Numerical modeling including hysteresis properties for CO2 storage in Tubåen formation, Snøhvit field, Barents Sea

Pham, Thi Hai Van; Maast, Tom Erik; Hellevang, Helge; Aagaard, Per

doi:10.1016/j.egypro.2011.02.308

Cited by 15 publications

(7 citation statements)

References 11 publications

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“…Most importantly, the CO 2 plume has been restricted to due tight (less porous) formations and this it ensures the storage safety and assurance of leakage prevention. Actually, reservoir hysteresis properties can reduce the plume migration during CO 2 injection and storage (Pham et al 2011). Therefore, on the basis of the above modelling results, it can be explicitly stated that the Western Canada Sedimentary Basin exhibits an attractive and secure storage sites for CO 2 sequestration and subsurface fuel (reservoir fluids) recovery as well.…”

Section: Discussionmentioning

confidence: 92%

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: Discussionmentioning

confidence: 92%

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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“…In other related studies, Pham et al (2011) developed a numerical model to estimate the amount of CO 2 that was proposed to be injected into the Tubåen formation from the Snohvit field, Barents Sea (Fig. 2).…”

Section: Determination Of the Co 2 Storage Capacitymentioning

confidence: 99%

“…Klara et al (2003) conducted an integrated collaborative technology program for CO 2 sequestration in a geologic formation. The main objective (Pham et al 2011) was to predict the stored volume of CO 2 left in the formation since the remaining amount contributed toward global warming. They studied and proposed a flowchart for better accentuation.…”

Section: Determination Of the Co 2 Storage Capacitymentioning

confidence: 99%

Carbon dioxide sequestration in underground formations: review of experimental, modeling, and field studies

Kalam

Olayiwola

Al-Rubaii

et al. 2020

J Petrol Explor Prod Technol

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Carbon dioxide has gradually found widespread usage in the field of science and engineering while various efforts have focused on ways to combat the menace resulting from the release of this compound in the atmosphere. A major approach to combating this release is by storage in various geological formations ranging from depleted reservoir types such as saline aquifers to other carbon sinks. In this research study, we reviewed the experimental, modeling, and field studies related to the underground storage of CO2. A considerable amount of research has been conducted in simulating and modeling CO2 sequestration in the subsurface. This review highlights some of the latest contributions. Additionally, the impact of CO2 sequestration on its surroundings due to chemical reactions, adsorption, capillarity, hysteresis, and wettability were reviewed. Some major challenges associated with CO2 injection have also been highlighted. Finally, this work presents a brief history of selected field scale projects such as Sleipner, Weyburn, In Salah, Otway Basin, Snøhvit, Alberta, Boundary Dam, Cranfield, and Ketzin. Thus, this study provides a guide of the CO2 storage process from the perspectives of experimental, modelling, and existing field studies.

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“…Existing studies focus on fluid flow and caprock integrity by comparing overpressure with a limiting fracture pressure in addition to evaluating potential leakage pathways (e.g. Geel et al, 2006;der Meer et al, 2006;Shell, 2008;Eigestad et al, 2009;Estublier and Lackner, 2009;Hortle et al, 2009;Gapillou et al, 2009;Oldenburg et al, 2011;Pham et al, 2011;Jenkins et al, 2012b;MUSTANG, 2014a,b;Buscheck et al, 2016;Marshall et al, 2017). Implicit fracturing in the context of caprock integrity was investigated for the In Salah site (Gor et al, 2013a;Gor and Prevost, 2013;Gor et al, 2013b;Preisig and Prévost, 2011;, for the Goldeneye field (Peterhead) (Akhurst et al, 2017;McDermott et al, 2016;Davison et al, 2012), for the Lacq project (Pourtoy et al, 2013), and for a generic depleted Dutch field (Orlic et al, 2011a).…”

Section: Caprock Integrity Modelling Studies Of the Depleted Pilot Sitesmentioning

confidence: 99%

Caprock integrity and public perception studies of carbon storage in depleted hydrocarbon reservoirs

Paluszny

Graham

Daniels

et al. 2020

International Journal of Greenhouse Gas Control

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Capture and subsurface storage of CO 2 is widely viewed as being a necessary component of any strategy to minimise and control the continued increase in average global temperatures. Existing oil and gas reservoirs can be re-used for carbon storage, providing a substantial fraction of the vast amounts of subsurface storage space that will be required for the implementation of carbon storage at an industrial scale. Carbon capture and storage (CCS) in depleted reservoirs aims to ensure subsurface containment, both to satisfy safety considerations, and to provide confidence that the containment will continue over the necessary timescales. Other technical issues that need to be addressed include the risk of unintended subsurface events, such as induced seismicity. Minimisation of these risks is key to building confidence in CCS technology, both in relation to financing/liability, and the development and maintenance of public acceptance. These factors may be of particular importance with regard to CCS projects involving depleted hydrocarbon reservoirs, where the mechanical effects of production activities must also be considered. Given the importance of caprock behaviour in this context, several previously published geomechanical caprock studies of depleted hydrocarbon reservoirs are identified and reviewed, comprising experimental and numerical studies of fourteen CCS pilot sites in depleted hydrocarbon reservoirs, in seven countries (

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Numerical modeling including hysteresis properties for CO2 storage in Tubåen formation, Snøhvit field, Barents Sea

Cited by 15 publications

References 11 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

Carbon dioxide sequestration in underground formations: review of experimental, modeling, and field studies

Caprock integrity and public perception studies of carbon storage in depleted hydrocarbon reservoirs

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