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Adel M. Elsharkawy - One of the best experts on this subject based on the ideXlab platform.
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Using RBF network to model the reservoir fluid behavior of black Oil systems
Developments in Petroleum Science, 2003Co-Authors: Adel M. ElsharkawyAbstract:This paper presents a new technique to model the behavior of crude Oil systems. The proposed technique is using a radial basis function neural network model (RBFNM). The model predicts Oil formation volume factor, solution gas-Oil ratio, Oil viscosity, saturated Oil density, undersaturated Oil compressibility, and evolved gas Gravity. Input data to the RBFNM are reservoir pressure, temperature, stock tank Oil Gravity, and separator gas Gravity. The model is trained using differential PVT analysis of numerous black-Oil samples collected from various Oil fields. The proposed RBFNM is tested using PVT properties of other samples that have not been used during the training process. Accuracy of the proposed network model to predict PUT properties of black-Oils systems is compared to the accuracy of numerous published PVT correlations.
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Wax deposition from Middle East crudes
Fuel, 2000Co-Authors: Adel M. Elsharkawy, Taher A. Al-sahhaf, Mohamed A. FahimAbstract:This paper reports measurements of wax content by acetone precipitation techniques as well as wax appearance temperature (WAT) by viscosity measurements and differential scanning calorimetry (DSC) of eight different stock-tank crude Oils from the Middle East. Comparison of WAT measured by DSC and viscosity indicates that the viscosity method overestimates the WAT. Crude Oil Gravity measured, by digital density meter, and molecular weight, by vapor pressure osmometer, were used to characterize the plus fraction and predict WAT and amount of wax formed at a given condition by the thermodynamic model. Comparison between predicted and measured results shows that measured WAT by DSC compares very well with that predicted from the model for most crudes. Generally, wax contents measured by the modified UOP method 46-64 and that predicted by the thermodynamic model are in good agreement.
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Changes in gas and Oil Gravity during pressure depletion of Oil reservoirs
Fuel, 1998Co-Authors: Adel M. ElsharkawyAbstract:Abstract The changes in reservoir evolved gas Gravity and Oil density during pressure depletion of Oil reservoirs is, usually, measured on collected bottom-hole samples by differential liberation. Occasionally, when these differentially measured data become unavailable, changes are estimated from correlations using production data. Simulation studies show that the Gravity of the produced gas changes by as much as 50% during pressure depletion of Oil reservoirs. In the absence of PVT studies, separator gas Gravity is used to calculate crude Oil and gas properties. While this assumption results in a small error in gas viscosity and gas FVF, it greatly underestimates solution GOR and Oil FVF, and overestimates Oil viscosity. A black Oil depletion model was used to study the sensitivity of Oil recovery to various PVT data sets estimated from separator gas and average produced gas. Reserve estimates show that using separator gas in calculating gas and Oil PVT properties results in underestimating depletion-drive ultimate Oil recovery by 40%. Laboratory-measured differential PVT data of crude Oil samples from the Middle East was used to develop correlations for predicting reservoir gas and Oil Gravity.
Robert M. Mink - One of the best experts on this subject based on the ideXlab platform.
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Haynesville sandstone reservoirs in the Updip Jurassic trend of Alabama
AAPG Bulletin, 1994Co-Authors: Ralph L. Kugler, Robert M. MinkAbstract:Subsequent to the 1986 drilling of the 1 Carolyn McCollough Unit 1-13 well, which initiated production from the Frisco City sand of the Haynesville Formation in Monroe County, Alabama, seven Haynesville fields have been established in Covington, Escambia, and Monroe counties. Initial flow rates of several hundred BOPD are typical for wells in these fields, and maximum rates exceed 2000 BOPD in North Frisco City field. As of August 1993, these fields produced more than 3,400,000 bbl of Oil and 4,000,000 mcf of gas from depths of 12,000 to 13,000 ft. Haynesville sandstone reservoirs are concentrated in two distinct areas: (1) an eastern area (Hickory Branch, North Rome, and West Falco fields; API Oil Gravity = 40{degrees}) in the Conecuh embayment and (2) a western area (Frisco City, North Frisco City, southeast Frisco City, and Megargel fields; API Oil Gravity = 58-59{degrees}) on the Conecuh ridge complex. Eastern fields are productive from Haynesville sandstone, which is not continuous with the two distinct, productive sandstone bodies in western fields, the Frisco City sand and the Megargel sand. Hydrocarbon traps are structural or combination traps associated with basement paleohighs. Reservoir bodies generally consist of conglomerate (igneous clasts in western fields; limestone clastsmore » in eastern fields), sandstone (subarkose-arkose), and shale (some of which is red) in stacked fining-upward sequences. Shale at the tops of these sequences is bioturbated. These marine strata were deposited in shoal-water braid-delta fronts. Petrophysical properties differ between the two areas. Maximum and average permeability in western fields (k{sub max} = 2000 md; k{sub ave} = 850-1800 md) is an order of magnitude higher than in eastern fields. The distribution of diagenetic components, including a variety of carbonate minerals, evaporate minerals (anhydrite and halite in western fields), and carbonate-replaced pseudomatrix, commonly is related to depositional architecture.« less
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Abstract: Haynesville Sandstone Reservoirs in the Updip Jurassic Trend of Alabama
1994Co-Authors: Ralph L. Kugler, Robert M. MinkAbstract:ABSTRACT Since the 1986 drilling of the 1 Carolyn McCollough Unit 1-13 well, which initiated production from the Frisco City sandstone of the Haynesville Formation in Monroe County, Alabama, seven Haynesville fields have been established in Covington, Escambia, and Monroe Counties. Initial flow rates of several hundred BOPD are typical in wells in these fields, and maximum rates exceed 2,000 BOPD in North Frisco City field. As of August 1993, these fields had produced more than 3,400,000 bbl of Oil and 4,000,000 Mcf of gas from depths of 12,000 to 13,000 ft. Haynesville sandstone reservoirs are concentrated in two distinct areas: (1) an eastern area (Hickory Branch, North Rome, and West Falco fields; API Oil Gravity = 40°) in the Conecuh embayment and (2) a western area (Frisco City, North Frisco City, southeast Frisco City, and Megargel fields; API Oil Gravity = 58-59°) on the Conecuh ridge complex. Eastern fields are productive from Haynesville sandstone, which is not continuous with the two distinct, productive sandstone bodies in western fields, the Frisco City sandstone and the Megargel sandstone. Hydrocarbon traps are structural or combination traps associated with basement paleohighs. Reservoir bodies generally consist of conglomerate (igneous clasts in western fields; limestone clasts in eastern fields), sandstone (subarkose-arkose), and shale (some of which is red) in stacked upward-fining sequences. Shale at the tops of these sequences is bioturbated. These marine strata were deposited in shoal-water braid-delta fronts. Petrophysical properties differ between the two areas. Maximum and average permeability in western fields (kmax = 2,000 md; kave = 850-1,800 md) is an order of magnitude higher than that in eastern fields. The distribution of diagenetic components, including a variety of carbonate minerals, evaporite minerals (anhydrite and halite in western fields), and carbonate- replaced pseudomatrix, commonly is related to depositional architecture. End_of_Record - Last_Page 764-------
Ralph L. Kugler - One of the best experts on this subject based on the ideXlab platform.
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Haynesville sandstone reservoirs in the Updip Jurassic trend of Alabama
AAPG Bulletin, 1994Co-Authors: Ralph L. Kugler, Robert M. MinkAbstract:Subsequent to the 1986 drilling of the 1 Carolyn McCollough Unit 1-13 well, which initiated production from the Frisco City sand of the Haynesville Formation in Monroe County, Alabama, seven Haynesville fields have been established in Covington, Escambia, and Monroe counties. Initial flow rates of several hundred BOPD are typical for wells in these fields, and maximum rates exceed 2000 BOPD in North Frisco City field. As of August 1993, these fields produced more than 3,400,000 bbl of Oil and 4,000,000 mcf of gas from depths of 12,000 to 13,000 ft. Haynesville sandstone reservoirs are concentrated in two distinct areas: (1) an eastern area (Hickory Branch, North Rome, and West Falco fields; API Oil Gravity = 40{degrees}) in the Conecuh embayment and (2) a western area (Frisco City, North Frisco City, southeast Frisco City, and Megargel fields; API Oil Gravity = 58-59{degrees}) on the Conecuh ridge complex. Eastern fields are productive from Haynesville sandstone, which is not continuous with the two distinct, productive sandstone bodies in western fields, the Frisco City sand and the Megargel sand. Hydrocarbon traps are structural or combination traps associated with basement paleohighs. Reservoir bodies generally consist of conglomerate (igneous clasts in western fields; limestone clastsmore » in eastern fields), sandstone (subarkose-arkose), and shale (some of which is red) in stacked fining-upward sequences. Shale at the tops of these sequences is bioturbated. These marine strata were deposited in shoal-water braid-delta fronts. Petrophysical properties differ between the two areas. Maximum and average permeability in western fields (k{sub max} = 2000 md; k{sub ave} = 850-1800 md) is an order of magnitude higher than in eastern fields. The distribution of diagenetic components, including a variety of carbonate minerals, evaporate minerals (anhydrite and halite in western fields), and carbonate-replaced pseudomatrix, commonly is related to depositional architecture.« less
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Abstract: Haynesville Sandstone Reservoirs in the Updip Jurassic Trend of Alabama
1994Co-Authors: Ralph L. Kugler, Robert M. MinkAbstract:ABSTRACT Since the 1986 drilling of the 1 Carolyn McCollough Unit 1-13 well, which initiated production from the Frisco City sandstone of the Haynesville Formation in Monroe County, Alabama, seven Haynesville fields have been established in Covington, Escambia, and Monroe Counties. Initial flow rates of several hundred BOPD are typical in wells in these fields, and maximum rates exceed 2,000 BOPD in North Frisco City field. As of August 1993, these fields had produced more than 3,400,000 bbl of Oil and 4,000,000 Mcf of gas from depths of 12,000 to 13,000 ft. Haynesville sandstone reservoirs are concentrated in two distinct areas: (1) an eastern area (Hickory Branch, North Rome, and West Falco fields; API Oil Gravity = 40°) in the Conecuh embayment and (2) a western area (Frisco City, North Frisco City, southeast Frisco City, and Megargel fields; API Oil Gravity = 58-59°) on the Conecuh ridge complex. Eastern fields are productive from Haynesville sandstone, which is not continuous with the two distinct, productive sandstone bodies in western fields, the Frisco City sandstone and the Megargel sandstone. Hydrocarbon traps are structural or combination traps associated with basement paleohighs. Reservoir bodies generally consist of conglomerate (igneous clasts in western fields; limestone clasts in eastern fields), sandstone (subarkose-arkose), and shale (some of which is red) in stacked upward-fining sequences. Shale at the tops of these sequences is bioturbated. These marine strata were deposited in shoal-water braid-delta fronts. Petrophysical properties differ between the two areas. Maximum and average permeability in western fields (kmax = 2,000 md; kave = 850-1,800 md) is an order of magnitude higher than that in eastern fields. The distribution of diagenetic components, including a variety of carbonate minerals, evaporite minerals (anhydrite and halite in western fields), and carbonate- replaced pseudomatrix, commonly is related to depositional architecture. End_of_Record - Last_Page 764-------
Zhangxing Chen - One of the best experts on this subject based on the ideXlab platform.
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Transient mass transfer ahead of a hot solvent chamber in a heavy Oil Gravity drainage process
Fuel, 2018Co-Authors: Qiong Wang, Zhangxing ChenAbstract:Abstract As one of the hybrid steam–solvent processes, hot solvent injection is a promising heavy Oil recovery technique. It takes advantage of both thermal recovery processes (quick thermal conduction and viscosity reduction) and solvent-based processes (lower energy consumption and less green-house gas emission). In comparison with conventional cold solvent processes, hot solvent processes can greatly improve Oil production. This paper develops a transient mass transfer model to analyze the heavy Oil–hot solvent mixing process during a hot solvent injection process. Modeling results show that a moderate elevation in temperature leads to a slight improvement in solvent dissolution but a large enhancement in Oil drainage. It is found that the Gravity drainage rate of solvent-diluted heavy Oil depends strongly on the heated Oil viscosity. Furthermore, it shows that temperature falloff slows down Oil drainage, which suggests that temperature should be maintained stable during a hot solvent injection process.
Shahab Ayatollahi - One of the best experts on this subject based on the ideXlab platform.
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Secondary and Tertiary Thermally Induced Gas-Oil Gravity Drainage from Oil-wet Fractured Rocks: Experiments under Reservoir Conditions
Energy Sources Part A-recovery Utilization and Environmental Effects, 2014Co-Authors: S. Asadizadeh, Shahab Ayatollahi, Amin Mohsenzadeh, Mehdi Escrochi, Emad RoayaeiAbstract:A series of reservoir condition experimental studies are presented that investigate the effects of Oil production by water drive on the success of subsequent Oil production by gas-Oil Gravity drainage in a fractured laboratory model. The experiments were performed using low permeable, Oil-wet carbonate core samples. During this work, injection of N2 gas followed by steam into the fracture was studied using two different scenarios: initial Oil place at connate water saturation condition utilized for secondary Oil recovery, and water flooded cores at residual Oil saturation for tertiary Oil recovery. The result showed that the water invasion into the fractures reduces Oil production potential, and it is shown that the ultimate recovery for secondary gas injection is considerably higher than tertiary gas-Oil Gravity drainage for both isothermal and non-isothermal tests. Steam injection into the fractured model leads to twice more Oil recovery than the preceding isothermal recovery. The results confirmed that...
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laboratory investigation of thermally assisted gas Oil Gravity drainage for secondary and tertiary Oil recovery in fractured models
Journal of Petroleum Science and Engineering, 2007Co-Authors: Moei Nabipou, M. Wadhahi, Ricardo Maamari, Shahab Ayatollahi, Mehdi Escrochi, F H Oukadi, A S EmaniAbstract:Abstract Heavy Oil in Middle East fractured carbonate reservoirs account for 25–30% of the total Oil in place in the region. Production of heavy Oil from such reservoirs is thought to play an important role in the future of the ever-growing world's energy consumption. Besides, having very active water drives, some of these reservoirs are already depleted resulted in high residual Oil in place. To enhance the Oil recovery efficiency, the mechanism of thermally-assisted gas–Oil Gravity drainage for secondary and tertiary Oil recovery was investigated on a fractured laboratory model. Very high recovery efficiencies were achieved due to Oil viscosity reduction as well as Gravity stability of the gas–Oil contact in both Oil-wet and water-wet fractured porous media. It was also noted that a combination of waterflooding and thermal recovery is very effective to enhance heavy Oil recovery from fractured water-wet and Oil-wet models.
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Laboratory investigation of thermally-assisted gas–Oil Gravity drainage for secondary and tertiary Oil recovery in fractured models
Journal of Petroleum Science and Engineering, 2006Co-Authors: Moein Nabipour, F. H. Boukadi, M. Wadhahi, Ricardo Maamari, Shahab Ayatollahi, Mehdi Escrochi, Ali S. Al-bemaniAbstract:Abstract Heavy Oil in Middle East fractured carbonate reservoirs account for 25–30% of the total Oil in place in the region. Production of heavy Oil from such reservoirs is thought to play an important role in the future of the ever-growing world's energy consumption. Besides, having very active water drives, some of these reservoirs are already depleted resulted in high residual Oil in place. To enhance the Oil recovery efficiency, the mechanism of thermally-assisted gas–Oil Gravity drainage for secondary and tertiary Oil recovery was investigated on a fractured laboratory model. Very high recovery efficiencies were achieved due to Oil viscosity reduction as well as Gravity stability of the gas–Oil contact in both Oil-wet and water-wet fractured porous media. It was also noted that a combination of waterflooding and thermal recovery is very effective to enhance heavy Oil recovery from fractured water-wet and Oil-wet models.
