Numerical Optimisation of CO₂ Injection in a Sandstone Reservoir
This paper presents a study on the numerical optimisation of CO2 injection in sandstone reservoirs to maximise oil recovery. Using PETREL and CMG-GEM, the research explores various injection strategies, including Water-Alternating-Gas (WAG), miscible CO2 , and CO2-N2 injection. The model...
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| Main Authors: | , |
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| Format: | Article |
| Language: | English |
| Published: |
UTP Press
2024-12-01
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| Series: | Platform, a Journal of Engineering |
| Subjects: | |
| Online Access: | https://mysitasi.mohe.gov.my/uploads/get-media-file?refId=fb63a19a-8148-490d-9254-45f40460a2b9 |
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| Summary: | This paper presents a study on the numerical optimisation of CO2
injection in sandstone reservoirs to maximise
oil recovery. Using PETREL and CMG-GEM, the research explores various injection strategies, including
Water-Alternating-Gas (WAG), miscible CO2
, and CO2-N2
injection. The model was created based on a publicly available
research paper on an onshore oil field in the Sirt Basin, Libya. The model was validated using historical production data
from January 1967 to January 2003, resulting in a Global History Matching Error of 10.37%, indicating satisfactory
accuracy. For miscible CO2
injection, the optimal maximum injection rate was 30 MMcfd. In the case of WAG, a 6-month
cycle with a maximum water injection rate of 1000 bbl/d was determined to be most effective. For CO2-N2
injection,
a mixture of 50% CO2
and 50% N2
at 30 MMcfd was used. In this high-pressure reservoir, CO2
and CO2-N2
injections
yielded higher recovery rates than WAG despite the lower mobility of gases. The high reservoir pressure of 4000 psia and
low-pressure differentials during injection made gas injection particularly effective due to compressibility. The findings
underscore the significance of customising injection strategies to reservoir conditions to maximise oil production. |
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| ISSN: | 2636-9877 |