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Tayfun Babadagli - One of the best experts on this subject based on the ideXlab platform.
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An enhanced Oil recovery technology as a follow up to cold Heavy Oil Production with sand
Journal of Petroleum Science and Engineering, 2015Co-Authors: Goekhan Coskuner, Khosrow Naderi, Tayfun BabadagliAbstract:Abstract Lloydminster area that straddles Alberta and Saskatchewan border contains vast amounts of Heavy Oil deposits in thin unconsolidated formations. Cold Heavy Oil Production with Sand (CHOPS) has been successfully implemented in these reservoirs. However, primary recovery is still low averaging below 10%. How to economically recover the large amount of remaining Oil in place is a challenge. Therefore, an effective follow up recovery process is required. Steam injection technologies cannot be widely applied because most of the Lloydminster Heavy Oil reservoirs are thin and the heat losses to overburden and underburden make the process uneconomic. Alternative solvent methods are not commercial yet due to uncertain Oil recovery rates and low solvent recovery. Hybrid application of the aforementioned two technologies using hot water together with solvents could be an economic post-CHOPS recovery process. The wormholes created during the primary recovery can be used to contact large reservoir volumes with hot water and solvent. This paper contains the results of hot water and solvent Oil recovery experiments conducted in preserved Heavy Oil cores. Experimental work consisted of three phases. Cores were immersed in hot water in the first phase to pre-heat the formation. Next, cores were exposed to n-heptane as hydrocarbon solvent. Finally, cores were immersed in hot water again to recover the Oil as well as the solvent. The ultimate Oil recoveries varied between 42% and 88% OOIP and, the asphaltene precipitation varied between 2.5 wt% and 11.7 wt%. Experiments were also carried out with a distillate from Husky’s Lloydminster upgrader used for Heavy Oil transportation in the pipelines. Better results were obtained if the distillate was used instead of the pure hydrocarbon solvent. It was observed that Oil recovery at the end of the initial hot water injection phase due to thermal expansion and viscosity reduction was negligible compared to the ultimate recovery. However, the first phase serves to condition the reservoir for better diffusion in the second phase when the solvent is injected. The final phase of hot water injection causes the water to strongly imbibe into the matrix enhancing the Oil and the solvent recovery.
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Multi-stage hydraulic fracturing and radio-frequency electromagnetic radiation for Heavy-Oil Production
Journal of Unconventional Oil and Gas Resources, 2015Co-Authors: Alfred Davletbaev, L. A. Kovaleva, N. M. Nasyrov, Tayfun BabadagliAbstract:Abstract Numerical model results of Heavy Oil Production through multi-stage radio-frequency electromagnetic (RF EM) heating from a well after fracturing and re-fracturing operations are given in this paper. We consider the inflow of Heavy Oil to the well through two perpendicular fractures filled with propping agent. The conductivity of fractures is substantially greater than the conductivity of the reservoir but the dielectric and thermal properties of the reservoir and fractures are considered identical. In the expression used for heat distribution, a correction for near-field is introduced, which is shown to improve the accuracy of the temperature distribution around the well. The calculations for different powers of EM emitters and length of fractures are also considered and compared to the base case (cold Oil) Production.
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Heavy Oil Production by Electromagnetic Heating in Hydraulically Fractured Wells
Energy & Fuels, 2014Co-Authors: Alfred Davletbaev, L. A. Kovaleva, Tayfun BabadagliAbstract:The results of numerical studies of Heavy Oil Production by radio frequency–electromagnetic heating (RF–EM) from hydraulically fractured low-permeability reservoirs are presented. The fluid flow to a single vertical high-conductivity fracture is considered assuming that electrical and thermal properties of the reservoir rock and fluid-saturated fracture are the same. Comparative analysis is performed for the cases of Heavy Oil recovery by RF–EM radiation with hydraulic fracturing and “cold” Production. Modeling of the combined multi-stage method and economic analysis for different RF–EM generator powers, differential pressure between the well and formation, and the fracture conductivity showed that the method is most effective for wells with “short” and low-conductivity hydraulic fractures.
Alfred Davletbaev - One of the best experts on this subject based on the ideXlab platform.
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Cold Heavy Oil Production and Production by radio-frequency electromagnetic radiation: Comparative numerical study
2016Co-Authors: Alfred Davletbaev, Victor Kireev, L. A. Kovaleva, Aleksey Zainullin, Rais MinnigalimovAbstract:Comparative analysis for “cold” Heavy Oil Production from fractured well in low-permeability formation, as well as Heavy Oil Production by radio-frequency electromagnetic heating has been carried out. The results of mathematical modeling for both these technologies taking into account different fracture’s lengths show that the thermal method is most effective for more “short” fractures up to some their optimal size 5-10 m.
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Multi-stage hydraulic fracturing and radio-frequency electromagnetic radiation for Heavy-Oil Production
Journal of Unconventional Oil and Gas Resources, 2015Co-Authors: Alfred Davletbaev, L. A. Kovaleva, N. M. Nasyrov, Tayfun BabadagliAbstract:Abstract Numerical model results of Heavy Oil Production through multi-stage radio-frequency electromagnetic (RF EM) heating from a well after fracturing and re-fracturing operations are given in this paper. We consider the inflow of Heavy Oil to the well through two perpendicular fractures filled with propping agent. The conductivity of fractures is substantially greater than the conductivity of the reservoir but the dielectric and thermal properties of the reservoir and fractures are considered identical. In the expression used for heat distribution, a correction for near-field is introduced, which is shown to improve the accuracy of the temperature distribution around the well. The calculations for different powers of EM emitters and length of fractures are also considered and compared to the base case (cold Oil) Production.
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Heavy Oil Production by Electromagnetic Heating in Hydraulically Fractured Wells
Energy & Fuels, 2014Co-Authors: Alfred Davletbaev, L. A. Kovaleva, Tayfun BabadagliAbstract:The results of numerical studies of Heavy Oil Production by radio frequency–electromagnetic heating (RF–EM) from hydraulically fractured low-permeability reservoirs are presented. The fluid flow to a single vertical high-conductivity fracture is considered assuming that electrical and thermal properties of the reservoir rock and fluid-saturated fracture are the same. Comparative analysis is performed for the cases of Heavy Oil recovery by RF–EM radiation with hydraulic fracturing and “cold” Production. Modeling of the combined multi-stage method and economic analysis for different RF–EM generator powers, differential pressure between the well and formation, and the fracture conductivity showed that the method is most effective for wells with “short” and low-conductivity hydraulic fractures.
L. A. Kovaleva - One of the best experts on this subject based on the ideXlab platform.
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Cold Heavy Oil Production and Production by radio-frequency electromagnetic radiation: Comparative numerical study
2016Co-Authors: Alfred Davletbaev, Victor Kireev, L. A. Kovaleva, Aleksey Zainullin, Rais MinnigalimovAbstract:Comparative analysis for “cold” Heavy Oil Production from fractured well in low-permeability formation, as well as Heavy Oil Production by radio-frequency electromagnetic heating has been carried out. The results of mathematical modeling for both these technologies taking into account different fracture’s lengths show that the thermal method is most effective for more “short” fractures up to some their optimal size 5-10 m.
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Multi-stage hydraulic fracturing and radio-frequency electromagnetic radiation for Heavy-Oil Production
Journal of Unconventional Oil and Gas Resources, 2015Co-Authors: Alfred Davletbaev, L. A. Kovaleva, N. M. Nasyrov, Tayfun BabadagliAbstract:Abstract Numerical model results of Heavy Oil Production through multi-stage radio-frequency electromagnetic (RF EM) heating from a well after fracturing and re-fracturing operations are given in this paper. We consider the inflow of Heavy Oil to the well through two perpendicular fractures filled with propping agent. The conductivity of fractures is substantially greater than the conductivity of the reservoir but the dielectric and thermal properties of the reservoir and fractures are considered identical. In the expression used for heat distribution, a correction for near-field is introduced, which is shown to improve the accuracy of the temperature distribution around the well. The calculations for different powers of EM emitters and length of fractures are also considered and compared to the base case (cold Oil) Production.
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Heavy Oil Production by Electromagnetic Heating in Hydraulically Fractured Wells
Energy & Fuels, 2014Co-Authors: Alfred Davletbaev, L. A. Kovaleva, Tayfun BabadagliAbstract:The results of numerical studies of Heavy Oil Production by radio frequency–electromagnetic heating (RF–EM) from hydraulically fractured low-permeability reservoirs are presented. The fluid flow to a single vertical high-conductivity fracture is considered assuming that electrical and thermal properties of the reservoir rock and fluid-saturated fracture are the same. Comparative analysis is performed for the cases of Heavy Oil recovery by RF–EM radiation with hydraulic fracturing and “cold” Production. Modeling of the combined multi-stage method and economic analysis for different RF–EM generator powers, differential pressure between the well and formation, and the fracture conductivity showed that the method is most effective for wells with “short” and low-conductivity hydraulic fractures.
D. K. Olsen - One of the best experts on this subject based on the ideXlab platform.
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Heavy Oil Production from Alaska
1995Co-Authors: Syed Mohammad Mahmood, D. K. Olsen, C.p. ThomasAbstract:North Slope of Alaska has an estimated 40 billion barrels of Heavy Oil and bitumen in the shallow formations of West Sak and Ugnu. Recovering this resource economically is a technical challenge for two reasons: (1) the geophysical environment is unique, and (2) the expected recovery is a low percentage of the Oil in place. The optimum advanced recovery process is still undetermined. Thermal methods would be applicable if the risks of thawing the permafrost can be minimized and the enormous heat losses reduced. Use of enriched natural gas is a probable recovery process for West Sak. Nearby Prudhoe Bay field is using its huge natural gas resources for pressure maintenance and enriched gas improved Oil recovery (IOR). Use of carbon dioxide is unlikely because of dynamic miscibility problems. Major concerns for any IOR include close well spacing and its impact on the environment, asphaltene precipitation, sand Production, and fines migration, in addition to other more common Production problems. Studies have indicated that recovering West Sak and Lower Ugnu Heavy Oil is technically feasible, but its development has not been economically viable so far. Remoteness from markets and harsh Arctic climate increase Production costs relative to California Heavy Oil ormore » Central/South American Heavy crude delivered to the U.S. Gulf Coast. A positive change in any of the key economic factors could provide the impetus for future development. Cooperation between the federal government, state of Alaska, and industry on taxation, leasing, and permitting, and an aggressive support for development of technology to improve economics is needed for these Heavy Oil resources to be developed.« less
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State of Heavy Oil Production and refining in California
1995Co-Authors: D. K. Olsen, E.b. RamzelAbstract:California is unique in the United States because it has the largest Heavy Oil (10{degrees} to 20{degrees}API gravity) resource, estimated to be in excess of 40 billion barrels. Of the current 941,543 barrels/day of Oil produced in California (14% of the U.S. total), 70% or 625,312 barrels/day is Heavy Oil. Heavy Oil constituted only 20% of California`s Oil Production in the early 1940s, but development of thermal Oil Production technology in the 1960s allowed the Heavy industry to grow and prosper to the point where by the mid-1980s, Heavy Oil constituted 70% of the state`s Oil Production. Similar to the rest of the United States, light Oil Production in the Los Angeles Basin, Coastal Region, and San Joaquin Valley peaked and then declined at different times throughout the past 30 years. Unlike other states, California developed a Heavy Oil industry that replaced declining light Oil Production and increased the states total Oil Production, despite low Heavy Oil prices, stringent environmental regulations and long and costly delays in developing known Oil resources. California`s deep conversion refineries process the nation`s highest sulfur, lowest API gravity crude to make the cleanest transportation fuels available. More efficient vehicles burning cleaner reformulated fuels have significantlymore » reduced the level of ozone precursors (the main contributor to California`s air pollution) and have improved air quality over the last 20 years. In a state where major Oil companies dominate, the infrastructure is highly dependent on the 60% of ANS Production being refined in California, and California`s own Oil Production. When this Oil is combined with the small volume of imported crude, a local surplus of marketed Oil exists that inhibits exploitation of California`s Heavy Oil resources. As ANS Production declines, or if the export restrictions on ANS sales are lifted, a window of opportunity develops for increased Heavy Oil Production.« less
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Projections of the impact of expansion of domestic Heavy Oil Production on the U.S. refining industry from 1990 to 2010. Topical report
1994Co-Authors: D. K. Olsen, E.b. Ramzel, A.r. Strycker, G. Guariguata, F.g. SalmenAbstract:This report is one of a series of publications assessing the feasibility of increasing domestic Heavy Oil (10{degrees} to 20{degrees} API gravity) Production. This report provides a compendium of the United States refining industry and analyzes the industry by Petroleum Administration for Defense District (PADD) and by ten smaller refining areas. The refining capacity, Oil source and Oil quality are analyzed, and projections are made for the U.S. refining industry for the years 1990 to 2010. The study used publicly available data as background. A linear program model of the U.S. refining industry was constructed and validated using 1990 U.S. refinery performance. Projections of domestic Oil Production (decline) and import of crude Oil (increases) were balanced to meet anticipated demand to establish a base case for years 1990 through 2010. The impact of additional domestic Heavy Oil Production, (300 MB/D to 900 MB/D, originating in select areas of the U.S.) on the U.S. refining complex was evaluated. This Heavy Oil could reduce the import rate and the balance of payments by displacing some imported, principally Mid-east, medium crude. The construction cost for refining units to accommodate this additional domestic Heavy Oil Production in both the low and high volume scenarios more » is about 7 billion dollars for bottoms conversion capacity (delayed coking) with about 50% of the cost attributed to compliance with the Clean Air Act Amendment of 1990. « less
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Recent trends in Heavy Oil Production and refining in California
Preprints-American Chemical Society Division of Petroleum Chemistry, 1993Co-Authors: D. K. Olsen, E. B. Ramzel, R. A. PendergrassAbstract:Trends and limitations in Heavy Oil Production and refining in California. The objectives of this nationwide Heavy Oil feasibility study are : To investigate from secondary data the known Heavy Oil resources; to screen this resource for potential enhanced Oil recovery or other techniques and to evaluate constraints (Oil price, Production cost, transportation, environmental, etc.) that may impede the expansion of Heavy Oil Production
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Estimates of future regional Heavy Oil Production at three Production rates--background information for assessing effects in the US refining industry
1993Co-Authors: D. K. OlsenAbstract:This report is one of a series of publications from a project considering the feasibility of increasing domestic Heavy Oil (10{degree} to 20{degree} API gravity inclusive) Production being conducted for the US Department of Energy. The report includes projections of future Heavy Oil Production at three Production levels: 900,000; 500,000; and 300,000 BOPD above the current 1992 Heavy Oil Production level of 750,000 BOPD. These free market scenario projections include time frames and locations. Production projections through a second scenario were developed to examine which Heavy Oil areas would be developed if significant changes in the US petroleum industry occurred. The Production data helps to define the possible constraints (impact) of increased Heavy Oil Production on the US refining industry (the subject of a future report). Constraints include a low Oil price and low rate of return. Heavy Oil has high Production, transportation, and refining cost per barrel as compared to light Oil. The resource is known, but the right mix of technology and investment is required to bring about significant expansion of Heavy Oil Production in the US.
E. B. Ramzel - One of the best experts on this subject based on the ideXlab platform.
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Recent trends in Heavy Oil Production and refining in California
Preprints-American Chemical Society Division of Petroleum Chemistry, 1993Co-Authors: D. K. Olsen, E. B. Ramzel, R. A. PendergrassAbstract:Trends and limitations in Heavy Oil Production and refining in California. The objectives of this nationwide Heavy Oil feasibility study are : To investigate from secondary data the known Heavy Oil resources; to screen this resource for potential enhanced Oil recovery or other techniques and to evaluate constraints (Oil price, Production cost, transportation, environmental, etc.) that may impede the expansion of Heavy Oil Production
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Trends in Heavy Oil Production and refining in California
1992Co-Authors: D. K. Olsen, E. B. Ramzel, R. A. PendergrassAbstract:This report is one of a series of publications assessing the feasibility of increasing domestic Heavy Oil Production and is part of a study being conducted for the US Department of Energy. This report summarizes trends in Oil Production and refining in Canada. Heavy Oil (10{degrees} to 20{degrees} API gravity) Production in California has increased from 20% of the state's total Oil Production in the early 1940s to 70% in the late 1980s. In each of the three principal petroleum producing districts (Los Angeles Basin, Coastal Basin, and San Joaquin Valley) Oil Production has peaked then declined at different times throughout the past 30 years. Thermal Production of Heavy Oil has contributed to making California the largest producer of Oil by enhanced Oil recovery processes in spite of low Oil prices for Heavy Oil and stringent environmental regulation. Opening of Naval Petroleum Reserve No. 1, Elk Hills (CA) field in 1976, brought about a major new source of light Oil at a time when light Oil Production had greatly declined. Although California is a major petroleum-consuming state, in 1989 the state used 13.3 billion gallons of gasoline or 11.5% of US demand but it contributed substantially to the Nation's energymore » Production and refining capability. California is the recipient and refines most of Alaska's 1.7 million barrel per day Oil Production. With California Production, Alaskan Oil, and imports brought into California for refining, California has an excess of Oil and refined products and is a net exporter to other states. The local surplus of Oil inhibits exploitation of California Heavy Oil resources even though the Heavy Oil resources exist. Transportation, refining, and competition in the market limit full development of California Heavy Oil resources.« less
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Heavy Oil refining and transportation : effect on the feasibility of increasing domestic Heavy Oil Production
Fuel, 1992Co-Authors: D. K. Olsen, E. B. RamzelAbstract:Abstract As part of a programme to assess the feasibility of increasing domestic Heavy Oil Production from US reservoirs, a study of the crude Oil transportation system and petroleum refining industry has been initiated to determine their ability to accommodate additional domestic Heavy Oil. This paper summarizes refining trends and potential limitations in the Production/transportation/refining network that may influence the expansion of domestic Heavy Oil Production outside the current Heavy Oil producing areas. Although the number of refineries has decreased over the past decade, the remaining large refineries have been able to stabilize charge capacity and increase refinery throughput. A few refineries have been designed to economically process select Heavy Oils and obtain acceptable yields of products. However, refiners seek more light sweet crude Oil and less sour or Heavy crude to meet the requirements of clean fuels as mandated by the Clean Air Act Amendments of 1990. Transport of Heavy Oil poses significant problems in that there are limited heated pipelines, and transport of Heavy Oil to distant refineries adds to the cost of Heavy Oil Production. Addition of significantly more Heavy Oil, either domestic or imported, will substantially reduce refinery efficiency and throughput affecting yields and margins. This will not change without significant investment in refinery modification to be able to process Heavy Oil.