Simulation Study of CO2 EOR and Storage Potential in a North Sea Reservoir

Karimaie, Hassan; Nazarian, Bamshad; Aurdal, T.; Nøkleby, Pål Helge; Hansen, O.

doi:10.1016/j.egypro.2017.03.1843

Cited by 27 publications

(12 citation statements)

References 8 publications

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“…Furthermore, in depleted reservoirs, high amount of CO 2 was trapped by residual trapping mechanism during CO 2 sequestration. Karimaie et al (2017) conducted a simulation investigation on carbon dioxide enhanced oil recovery and storage potential in a North Sea reservoir. This simulation study was performed by the authors to quantify the CO 2 flooding performance on oil recovery and the results was compared with the performance of the water injection.…”

Section: Introductionmentioning

confidence: 99%

Influence of CO2 retention mechanism storage in Alberta tight oil and gas reservoirs at Western Canadian Sedimentary Basin, Canada: hysteresis modeling and appraisal

Rajkumar

Pranesh²,

Kesavakumar³

2020

J Petrol Explor Prod Technol

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Rapid combustion of fossil fuels in huge quantities resulted in the enormous release of CO2 in the atmosphere. Subsequently, leading to the greenhouse gas effect and climate change and contemporarily, quest and usage of fossil fuels has increased dramatically in recent times. The only solution to resolve the problem of CO2 emissions to the atmosphere is geological/subsurface storage of carbon dioxide or carbon capture and storage (CCS). Additionally, CO2 can be employed in the oil and gas fields for enhanced oil recovery operations and this cyclic form of the carbon dioxide injection into reservoirs for recovering oil and gas is known as CO2 Enhanced Oil and Gas Recovery (EOGR). Hence, this paper presents the CO2 retention dominance in tight oil and gas reservoirs in the Western Canadian Sedimentary Basin (WCSB) of the Alberta Province, Canada. Actually, hysteresis modeling was applied in the oil and gas reservoirs of WCSB for sequestering or trapping CO2 and EOR as well. Totally, four cases were taken for the investigation, such as WCSB Alberta tight oil and gas reservoirs with CO2 huff-n-puff and flooding processes. Actually, Canada has complex geology and therefore, implicate that it can serve as a promising candidate that is suitable and safer place for CO2 storage. Furthermore, injection pressure, time, rate (mass), number of cycles, soaking time, fracture half-length, conductivity, porosity, permeability, and initial reservoir pressure were taken as input parameters and cumulative oil production and oil recovery factor are the output parameters, this is mainly for tight oil reservoirs. In the tight gas reservoirs, only the output parameters differ from the oil reservoir, such as cumulative gas production and gas recovery factor. Reservoirs were modelled to operate for 30 years of oil and gas production and the factor year was designated as decision-making unit (DMU). CO2 retention was estimated in all four models and overall the gas retention in four cases showed a near sinusoidal behavior and the variations are sporadic. More than 80% CO2 retention in these tight formations were achieved and the major influencing factors that govern the CO2 storage in these tight reservoirs are injection pressure, time, mass, number of cycles, and soaking time. In general, the subsurface geology of the Canada is very complex consisting with many structural and stratigraphic layers and thus, it offers safe location for CO2 storage through retention mechanism and increasing the efficiency and reliability of oil and gas extraction from these complicated subsurface formations.

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Section: Introductionmentioning

confidence: 99%

Influence of CO2 retention mechanism storage in Alberta tight oil and gas reservoirs at Western Canadian Sedimentary Basin, Canada: hysteresis modeling and appraisal

Rajkumar

Pranesh²,

Kesavakumar³

2020

J Petrol Explor Prod Technol

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“…Another way is to delay gas channeling by adding a slug agent, and the commonly used slugs, such as water and surfactant, can effectively control the mobility of CO 2 and play a role in hindering gas fingering. 16 Adding water slug to CO 2 huff-n-puff is a common method, and water alternating gas (WAG) can effectively improve the development effect. 17 O'Brien et al carried out a comparative experiment of WAG and CO 2 flooding through laboratory experiments.…”

Section: Introductionmentioning

confidence: 99%

Effect of CO₂ Huff-n-Puff Mode with a Horizontal Well on Shale Oil Recovery: A Three-Dimensional Experimental Study

Yao

Zhao

et al. 2023

Energy Fuels

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After conventional development, there is still a significant amount of residual oil as a result of the poor porosity and permeability characteristics of shale reservoirs. Although CO 2 flooding is one of the most reasonable recovery techniques, it is affected by a serious sweep efficiency issue. In this paper, six CO 2 huff-n-puff cooperative combination methods were established with the aid of three-dimensional physical simulation equipment, including CO 2 huff-n-puff (HNP), water-disturbance-assisted CO 2 huff-n-puff (WD-HNP), surfactant-and water-disturbance-assisted CO 2 huff-n-puff (SWD-HNP), pumping-production-assisted CO 2 huff-n-puff (PP-HNP), water-disturbance-assisted CO 2 huff-n-puff after pumping production (WDP-HNP), and surfactant-and water-disturbance-assisted CO 2 huff-n-puff after pumping production (SWDP-HNP). The displacement characteristics, utilization law, and development effect were investigated. CO 2 huff-n-puff requires more gas injection quickly, and low permeability and pressure difference can easily cause irregular gas channeling, showing the arc linear flooding pattern. Water disturbance can significantly delay the rapid breakthrough, so that the displacement edge shows the radial flooding pattern. The effect of pumping production on the displacement is not obvious, and the leading edge still shows an oval-shaped flooding pattern. Surfactant assistance improves the gas injection ability, eventually demonstrating a plane steady flooding pattern. In comparison to HNP, the average enhancement degree of water injection disturbance, pumping production, and surfactant assistance to the utilization extent is 6.61, 1.82, and 8.93% respectively. Meanwhile, SWDP-HNP had the highest oil recovery (33.35%) among all modes. By comparison of effective productivity, it revealed that about 12% of the lifting range is helped by surfactant assistance, followed by a water injection disturbance lifting amplitude of 5.5%, while pumping production only led to a 3% improvement. With the combination of all development effect evaluation indicators, SWD-HNP is a reasonable displacement method to improve shale reservoir recovery in this study.

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Section: Introductionmentioning

confidence: 99%

“…G lobal and regional climate change caused by greenhouse gas emissions is still stimulating interest in the development of various technologies to reduce the concentrations of carbon dioxide (CO 2 ) in the atmosphere. [1][2][3][4][5] Many countries have set targets for reducing the emissions of greenhouse gases to mitigate global warming. Among these countries, and top on the list of CO 2 emission producers in the world, China aims to reduce 40%-45% of its CO 2 emissions per unit GDP by 2020, based on the 2005 level.…”

Section: Introductionmentioning

confidence: 99%

Potential evaluation of CO₂ EOR and storage in oilfields of the Pearl River Mouth Basin, northern South China Sea

Liu

et al. 2018

Greenhouse Gases

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The Pearl River Mouth Basin (PRMB) is the largest petroliferous sedimentary basin in the northern South China Sea. It is near the coastal economic zone of Guangdong province where a large number of CO2 emission sources are located. Carbon dioxide enhanced oil recovery (EOR) represents an opportunity to promote offshore carbon capture, utilization and storage (CCUS) deployment because CO2 flooding offers a method to recover additional oil while simultaneously sequestering anthropogenic CO2. In this paper, a comprehensive multiparameter ‘quick look’ and potential evaluation method was proposed to screen and assess offshore CO2 EOR potential. A screening scheme for the CO2 EOR potential of reservoirs of the PRMB was also proposed using additional parameters, including reservoir properties and engineering design incorporating a dimensionless screen model and calculations. The results show that the suitability of reservoirs for CO2 EOR and storage varies and could be categorized into four priority grades. Approximately 30 of the oil reservoirs from 10 oilfields were preferentially identified by applying the screening method for reservoirs with predicted higher ultimate recovery potentials. It was predicted that 3227 × 104 t of additional oil could be produced from these reservoirs and that 3617 × 104 t of CO2 could be simultaneously stored. The sensitivity analysis shows that injection pressure (Pinj) would be more sensitive than production pressure (Pp) and well distance (L) on the CO2 EOR and storage efficiency, indicating that EOR operations with higher Pinj may improve oil production. The prospective reservoirs include those candidates with suitability grades of I and II from the Lufeng (LF) and Huizhou (HZ) oilfield clusters, where 1164 × 104 t of additional oil could be produced and 1464 × 104 t of CO2 stored with CO2 EOR. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Simulation Study of CO2 EOR and Storage Potential in a North Sea Reservoir

Cited by 27 publications

References 8 publications

Influence of CO2 retention mechanism storage in Alberta tight oil and gas reservoirs at Western Canadian Sedimentary Basin, Canada: hysteresis modeling and appraisal

Influence of CO2 retention mechanism storage in Alberta tight oil and gas reservoirs at Western Canadian Sedimentary Basin, Canada: hysteresis modeling and appraisal

Effect of CO₂ Huff-n-Puff Mode with a Horizontal Well on Shale Oil Recovery: A Three-Dimensional Experimental Study

Potential evaluation of CO₂ EOR and storage in oilfields of the Pearl River Mouth Basin, northern South China Sea

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Simulation Study of CO2 EOR and Storage Potential in a North Sea Reservoir

Cited by 27 publications

References 8 publications

Influence of CO2 retention mechanism storage in Alberta tight oil and gas reservoirs at Western Canadian Sedimentary Basin, Canada: hysteresis modeling and appraisal

Influence of CO2 retention mechanism storage in Alberta tight oil and gas reservoirs at Western Canadian Sedimentary Basin, Canada: hysteresis modeling and appraisal

Effect of CO2 Huff-n-Puff Mode with a Horizontal Well on Shale Oil Recovery: A Three-Dimensional Experimental Study

Potential evaluation of CO2 EOR and storage in oilfields of the Pearl River Mouth Basin, northern South China Sea

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Effect of CO₂ Huff-n-Puff Mode with a Horizontal Well on Shale Oil Recovery: A Three-Dimensional Experimental Study

Potential evaluation of CO₂ EOR and storage in oilfields of the Pearl River Mouth Basin, northern South China Sea