Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda

Marembo Micheal; Asasira Sonia

doi:doi:10.11648/j.ijaos.20180202.12

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Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda

Marembo Micheal, Asasira Sonia

Published in International Journal of Atmospheric and Oceanic Sciences (Volume 2, Issue 2)

Received: 24 November 2018 Accepted: 13 December 2018 Published: 22 January 2019

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Abstract

Uganda is naturally endowed with vast resources ranging from oil to precious stones including diamond among others. Venturing into exploration and development of these resources has recently taken a center stage. Currently, the Ugandan oil reservoir located in the Albertine region, Western Uganda has only been appraised and production has not begun. This study uses standard correlation equations, field analogs, and compares with existing literature to predict the future oil recovery potential of the Albertine reservoir using water flooding and water-alternating gas (WAG) as the enhanced oil recovery methods using Carbon dioxide as the injection gas. Field analogue results indicate that the oil recovery factor during primary production is 8% to 15% while the oil recovery factor during secondary production ranges from 18.2% to 62%. Simulation results show an oil recovery factor of 9.81% and 36.85% during primary and secondary production respectively. The optimum well location is 800ft from the producer with an oil recovery factor of 36.85%. Well location has an effect on over all oil recovery factor and higher recovery factor is achieved when the injection well is 800 ft from the producer. Water flooding yields 31.67% of the original oil in place (OOIP) while Carbon dioxide yields 62.30% of OOIP. When WAG injection process is preceded by waterflooding, the oil recovery factor is 5.57% higher than when WAG process is preceded by Carbon dioxide injection.

Published in	International Journal of Atmospheric and Oceanic Sciences (Volume 2, Issue 2)
DOI	10.11648/j.ijaos.20180202.12
Page(s)	27-34
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), 2019. Published by Science Publishing Group

Keywords

Injection Well Location, Water Alternating Gas Injection, Primary Production, Secondary Production, Oil Recovery Facto, Conventional Reservoir

References

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[2]	Dou Lirong, Wang Jianjun, Cheng Dinsheng, Ran Xuefeng, Ernest N. T Rubondo, Robert Kasande, Abdul Byakagaba, Frank Mugisha, 2010. Geological conditions and petroleum exploration potential of the Albertine graben of Uganda. Acta geologica sinica-English edition/ Volume 78, issue 4.
[3]	www.oilinuganda.org/facts-faqs/uganda-oil-facts-faqs/how-much-oil-and-gas-does-uganda-have-and-where-is-it.html.
[4]	Rafael J. Kaczmarczyk, Professor Velisa Vesovic, Julio Herbas², Juan Del Castillo, 2011-2012. Approximation of primary, secondary, and tertiary recovery factors in viscous oil reservoirs deposited in Ugandan sands. ¹Imperial College, Tullow oil.
[5]	X. G Lu, S. Q Sun, J. Xu, 2010. Application of thermal recovery and waterflood to heavy and extra-heavy oil reservoirs. SPE 130758 presented at the CPE/SPE international oil and gas conference and exhibition in Beijing, China.
[6]	Dr. Josephine Wapakhabulo, 2019. Uganda National Oil Company (UNOC), China National Offshore Oil cooperation (CNOOC) to begin joint oil exploration in 2019. http://www.oilinuganda.org/features/infrastructure/unoc-cnooc-to-begin-joint-oil-exploration-in-2019.html. Tuesday, 25^th September, 2018.
[7]	Joshua Lukaye and Micheal Okello, 2015. Geochemical characterization and correlation of crude oils and potential source rocks from the semliki, southern Lake Albert, and Kaisotonya basins in the Albertine graben, Uganda. Petroleum exploration and production, ministry of energy and mineral development, Uganda, Entebbe, Uganda. International conference and exhibition, Melbourne, Australia.
[8]	B. Tripathy, 1985. Water influx characteristics of tar barriers-their impact on injector locations. Arabian American oil co.
[9]	B. A. Ramirez, G. J. P. Joosten, M. P. Kaleta, P. P. Gelderblom, 2017. Model-based well location optimization-A robust approach. Shell international exploration and production, inc, Shell global solutions international. DOI: https://doi.org/10.2118/182632-MS. SPE-182632-MS.
[10]	Saurabh Singh, Deepak Devegowda, Bhabesh Deka, 2017. Quantification of recovery factors in downspaced wells: Application to the eagle ford shale. DOI: https://doi.org/10.2118/185748-MS. SPE-185748-MS.
[11]	K. C. Hong, 1991. Optimum well location for steam flooding steeply dipping reservoirs. Chevron oil field research co.
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[13]	Gary Hoare, Carolina Coll, 2018. Effect of small/medium scale reservoir heterogeneity on the effectiveness of water, gas, and water alternating gas WAG injection. London south bank university. DOI: https://doi.org/10.2118/190855-MS. SPE-190855-MS. SPE Europec featured at 80 ^th EAGE conference and exhibition, 11-14 June, Copenhagen, Denmark.
[14]	Tiago A. Siqueira, Rodrigo S. Iglesias, Marcelo J. Ketzer, 2017. Carbon dioxide injection in carbonate reservoirs-a review of CO₂ -Water-rock interaction studies. https://doi.org/10.1002/ghg.1693.
[15]	Chawarwan Khan, Robert Amin, Gary Madden, 2013. Carbon dioxide injection for enhanced gas recovery and storage. https://doi.org/10.1016/j.ejpe.2013.06.002. Egyptian journal of petroleum.
[16]	A. Alvarado and E. Manrique, 2010. Enhanced oil recovery field planning and development strategies. Burlington, MA/USA: Elsevier inc.
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APA Style

Marembo Micheal, Asasira Sonia. (2019). Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda. International Journal of Atmospheric and Oceanic Sciences, 2(2), 27-34. https://doi.org/10.11648/j.ijaos.20180202.12

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ACS Style

Marembo Micheal; Asasira Sonia. Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda. Int. J. Atmos. Oceanic Sci. 2019, 2(2), 27-34. doi: 10.11648/j.ijaos.20180202.12

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AMA Style

Marembo Micheal, Asasira Sonia. Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda. Int J Atmos Oceanic Sci. 2019;2(2):27-34. doi: 10.11648/j.ijaos.20180202.12

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@article{10.11648/j.ijaos.20180202.12,
  author = {Marembo Micheal and Asasira Sonia},
  title = {Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda},
  journal = {International Journal of Atmospheric and Oceanic Sciences},
  volume = {2},
  number = {2},
  pages = {27-34},
  doi = {10.11648/j.ijaos.20180202.12},
  url = {https://doi.org/10.11648/j.ijaos.20180202.12},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ijaos.20180202.12},
  abstract = {Uganda is naturally endowed with vast resources ranging from oil to precious stones including diamond among others. Venturing into exploration and development of these resources has recently taken a center stage. Currently, the Ugandan oil reservoir located in the Albertine region, Western Uganda has only been appraised and production has not begun. This study uses standard correlation equations, field analogs, and compares with existing literature to predict the future oil recovery potential of the Albertine reservoir using water flooding and water-alternating gas (WAG) as the enhanced oil recovery methods using Carbon dioxide as the injection gas. Field analogue results indicate that the oil recovery factor during primary production is 8% to 15% while the oil recovery factor during secondary production ranges from 18.2% to 62%. Simulation results show an oil recovery factor of 9.81% and 36.85% during primary and secondary production respectively. The optimum well location is 800ft from the producer with an oil recovery factor of 36.85%. Well location has an effect on over all oil recovery factor and higher recovery factor is achieved when the injection well is 800 ft from the producer. Water flooding yields 31.67% of the original oil in place (OOIP) while Carbon dioxide yields 62.30% of OOIP. When WAG injection process is preceded by waterflooding, the oil recovery factor is 5.57% higher than when WAG process is preceded by Carbon dioxide injection.},
 year = {2019}
}

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TY  - JOUR
T1  - Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda
AU  - Marembo Micheal
AU  - Asasira Sonia
Y1  - 2019/01/22
PY  - 2019
N1  - https://doi.org/10.11648/j.ijaos.20180202.12
DO  - 10.11648/j.ijaos.20180202.12
T2  - International Journal of Atmospheric and Oceanic Sciences
JF  - International Journal of Atmospheric and Oceanic Sciences
JO  - International Journal of Atmospheric and Oceanic Sciences
SP  - 27
EP  - 34
PB  - Science Publishing Group
SN  - 2640-1150
UR  - https://doi.org/10.11648/j.ijaos.20180202.12
AB  - Uganda is naturally endowed with vast resources ranging from oil to precious stones including diamond among others. Venturing into exploration and development of these resources has recently taken a center stage. Currently, the Ugandan oil reservoir located in the Albertine region, Western Uganda has only been appraised and production has not begun. This study uses standard correlation equations, field analogs, and compares with existing literature to predict the future oil recovery potential of the Albertine reservoir using water flooding and water-alternating gas (WAG) as the enhanced oil recovery methods using Carbon dioxide as the injection gas. Field analogue results indicate that the oil recovery factor during primary production is 8% to 15% while the oil recovery factor during secondary production ranges from 18.2% to 62%. Simulation results show an oil recovery factor of 9.81% and 36.85% during primary and secondary production respectively. The optimum well location is 800ft from the producer with an oil recovery factor of 36.85%. Well location has an effect on over all oil recovery factor and higher recovery factor is achieved when the injection well is 800 ft from the producer. Water flooding yields 31.67% of the original oil in place (OOIP) while Carbon dioxide yields 62.30% of OOIP. When WAG injection process is preceded by waterflooding, the oil recovery factor is 5.57% higher than when WAG process is preceded by Carbon dioxide injection.
VL  - 2
IS  - 2
ER  -

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Author Information

Marembo Micheal

College of Petroleum, China University of Petroleum, Beijing, China
Asasira Sonia

Faculty of Management Science and Engineering, Central University of Finance and Economics, Beijing, China

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APA Style

Marembo Micheal, Asasira Sonia. (2019). Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda. International Journal of Atmospheric and Oceanic Sciences, 2(2), 27-34. https://doi.org/10.11648/j.ijaos.20180202.12

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ACS Style

Marembo Micheal; Asasira Sonia. Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda. Int. J. Atmos. Oceanic Sci. 2019, 2(2), 27-34. doi: 10.11648/j.ijaos.20180202.12

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AMA Style

Marembo Micheal, Asasira Sonia. Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda. Int J Atmos Oceanic Sci. 2019;2(2):27-34. doi: 10.11648/j.ijaos.20180202.12

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@article{10.11648/j.ijaos.20180202.12,
  author = {Marembo Micheal and Asasira Sonia},
  title = {Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda},
  journal = {International Journal of Atmospheric and Oceanic Sciences},
  volume = {2},
  number = {2},
  pages = {27-34},
  doi = {10.11648/j.ijaos.20180202.12},
  url = {https://doi.org/10.11648/j.ijaos.20180202.12},
  eprint = {https://article.sciencepublishinggroup.com/pdf/10.11648.j.ijaos.20180202.12},
  abstract = {Uganda is naturally endowed with vast resources ranging from oil to precious stones including diamond among others. Venturing into exploration and development of these resources has recently taken a center stage. Currently, the Ugandan oil reservoir located in the Albertine region, Western Uganda has only been appraised and production has not begun. This study uses standard correlation equations, field analogs, and compares with existing literature to predict the future oil recovery potential of the Albertine reservoir using water flooding and water-alternating gas (WAG) as the enhanced oil recovery methods using Carbon dioxide as the injection gas. Field analogue results indicate that the oil recovery factor during primary production is 8% to 15% while the oil recovery factor during secondary production ranges from 18.2% to 62%. Simulation results show an oil recovery factor of 9.81% and 36.85% during primary and secondary production respectively. The optimum well location is 800ft from the producer with an oil recovery factor of 36.85%. Well location has an effect on over all oil recovery factor and higher recovery factor is achieved when the injection well is 800 ft from the producer. Water flooding yields 31.67% of the original oil in place (OOIP) while Carbon dioxide yields 62.30% of OOIP. When WAG injection process is preceded by waterflooding, the oil recovery factor is 5.57% higher than when WAG process is preceded by Carbon dioxide injection.},
 year = {2019}
}

Copy | Download

TY  - JOUR
T1  - Investigation on the Water-Alternating Gas Oil Recovery Potential Based on Injection Well Location for the Albertine Oil Reservoir, Uganda
AU  - Marembo Micheal
AU  - Asasira Sonia
Y1  - 2019/01/22
PY  - 2019
N1  - https://doi.org/10.11648/j.ijaos.20180202.12
DO  - 10.11648/j.ijaos.20180202.12
T2  - International Journal of Atmospheric and Oceanic Sciences
JF  - International Journal of Atmospheric and Oceanic Sciences
JO  - International Journal of Atmospheric and Oceanic Sciences
SP  - 27
EP  - 34
PB  - Science Publishing Group
SN  - 2640-1150
UR  - https://doi.org/10.11648/j.ijaos.20180202.12
AB  - Uganda is naturally endowed with vast resources ranging from oil to precious stones including diamond among others. Venturing into exploration and development of these resources has recently taken a center stage. Currently, the Ugandan oil reservoir located in the Albertine region, Western Uganda has only been appraised and production has not begun. This study uses standard correlation equations, field analogs, and compares with existing literature to predict the future oil recovery potential of the Albertine reservoir using water flooding and water-alternating gas (WAG) as the enhanced oil recovery methods using Carbon dioxide as the injection gas. Field analogue results indicate that the oil recovery factor during primary production is 8% to 15% while the oil recovery factor during secondary production ranges from 18.2% to 62%. Simulation results show an oil recovery factor of 9.81% and 36.85% during primary and secondary production respectively. The optimum well location is 800ft from the producer with an oil recovery factor of 36.85%. Well location has an effect on over all oil recovery factor and higher recovery factor is achieved when the injection well is 800 ft from the producer. Water flooding yields 31.67% of the original oil in place (OOIP) while Carbon dioxide yields 62.30% of OOIP. When WAG injection process is preceded by waterflooding, the oil recovery factor is 5.57% higher than when WAG process is preceded by Carbon dioxide injection.
VL  - 2
IS  - 2
ER  -

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