PVT Properties of Live Crude Oils from Upstream Production Platforms

Luciana Loureiro de Pinho Rolemberg de Andrade; Krishnaswamy Rajagopal

doi:doi:10.11648/j.ogce.20170506.18

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PVT Properties of Live Crude Oils from Upstream Production Platforms

Luciana Loureiro de Pinho Rolemberg de Andrade, Krishnaswamy Rajagopal

Published in International Journal of Oil, Gas and Coal Engineering (Volume 5, Issue 6)

Received: 11 October 2017 Accepted: 13 November 2017 Published: 12 December 2017

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Abstract

The physical and compositional properties of live crude oils strongly affect the strategy of transportation of oil and gas from reservoirs to the stock tank and their storage. The relevant PVT properties of live crude oils like solution gas-oil ratio and oil formation volume factor should be measured preferably in laboratory for different pressures at the process or reservoir temperature. The sampling and PVT analysis include time consuming or expensive procedures and the data obtained are correlated for interpolation or estimation of properties. These properties vary considerably for different classes of crude oils. We obtain experimental data of crude oils properties from the PVT analysis of primary high-pressure separator samples of 260 live paraffinic-naphthenic crude oils from forty-four Brazilian oil wells. The solution gas-oil ratio and oil formation volume factor were obtained within experimental uncertainties of 5.79% and 1.00%, respectively. We have compared the results with the estimates of several cubic equations of state as well as with widely used literature correlations. The best equation of state estimate solution gas-oil ratio with average absolute percent relative error (AARE) of 10.36%, better than the empirical correlations in the literature using measured temperature, pressure and composition, the empirical correlation for solution gas-oil ratio with parameters estimated from the experimental data shows an AARE of 10.77%. The equations of state and literature correlations estimate the oil formation volume factor with an AARE about 2%, which is lower than the needed accuracy. The measured oil formation volume factors are correlated with an average absolute percent relative error of 1.18%, with a proposed correlation using readily measured liquid densities and solution gas-oil ratio. We can estimate the solution gas-oil ratio by Peng-Robinson equation of state and oil formation volume factor by proposed correlation to the needed accuracy for live paraffinic-naphthenic crude oils under separator conditions from composition, temperature and densities of gas and oil.

Published in	International Journal of Oil, Gas and Coal Engineering (Volume 5, Issue 6)
DOI	10.11648/j.ogce.20170506.18
Page(s)	175-183
Creative Commons	This is an Open Access article, distributed under the terms of the Creative Commons Attribution 4.0 International License (http://creativecommons.org/licenses/by/4.0/), which permits unrestricted use, distribution and reproduction in any medium or format, provided the original work is properly cited.
Copyright	Copyright © The Author(s), 2024. Published by Science Publishing Group

Keywords

Live Crude Oils, Experimental PVT Properties, Solution Gas-Oil Ratio, Oil Formation Volume Factor, Paraffinic-Naphthenic Crudes

References

[1]	Danesh A., “PVT and Phase Behavior of Reservoir Fluids; Developments in Petroleum Science”, Elsevier Science B. V., Amsterdam, 1998.
[2]	ASTM D5002-99, Standard Test Method for Density and Relative Density of Crude Oils by Digital Density Analyzer, ASTM International, West Conshohocken, PA, 1999, www.astm.org.
[3]	ASTM D4928-12, Standard Test Method for Water in Crude Oils by Coulometric Karl Fischer Titration, ASTM International, West Conshohocken, PA, 2012, www.astm.org.
[4]	ASTM D2887-03, Standard Test Method for Boiling Range Distribution of Petroleum Fractions by Gas Chromatography, ASTM International, West Conshohocken, PA, 2003, www.astm.org.
[5]	ASTM D1945-03 (2010), Standard Test Method for Analysis of Natural Gas by Gas Chromatography, ASTM International, West Conshohocken, PA, 2010, www.astm.org.
[6]	Farah M. A., “Petróleo e Seus Derivados. Definição, onstituição, Aplicação, Especificações, Características de Qualidade,” LTC, Rio de Janeiro, 2012.
[7]	ASTM D445-06, Standard Test Method for Kinematic Viscosity of Transparent and Opaque Liquids (and Calculation of Dynamic Viscosity), ASTM International, West Conshohocken, PA, 2006, www.astm.org.
[8]	Standing M. B., “A Pressure-Volume-Temperature Correlation for Mixtures of California Oils and Gases,” In Pacific Coast District, Los Angeles, Calif., May 1947.
[9]	Glaso O., “Generalized Pressure-Volume-Temperature Correlations,” Journal of Petroleum Technology, 1980, pp 785–795.
[10]	Vazquez M. E., Beggs H. D., “Correlations for Fluid Physical Property Prediction,” J. Pet. Technol., Vol. 32, No. 06, 1980, pp 968–970.
[11]	Kartoatmodjo R. S. T., Schmidt Z., “New Correlations for Crude Oil Physical Properties," SPE 23556, available from SPE Book Order Dept., Richardson, Texas, 1991.
[12]	Petrosky G. E., Jr., Farshad F. F., “(Gulf of Mexico Oil); Pressure-Volume-Temperature Correlations for Gulf of Mexico Crude Oils,” SPE 51395, Annual Technical Conference and Exhibition, Houston, JPT, pp 416–420, 3–6 October, 1993.
[13]	Elsharkawy A. M., Alikhan A. A., “Models for predicting the viscosity of Middle East Crude Oil,” Fuel, Vol. 78, 1999, pp 891–903.
[14]	Al-Marhoun M., “Black oil property correlations – state of art,” In SPE Middle East Oil & gas Show and Conference, Manam, Bahrain, 8–11 March, 2015.
[15]	McCain W. D., Jr., “Reservoir-Fluid Property Correlations-State of the Art,” Society of Petroleum Engineers, 1991, Vol. 6, No. 02, pp 266–272.
[16]	Omar M. I., Todd A. C., “Development of a modified black oil correlation for Malaysian crudes,” In SPE Asia Pacific Oil and Gas Conference, Singapore, 8–10 February, 1993.

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APA Style

Luciana Loureiro de Pinho Rolemberg de Andrade, Krishnaswamy Rajagopal. (2017). PVT Properties of Live Crude Oils from Upstream Production Platforms. International Journal of Oil, Gas and Coal Engineering, 5(6), 175-183. https://doi.org/10.11648/j.ogce.20170506.18

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ACS Style

Luciana Loureiro de Pinho Rolemberg de Andrade; Krishnaswamy Rajagopal. PVT Properties of Live Crude Oils from Upstream Production Platforms. Int. J. Oil Gas Coal Eng. 2017, 5(6), 175-183. doi: 10.11648/j.ogce.20170506.18

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AMA Style

Luciana Loureiro de Pinho Rolemberg de Andrade, Krishnaswamy Rajagopal. PVT Properties of Live Crude Oils from Upstream Production Platforms. Int J Oil Gas Coal Eng. 2017;5(6):175-183. doi: 10.11648/j.ogce.20170506.18

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@article{10.11648/j.ogce.20170506.18,
  author = {Luciana Loureiro de Pinho Rolemberg de Andrade and Krishnaswamy Rajagopal},
  title = {PVT Properties of Live Crude Oils from Upstream Production Platforms},
  journal = {International Journal of Oil, Gas and Coal Engineering},
  volume = {5},
  number = {6},
  pages = {175-183},
  doi = {10.11648/j.ogce.20170506.18},
  url = {https://doi.org/10.11648/j.ogce.20170506.18},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ogce.20170506.18},
  abstract = {The physical and compositional properties of live crude oils strongly affect the strategy of transportation of oil and gas from reservoirs to the stock tank and their storage. The relevant PVT properties of live crude oils like solution gas-oil ratio and oil formation volume factor should be measured preferably in laboratory for different pressures at the process or reservoir temperature. The sampling and PVT analysis include time consuming or expensive procedures and the data obtained are correlated for interpolation or estimation of properties. These properties vary considerably for different classes of crude oils. We obtain experimental data of crude oils properties from the PVT analysis of primary high-pressure separator samples of 260 live paraffinic-naphthenic crude oils from forty-four Brazilian oil wells. The solution gas-oil ratio and oil formation volume factor were obtained within experimental uncertainties of 5.79% and 1.00%, respectively. We have compared the results with the estimates of several cubic equations of state as well as with widely used literature correlations. The best equation of state estimate solution gas-oil ratio with average absolute percent relative error (AARE) of 10.36%, better than the empirical correlations in the literature using measured temperature, pressure and composition, the empirical correlation for solution gas-oil ratio with parameters estimated from the experimental data shows an AARE of 10.77%. The equations of state and literature correlations estimate the oil formation volume factor with an AARE about 2%, which is lower than the needed accuracy. The measured oil formation volume factors are correlated with an average absolute percent relative error of 1.18%, with a proposed correlation using readily measured liquid densities and solution gas-oil ratio. We can estimate the solution gas-oil ratio by Peng-Robinson equation of state and oil formation volume factor by proposed correlation to the needed accuracy for live paraffinic-naphthenic crude oils under separator conditions from composition, temperature and densities of gas and oil.},
 year = {2017}
}

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TY  - JOUR
T1  - PVT Properties of Live Crude Oils from Upstream Production Platforms
AU  - Luciana Loureiro de Pinho Rolemberg de Andrade
AU  - Krishnaswamy Rajagopal
Y1  - 2017/12/12
PY  - 2017
N1  - https://doi.org/10.11648/j.ogce.20170506.18
DO  - 10.11648/j.ogce.20170506.18
T2  - International Journal of Oil, Gas and Coal Engineering
JF  - International Journal of Oil, Gas and Coal Engineering
JO  - International Journal of Oil, Gas and Coal Engineering
SP  - 175
EP  - 183
PB  - Science Publishing Group
SN  - 2376-7677
UR  - https://doi.org/10.11648/j.ogce.20170506.18
AB  - The physical and compositional properties of live crude oils strongly affect the strategy of transportation of oil and gas from reservoirs to the stock tank and their storage. The relevant PVT properties of live crude oils like solution gas-oil ratio and oil formation volume factor should be measured preferably in laboratory for different pressures at the process or reservoir temperature. The sampling and PVT analysis include time consuming or expensive procedures and the data obtained are correlated for interpolation or estimation of properties. These properties vary considerably for different classes of crude oils. We obtain experimental data of crude oils properties from the PVT analysis of primary high-pressure separator samples of 260 live paraffinic-naphthenic crude oils from forty-four Brazilian oil wells. The solution gas-oil ratio and oil formation volume factor were obtained within experimental uncertainties of 5.79% and 1.00%, respectively. We have compared the results with the estimates of several cubic equations of state as well as with widely used literature correlations. The best equation of state estimate solution gas-oil ratio with average absolute percent relative error (AARE) of 10.36%, better than the empirical correlations in the literature using measured temperature, pressure and composition, the empirical correlation for solution gas-oil ratio with parameters estimated from the experimental data shows an AARE of 10.77%. The equations of state and literature correlations estimate the oil formation volume factor with an AARE about 2%, which is lower than the needed accuracy. The measured oil formation volume factors are correlated with an average absolute percent relative error of 1.18%, with a proposed correlation using readily measured liquid densities and solution gas-oil ratio. We can estimate the solution gas-oil ratio by Peng-Robinson equation of state and oil formation volume factor by proposed correlation to the needed accuracy for live paraffinic-naphthenic crude oils under separator conditions from composition, temperature and densities of gas and oil.
VL  - 5
IS  - 6
ER  -

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Author Information

Luciana Loureiro de Pinho Rolemberg de Andrade

Laboratory of Applied Thermodynamics and Kinetics, School of Chemistry, Federal University of Rio de Janeiro, Rio de Janeiro, Brazil
Krishnaswamy Rajagopal

Laboratory of Applied Thermodynamics and Kinetics, School of Chemistry, Federal University of Rio de Janeiro, Rio de Janeiro, Brazil

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APA Style

Luciana Loureiro de Pinho Rolemberg de Andrade, Krishnaswamy Rajagopal. (2017). PVT Properties of Live Crude Oils from Upstream Production Platforms. International Journal of Oil, Gas and Coal Engineering, 5(6), 175-183. https://doi.org/10.11648/j.ogce.20170506.18

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ACS Style

Luciana Loureiro de Pinho Rolemberg de Andrade; Krishnaswamy Rajagopal. PVT Properties of Live Crude Oils from Upstream Production Platforms. Int. J. Oil Gas Coal Eng. 2017, 5(6), 175-183. doi: 10.11648/j.ogce.20170506.18

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AMA Style

Luciana Loureiro de Pinho Rolemberg de Andrade, Krishnaswamy Rajagopal. PVT Properties of Live Crude Oils from Upstream Production Platforms. Int J Oil Gas Coal Eng. 2017;5(6):175-183. doi: 10.11648/j.ogce.20170506.18

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@article{10.11648/j.ogce.20170506.18,
  author = {Luciana Loureiro de Pinho Rolemberg de Andrade and Krishnaswamy Rajagopal},
  title = {PVT Properties of Live Crude Oils from Upstream Production Platforms},
  journal = {International Journal of Oil, Gas and Coal Engineering},
  volume = {5},
  number = {6},
  pages = {175-183},
  doi = {10.11648/j.ogce.20170506.18},
  url = {https://doi.org/10.11648/j.ogce.20170506.18},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ogce.20170506.18},
  abstract = {The physical and compositional properties of live crude oils strongly affect the strategy of transportation of oil and gas from reservoirs to the stock tank and their storage. The relevant PVT properties of live crude oils like solution gas-oil ratio and oil formation volume factor should be measured preferably in laboratory for different pressures at the process or reservoir temperature. The sampling and PVT analysis include time consuming or expensive procedures and the data obtained are correlated for interpolation or estimation of properties. These properties vary considerably for different classes of crude oils. We obtain experimental data of crude oils properties from the PVT analysis of primary high-pressure separator samples of 260 live paraffinic-naphthenic crude oils from forty-four Brazilian oil wells. The solution gas-oil ratio and oil formation volume factor were obtained within experimental uncertainties of 5.79% and 1.00%, respectively. We have compared the results with the estimates of several cubic equations of state as well as with widely used literature correlations. The best equation of state estimate solution gas-oil ratio with average absolute percent relative error (AARE) of 10.36%, better than the empirical correlations in the literature using measured temperature, pressure and composition, the empirical correlation for solution gas-oil ratio with parameters estimated from the experimental data shows an AARE of 10.77%. The equations of state and literature correlations estimate the oil formation volume factor with an AARE about 2%, which is lower than the needed accuracy. The measured oil formation volume factors are correlated with an average absolute percent relative error of 1.18%, with a proposed correlation using readily measured liquid densities and solution gas-oil ratio. We can estimate the solution gas-oil ratio by Peng-Robinson equation of state and oil formation volume factor by proposed correlation to the needed accuracy for live paraffinic-naphthenic crude oils under separator conditions from composition, temperature and densities of gas and oil.},
 year = {2017}
}

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TY  - JOUR
T1  - PVT Properties of Live Crude Oils from Upstream Production Platforms
AU  - Luciana Loureiro de Pinho Rolemberg de Andrade
AU  - Krishnaswamy Rajagopal
Y1  - 2017/12/12
PY  - 2017
N1  - https://doi.org/10.11648/j.ogce.20170506.18
DO  - 10.11648/j.ogce.20170506.18
T2  - International Journal of Oil, Gas and Coal Engineering
JF  - International Journal of Oil, Gas and Coal Engineering
JO  - International Journal of Oil, Gas and Coal Engineering
SP  - 175
EP  - 183
PB  - Science Publishing Group
SN  - 2376-7677
UR  - https://doi.org/10.11648/j.ogce.20170506.18
AB  - The physical and compositional properties of live crude oils strongly affect the strategy of transportation of oil and gas from reservoirs to the stock tank and their storage. The relevant PVT properties of live crude oils like solution gas-oil ratio and oil formation volume factor should be measured preferably in laboratory for different pressures at the process or reservoir temperature. The sampling and PVT analysis include time consuming or expensive procedures and the data obtained are correlated for interpolation or estimation of properties. These properties vary considerably for different classes of crude oils. We obtain experimental data of crude oils properties from the PVT analysis of primary high-pressure separator samples of 260 live paraffinic-naphthenic crude oils from forty-four Brazilian oil wells. The solution gas-oil ratio and oil formation volume factor were obtained within experimental uncertainties of 5.79% and 1.00%, respectively. We have compared the results with the estimates of several cubic equations of state as well as with widely used literature correlations. The best equation of state estimate solution gas-oil ratio with average absolute percent relative error (AARE) of 10.36%, better than the empirical correlations in the literature using measured temperature, pressure and composition, the empirical correlation for solution gas-oil ratio with parameters estimated from the experimental data shows an AARE of 10.77%. The equations of state and literature correlations estimate the oil formation volume factor with an AARE about 2%, which is lower than the needed accuracy. The measured oil formation volume factors are correlated with an average absolute percent relative error of 1.18%, with a proposed correlation using readily measured liquid densities and solution gas-oil ratio. We can estimate the solution gas-oil ratio by Peng-Robinson equation of state and oil formation volume factor by proposed correlation to the needed accuracy for live paraffinic-naphthenic crude oils under separator conditions from composition, temperature and densities of gas and oil.
VL  - 5
IS  - 6
ER  -

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