The Experts below are selected from a list of 6 Experts worldwide ranked by ideXlab platform
K.a. Abd-el Fattah - One of the best experts on this subject based on the ideXlab platform.
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NEW GAS Pseudocritical Property EQUATIONS DEVELOPED
Oil & Gas Journal, 1997Co-Authors: K.a. Abd-el FattahAbstract:New equations have been developed for calculating natural gas Pseudocritical temperature and pressure over a wider range of gas specific gravities than previously published equations. Both Pseudocritical temperature and pressure are required for many gas calculations. If the gas specific gravity is known, one can use correlations for estimating these parameters whenever field or laboratory measurements are unavailable. The new equations apply for gas with a specific gravity of 0.55--1.2.
Gordon R. Moore - One of the best experts on this subject based on the ideXlab platform.
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Natural Gas z-Factors at HP/HT Reservoir Conditions: Comparing Laboratory Measurements With Industry-Standard Correlations for a Dry Gas
All Days, 2008Co-Authors: Jay Alan Rushing, Kent Edward Newsham, Kees Cornelius Van Fraassen, Sudarshan A. Mehta, Gordon R. MooreAbstract:Abstract This paper presents preliminary laboratory measurements of the natural gas compressibility or z-factor at high-pressure, high-temperature (HP/HT) reservoir conditions. We conducted laboratory studies to measure gas density and z-factor for several dry gas mixtures at pressures up to 20,000 psia and temperatures of 300°F and 400°F. For our study, we define a dry gas as one that remains in the single hydrocarbon (gas) phase during the entire isothermal pressure depletion path from the reservoir through surface conditions. We also measured the effects of CO2 in the gas phase on gas density and z-factor at HP/HT conditions. Several gas mixtures contained CO2 concentrations up to 20 mol% each. We then compared the new laboratory data with two equation-of-state (EOS) models used by the petroleum industry to compute z-factor. In combination with our evaluation of the EOS models, we also assessed several mixing rules and empirical correlations for estimating Pseudocritical properties of gas mixtures. Results of our comparisons indicate the following: ?? For gases with no CO2, the Hall & Yarborough EOS [1973] combined with the Sutton [2005, 2007] Pseudocritical Property correlations were the most accurate, especially in the higher pressure range and for both temperatures evaluated. The Dranchuk & Abou-Kassem EOS [1975] was the least accurate regardless of the mixing rule or empirical correlation used to estimate Pseudocritical properties; ?? Although the Hall & Yarborough EOS combined with the Sutton Pseudocritical Property correlations were the most accurate for gases with no CO2 at 400°F, the errors were still more than 300% higher than those for the same gas mixtures at 300°F. These differences suggest neither EOS has been properly "tuned" to data at higher temperatures and validates our concerns about extending the Standing-Katz correlations numerically to higher pressures and temperatures; ?? When combined with the Hall & Yarborough EOS, both the Kay [1936] and the Stewart-Burkhardt-Voo [1956] mixing rules were surprisingly quite often the second most accurate models for estimating z-factors at HP/HT conditions; and ?? For gas mixtures with CO2, the Hall & Yarborough EOS was again the most accurate when combined with the Wichert & Aziz [1971] correlations for CO2 and the Sutton Pseudocritical Property correlations. Conversely, the Dranchuk & Abou-Kassem EOS was the least accurate for all mixing rules or empirical correlations. Introduction The majority of natural gas resources targeted for exploration and development activities by the oil and gas industry prior to the 1970s were at depths less than 15,000 ft. Most of these natural gas resources exhibited normal pore pressure and temperature gradients. However, the oil and gas industry has continued to extend exploration and development activities to depths much greater than 15,000 ft. In some geologic basins, the depths are approaching 20,000 to 25,000 ft. Moreover, many of these deep natural gas resources are characterized by both abnormally high pore pressure and temperature gradients — i.e. high-pressure and high-temperature (HP/HT) reservoir conditions. And, natural gases at HP/HT conditions frequently contain nonhydrocarbon contaminants, e.g., typically CO2, N2, H2S, and/or water vapor.
Jay Alan Rushing - One of the best experts on this subject based on the ideXlab platform.
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Natural Gas z-Factors at HP/HT Reservoir Conditions: Comparing Laboratory Measurements With Industry-Standard Correlations for a Dry Gas
All Days, 2008Co-Authors: Jay Alan Rushing, Kent Edward Newsham, Kees Cornelius Van Fraassen, Sudarshan A. Mehta, Gordon R. MooreAbstract:Abstract This paper presents preliminary laboratory measurements of the natural gas compressibility or z-factor at high-pressure, high-temperature (HP/HT) reservoir conditions. We conducted laboratory studies to measure gas density and z-factor for several dry gas mixtures at pressures up to 20,000 psia and temperatures of 300°F and 400°F. For our study, we define a dry gas as one that remains in the single hydrocarbon (gas) phase during the entire isothermal pressure depletion path from the reservoir through surface conditions. We also measured the effects of CO2 in the gas phase on gas density and z-factor at HP/HT conditions. Several gas mixtures contained CO2 concentrations up to 20 mol% each. We then compared the new laboratory data with two equation-of-state (EOS) models used by the petroleum industry to compute z-factor. In combination with our evaluation of the EOS models, we also assessed several mixing rules and empirical correlations for estimating Pseudocritical properties of gas mixtures. Results of our comparisons indicate the following: ?? For gases with no CO2, the Hall & Yarborough EOS [1973] combined with the Sutton [2005, 2007] Pseudocritical Property correlations were the most accurate, especially in the higher pressure range and for both temperatures evaluated. The Dranchuk & Abou-Kassem EOS [1975] was the least accurate regardless of the mixing rule or empirical correlation used to estimate Pseudocritical properties; ?? Although the Hall & Yarborough EOS combined with the Sutton Pseudocritical Property correlations were the most accurate for gases with no CO2 at 400°F, the errors were still more than 300% higher than those for the same gas mixtures at 300°F. These differences suggest neither EOS has been properly "tuned" to data at higher temperatures and validates our concerns about extending the Standing-Katz correlations numerically to higher pressures and temperatures; ?? When combined with the Hall & Yarborough EOS, both the Kay [1936] and the Stewart-Burkhardt-Voo [1956] mixing rules were surprisingly quite often the second most accurate models for estimating z-factors at HP/HT conditions; and ?? For gas mixtures with CO2, the Hall & Yarborough EOS was again the most accurate when combined with the Wichert & Aziz [1971] correlations for CO2 and the Sutton Pseudocritical Property correlations. Conversely, the Dranchuk & Abou-Kassem EOS was the least accurate for all mixing rules or empirical correlations. Introduction The majority of natural gas resources targeted for exploration and development activities by the oil and gas industry prior to the 1970s were at depths less than 15,000 ft. Most of these natural gas resources exhibited normal pore pressure and temperature gradients. However, the oil and gas industry has continued to extend exploration and development activities to depths much greater than 15,000 ft. In some geologic basins, the depths are approaching 20,000 to 25,000 ft. Moreover, many of these deep natural gas resources are characterized by both abnormally high pore pressure and temperature gradients — i.e. high-pressure and high-temperature (HP/HT) reservoir conditions. And, natural gases at HP/HT conditions frequently contain nonhydrocarbon contaminants, e.g., typically CO2, N2, H2S, and/or water vapor.
Kent Edward Newsham - One of the best experts on this subject based on the ideXlab platform.
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Natural Gas z-Factors at HP/HT Reservoir Conditions: Comparing Laboratory Measurements With Industry-Standard Correlations for a Dry Gas
All Days, 2008Co-Authors: Jay Alan Rushing, Kent Edward Newsham, Kees Cornelius Van Fraassen, Sudarshan A. Mehta, Gordon R. MooreAbstract:Abstract This paper presents preliminary laboratory measurements of the natural gas compressibility or z-factor at high-pressure, high-temperature (HP/HT) reservoir conditions. We conducted laboratory studies to measure gas density and z-factor for several dry gas mixtures at pressures up to 20,000 psia and temperatures of 300°F and 400°F. For our study, we define a dry gas as one that remains in the single hydrocarbon (gas) phase during the entire isothermal pressure depletion path from the reservoir through surface conditions. We also measured the effects of CO2 in the gas phase on gas density and z-factor at HP/HT conditions. Several gas mixtures contained CO2 concentrations up to 20 mol% each. We then compared the new laboratory data with two equation-of-state (EOS) models used by the petroleum industry to compute z-factor. In combination with our evaluation of the EOS models, we also assessed several mixing rules and empirical correlations for estimating Pseudocritical properties of gas mixtures. Results of our comparisons indicate the following: ?? For gases with no CO2, the Hall & Yarborough EOS [1973] combined with the Sutton [2005, 2007] Pseudocritical Property correlations were the most accurate, especially in the higher pressure range and for both temperatures evaluated. The Dranchuk & Abou-Kassem EOS [1975] was the least accurate regardless of the mixing rule or empirical correlation used to estimate Pseudocritical properties; ?? Although the Hall & Yarborough EOS combined with the Sutton Pseudocritical Property correlations were the most accurate for gases with no CO2 at 400°F, the errors were still more than 300% higher than those for the same gas mixtures at 300°F. These differences suggest neither EOS has been properly "tuned" to data at higher temperatures and validates our concerns about extending the Standing-Katz correlations numerically to higher pressures and temperatures; ?? When combined with the Hall & Yarborough EOS, both the Kay [1936] and the Stewart-Burkhardt-Voo [1956] mixing rules were surprisingly quite often the second most accurate models for estimating z-factors at HP/HT conditions; and ?? For gas mixtures with CO2, the Hall & Yarborough EOS was again the most accurate when combined with the Wichert & Aziz [1971] correlations for CO2 and the Sutton Pseudocritical Property correlations. Conversely, the Dranchuk & Abou-Kassem EOS was the least accurate for all mixing rules or empirical correlations. Introduction The majority of natural gas resources targeted for exploration and development activities by the oil and gas industry prior to the 1970s were at depths less than 15,000 ft. Most of these natural gas resources exhibited normal pore pressure and temperature gradients. However, the oil and gas industry has continued to extend exploration and development activities to depths much greater than 15,000 ft. In some geologic basins, the depths are approaching 20,000 to 25,000 ft. Moreover, many of these deep natural gas resources are characterized by both abnormally high pore pressure and temperature gradients — i.e. high-pressure and high-temperature (HP/HT) reservoir conditions. And, natural gases at HP/HT conditions frequently contain nonhydrocarbon contaminants, e.g., typically CO2, N2, H2S, and/or water vapor.
Kees Cornelius Van Fraassen - One of the best experts on this subject based on the ideXlab platform.
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Natural Gas z-Factors at HP/HT Reservoir Conditions: Comparing Laboratory Measurements With Industry-Standard Correlations for a Dry Gas
All Days, 2008Co-Authors: Jay Alan Rushing, Kent Edward Newsham, Kees Cornelius Van Fraassen, Sudarshan A. Mehta, Gordon R. MooreAbstract:Abstract This paper presents preliminary laboratory measurements of the natural gas compressibility or z-factor at high-pressure, high-temperature (HP/HT) reservoir conditions. We conducted laboratory studies to measure gas density and z-factor for several dry gas mixtures at pressures up to 20,000 psia and temperatures of 300°F and 400°F. For our study, we define a dry gas as one that remains in the single hydrocarbon (gas) phase during the entire isothermal pressure depletion path from the reservoir through surface conditions. We also measured the effects of CO2 in the gas phase on gas density and z-factor at HP/HT conditions. Several gas mixtures contained CO2 concentrations up to 20 mol% each. We then compared the new laboratory data with two equation-of-state (EOS) models used by the petroleum industry to compute z-factor. In combination with our evaluation of the EOS models, we also assessed several mixing rules and empirical correlations for estimating Pseudocritical properties of gas mixtures. Results of our comparisons indicate the following: ?? For gases with no CO2, the Hall & Yarborough EOS [1973] combined with the Sutton [2005, 2007] Pseudocritical Property correlations were the most accurate, especially in the higher pressure range and for both temperatures evaluated. The Dranchuk & Abou-Kassem EOS [1975] was the least accurate regardless of the mixing rule or empirical correlation used to estimate Pseudocritical properties; ?? Although the Hall & Yarborough EOS combined with the Sutton Pseudocritical Property correlations were the most accurate for gases with no CO2 at 400°F, the errors were still more than 300% higher than those for the same gas mixtures at 300°F. These differences suggest neither EOS has been properly "tuned" to data at higher temperatures and validates our concerns about extending the Standing-Katz correlations numerically to higher pressures and temperatures; ?? When combined with the Hall & Yarborough EOS, both the Kay [1936] and the Stewart-Burkhardt-Voo [1956] mixing rules were surprisingly quite often the second most accurate models for estimating z-factors at HP/HT conditions; and ?? For gas mixtures with CO2, the Hall & Yarborough EOS was again the most accurate when combined with the Wichert & Aziz [1971] correlations for CO2 and the Sutton Pseudocritical Property correlations. Conversely, the Dranchuk & Abou-Kassem EOS was the least accurate for all mixing rules or empirical correlations. Introduction The majority of natural gas resources targeted for exploration and development activities by the oil and gas industry prior to the 1970s were at depths less than 15,000 ft. Most of these natural gas resources exhibited normal pore pressure and temperature gradients. However, the oil and gas industry has continued to extend exploration and development activities to depths much greater than 15,000 ft. In some geologic basins, the depths are approaching 20,000 to 25,000 ft. Moreover, many of these deep natural gas resources are characterized by both abnormally high pore pressure and temperature gradients — i.e. high-pressure and high-temperature (HP/HT) reservoir conditions. And, natural gases at HP/HT conditions frequently contain nonhydrocarbon contaminants, e.g., typically CO2, N2, H2S, and/or water vapor.
