilities. Fracture crossing mechanisms at the same wettability conditions have been mapped. And the observations are consistent with those of the water floods. During strongly water wet displacement, the fracture crossing is occurring once the inlet core has reached endpoint of spontaneous imbibition. At moderately water wet conditions the fracture crossing is less abrupt, and creation of wetting

  18. Oil recovery in the presence of microbubbles in the filtration flow

    Science.gov (United States)

    Mikhailov, D. N.

    2012-05-01

    This paper presents mathematical models for oil-gas flow taking into account the various processes due to the formation of gas micronuclei (microbubbles) in oil: slip of oil relative to the walls of the pore channels (gas lubrication), changes in oil viscosity, and motion of microbubles with respect to oil. We consider examples of oil flow in the near-wellbore zone for the case where a reduction in pressure to the saturation pressure leads to the formation of gas microbubbles and micronuclei and examples of the action of a water-gas mixture in the case where oil foams in the contact area with the injected gas, i.e., a finely dispersed mixture of oil and microbubbles is formed. The behavior of indicator curves for an oil well with the formation of microbubbles is simulated, and the effect of microbubbles on the oil recovery factor in a water-alternating-gas injection process is studied.

  19. Long-term modelling of fly ash and radionuclide emissions as well as deposition fluxes due to the operation of large oil shale-fired power plants.

    Science.gov (United States)

    Vaasma, Taavi; Kaasik, Marko; Loosaar, Jüri; Kiisk, Madis; Tkaczyk, Alan H

    2017-11-01

    Two of the world's largest oil shale-fired power plants (PPs) in Estonia have been operational over 40 years, emitting various pollutants, such as fly ash, SOx, NOx, heavy metals, volatile organic compounds as well as radionuclides to the environment. The emissions from these PPs have varied significantly during this period, with the maximum during the 1970s and 1980s. The oil shale burned in the PPs contains naturally occurring radionuclides from the (238)U and (232)Th decay series as well as (40)K. These radionuclides become enriched in fly ash fractions (up to 10 times), especially in the fine fly ash escaping the purification system. Using a validated Gaussian-plume model, atmospheric dispersion modelling was carried out to determine the quantity and a real magnitude of fly ash and radionuclide deposition fluxes during different decades. The maximum deposition fluxes of volatile radionuclides ((210)Pb and (210)Po) were around 70 mBq m(-2) d(-1) nearby the PPs during 1970s and 1980s. Due to the reduction of burned oil shale and significant renovations done on the PPs, the deposition fluxes were reduced to 10 mBq m(-2) d(-1) in the 2000s and down to 1.5 mBq m(-2) d(-1) in 2015. The maximum deposition occurs within couple of kilometers of the PPs, but the impacted area extends to over 50 km from the sources. For many radionuclides, including (210)Po, the PPs have been larger contributors of radionuclides to the environment via atmospheric pathway than natural sources. This is the first time that the emissions and deposition fluxes of radionuclides from the PPs have been quantified, providing the information about their radionuclide deposition load on the surrounding environment during various time periods. Copyright © 2017 Elsevier Ltd. All rights reserved.

  20. Coal and oil shale of Early Carboniferous age in northern Canada - significance for paleoenvironmental and paleoclimatic interpretations. [Canada - Northwest Territories and Yukon Territory

    Energy Technology Data Exchange (ETDEWEB)

    Cameron, A.R.; Goodarzi, F.; Potter, J. (Geological Survey of Canada, Calgary, AB (Canada))

    1994-01-01

    Lower Carboniferous (Mississippian) coal beds and oil shale occur at several locations in northern Canada. In the northern Yukon Territory coal of semi-anthracite/anthracite rank occurs in the Kayak Formation in the British Mountains and at Hoidahl Dome near the headwaters of Blow River. Farther south in the Liard Basin, Northwest Territories, coals of high volatile bituminous rank occur in the Mattson Formation. In the Arctic Islands thicker beds of the Emma Fiord Formation, the oldest unit in the Sverdrup Basin, contain thin coal seams and oil shale on Devon Island, near the southern edge of the basin and on Axel Heiberg and Ellesmere islands on the north side of the basin. Organic matter in the Devon Island section is at a low maturity level (R[sub o, max] % 0.26-0.50), whereas that from Ellesmere and Axel Heiberg has reached the level of meta-anthracite. Depositional environments for these carbonaceous sediments were different. The coal-bearing Kayak strata accumulated in a coastal plain setting overlain transgressively by younger marine beds. The Mattson coal beds appear to have formed in a prograding delta, but coal and oil shale in the Emma Ford were deposited in lacustrine environments in a rift basin. These Canadian occurrences resemble penecontemporaneous deposits in Svalbard and elsewhere, adjacent to the present-day Arctic Ocean. They formed at low latitudes where conditions were favourable for the preservation of carbonaceous matter. Prior to the opening of the Arctic Ocean basin in Mesozoic times, sites on the mainland were undoubtedly closer to sites in the Arctic Islands than they are today.

  1. Salinity of injection water and its impact on oil recovery absolute permeability, residual oil saturation, interfacial tension and capillary pressure

    Directory of Open Access Journals (Sweden)

    Mehdi Mohammad Salehi

    2017-06-01

    This paper presents laboratory investigation of the effect of salinity injection water on oil recovery, pressure drop, permeability, IFT and relative permeability in water flooding process. The experiments were conducted at the 80 °C and a net overburden pressure of 1700 psi using core sample. The results of this study have been shown oil recovery increases as the injected water salinity up to 200,000 ppm and appointment optimum salinity. This increase has been found to be supported by a decrease in the IFT. This effect caused a reduction in capillary pressure increasing the tendency to reduce the residual oil saturation.

  2. Application of decline curve analysis to estimate recovery factors for carbon dioxide enhanced oil recovery

    Science.gov (United States)

    Jahediesfanjani, Hossein

    2017-07-17

    IntroductionIn the decline curve analysis (DCA) method of estimating recoverable hydrocarbon volumes, the analyst uses historical production data from a well, lease, group of wells (or pattern), or reservoir and plots production rates against time or cumu­lative production for the analysis. The DCA of an individual well is founded on the same basis as the fluid-flow principles that are used for pressure-transient analysis of a single well in a reservoir domain and therefore can provide scientifically reasonable and accurate results. However, when used for a group of wells, a lease, or a reservoir, the DCA becomes more of an empirical method. Plots from the DCA reflect the reservoir response to the oil withdrawal (or production) under the prevailing operating and reservoir conditions, and they continue to be good tools for estimating recoverable hydrocarbon volumes and future production rates. For predicting the total recov­erable hydrocarbon volume, the DCA results can help the analyst to evaluate the reservoir performance under any of the three phases of reservoir productive life—primary, secondary (waterflood), or tertiary (enhanced oil recovery) phases—so long as the historical production data are sufficient to establish decline trends at the end of the three phases.

  3. Quantification of oil recovery efficiency, CO 2 storage potential, and fluid-rock interactions by CWI in heterogeneous sandstone oil reservoirs

    DEFF Research Database (Denmark)

    Seyyedi, Mojtaba; Sohrabi, Mehran; Sisson, Adam

    2017-01-01

    Significant interest exists in improving recovery from oil reservoirs while addressing concerns about increasing CO2 concentrations in the atmosphere. The combination of Enhanced Oil Recovery (EOR) and safe geologic storage of CO2 in oil reservoirs is appealing and can be achieved by carbonated (...... for oil recovery and CO2 storage potential on heterogeneous cores. Since not all the oil reservoirs are homogenous, understanding the potential of CWI as an integrated EOR and CO2 storage scenario in heterogeneous oil reservoirs is essential.......Significant interest exists in improving recovery from oil reservoirs while addressing concerns about increasing CO2 concentrations in the atmosphere. The combination of Enhanced Oil Recovery (EOR) and safe geologic storage of CO2 in oil reservoirs is appealing and can be achieved by carbonated (CO...

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

    Energy Technology Data Exchange (ETDEWEB)

    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 fracture