Experimental Investigations on the Flow Dynamics and Abandonment Pressure for CO2 Sequestration and Oil Recovery in Artificially Fractured Cores

Trivedi, Japan; Babadagli, Tayfun

doi:10.2118/134245-pa

Cited by 20 publications

(9 citation statements)

References 12 publications

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“…In recent years, CO 2 huff 'n' puff has proven to be effective in tight oil recovery. Trivedi and Babadagli (Trivedi and Babadagli 2010) experimentally studied oil recovery by CO 2 injection in artificially fractured cores and found that the pressure blowdown could increase oil recovery significantly until a certain critical pressure. Wang et al (Wang et al 2020) studied the CO 2 huff 'n' puff process with staged fracturing wells by large-scale physical simulation experiments and found that CO 2 huff 'n' puff can improve the development effect of tight oil recovery.…”

Section: Introductionmentioning

confidence: 99%

Tight oil reservoir production characteristics developed by CO2 huff ‘n’ puff under well pattern conditions

Xia¹,

Wang²,

Rui

et al. 2022

J Petrol Explor Prod Technol

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Tight oil reservoirs have poor physical properties, and the problems including rapid oil rate decline and low oil recovery degree are quite common after volume fracturing. To obtain a general understanding of tight oil reservoir production improvement by CO2 huff ‘n’ puff, the high-pressure physical properties of typical tight oil samples are measured. Combining the typical reservoir parameters, the production characteristics of the tight oil reservoir developed by the CO2 huff ‘n’ puff are numerically studied on the basis of highly fitted experimental results. The results show that: (1) during the natural depletion stage, the oil production rate decreases rapidly and the oil recovery degree is low because of the decrease in oil displacement energy and the increase in fluid seepage resistance. (2) CO2 huff ‘n’ puff can improve the development effect of tight oil reservoirs by supplementing reservoir energy and improving oil mobility, but the development effect gradually worsens with increasing cycle number. (3) The earlier the CO2 injection timing is, the better the development effect of the tight reservoir is, but the less sufficient natural energy utilization is. When carrying out CO2 stimulation, full use should be made of the natural energy, and the appropriate injection timing should be determined by comprehensively considering the formation-saturation pressure difference and oil production rate. The research results are helpful for strengthening the understanding of the production characteristics of tight oil reservoirs developed by CO2 huff ‘n’ puff.

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Section: Introductionmentioning

confidence: 99%

Tight oil reservoir production characteristics developed by CO2 huff ‘n’ puff under well pattern conditions

Xia¹,

Wang²,

Rui

et al. 2022

J Petrol Explor Prod Technol

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“…CO 2 EOR and storage lower the cost of geological CO 2 storage by recovering incremental oil, which is more attractive in mature oilfields. CO 2 EOR and storage has also been studied for fractured reservoirs in the form of immiscible or miscible gas injections [1][2][3][4][5][6]. The Western Canadian Sedimentary Basin (WCSB), where many oil pools are near depletion, can be one of the favorable CO 2 storage targets where most of the required infrastructure is already in place [7][8][9].…”

Section: Introductionmentioning

confidence: 99%

CO2 Foam and CO2 Polymer Enhanced Foam for Heavy Oil Recovery and CO2 Storage

Telmadarreie

Trivedi

2020

Energies

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Enhanced oil recovery (EOR) from heavy oil reservoirs is challenging. High oil viscosity, high mobility ratio, inadequate sweep, and reservoir heterogeneity adds more challenges and severe difficulties during any EOR method. Foam injection showed potential as an EOR method for challenging and heterogeneous reservoirs containing light oil. However, the foams and especially polymer enhanced foams (PEF) for heavy oil recovery have been less studied. This study aims to evaluate the performance of CO2 foam and CO2 PEF for heavy oil recovery and CO2 storage by analyzing flow through porous media pressure profile, oil recovery, and CO2 gas production. Foam bulk stability tests showed higher stability of PEF compared to that of surfactant-based foam both in the absence and presence of heavy crude oil. The addition of polymer to surfactant-based foam significantly improved its dynamic stability during foam flow experiments. CO2 PEF propagated faster with higher apparent viscosity and resulted in more oil recovery compared to that of CO2 foam injection. The visual observation of glass column demonstrated stable frontal displacement and higher sweep efficiency of PEF compared to that of conventional foam. In the fractured rock sample, additional heavy oil recovery was obtained by liquid diversion into the matrix area rather than gas diversion. Aside from oil production, the higher stability of PEF resulted in more gas storage compared to conventional foam. This study shows that CO2 PEF could significantly improve heavy oil recovery and CO2 storage.

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“…They showed the oil recovery may decrease far above the miscibility. Trivedi et al [3,4] also conducted experimental work about effect of CO 2 injection rate at various miscibility conditions in fractured reservoir. Kulkarni et al [5] reported gravity drainage effect for Gas Assisted Gravity Drainage (GAGD) process under immiscible and miscible conditions.…”

Section: Introductionmentioning

confidence: 99%

“…Nasrabadi et al [6] conducted the simulation study to investigate the effect of density in the 2D vertical reservoir and shown significant effect of gravity and heterogeneity. Although a number of researchers [1][2][3][4][5][6][7][8][9][10] have investigated about CO 2 flooding under the various miscibility conditions and the gravity drainage mechanism, none of researches have been done in vertical oil reservoir.…”

Section: Introductionmentioning

confidence: 99%

Effect of Miscibility Condition for CO2 Flooding on Gravity Drainage in 2D Vertical System

Kim¹

2014

J Pet Environ Biotechnol

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In CO 2 flooding process, gravity drainage and miscibility condition are the main factors on the efficiency of oil recovery. In this study, we observed oil recovery for different miscibility conditions in vertical oil reservoir. This was investigated in two dimensional vertical sandstone slab, where unstable gravity drainage phenomena can be formed. CO 2 is injected at bottom into 100% saturated with oil and production port is open at top of the system. We have performed a series of experiments using continuous CO 2 flooding for immiscible and near-miscible conditions. From the experimental results, oil recovery at near-miscible condition is 3.77 times greater than at immiscible condition, particularly in vertical system. It indicated that applying the immiscible CO 2 flooding is ineffective because of gravity override of CO 2 and generation of CO 2 channel at upper side in vertical reservoir. Meanwhile, the results revealed that oil recovery increases considerably once miscibility is reached at outlet. That is, miscibility condition is found to be a sensitive factor on oil recovery particularly in vertical oil reservoir.

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Experimental Investigations on the Flow Dynamics and Abandonment Pressure for CO2 Sequestration and Oil Recovery in Artificially Fractured Cores

Cited by 20 publications

References 12 publications

Tight oil reservoir production characteristics developed by CO2 huff ‘n’ puff under well pattern conditions

Tight oil reservoir production characteristics developed by CO2 huff ‘n’ puff under well pattern conditions

CO2 Foam and CO2 Polymer Enhanced Foam for Heavy Oil Recovery and CO2 Storage

Effect of Miscibility Condition for CO2 Flooding on Gravity Drainage in 2D Vertical System

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