A review of the current progress of CO2 injection EOR and carbon storage in shale oil reservoirs

Jia, Bao; Tsau, Jyun‐Syung; Barati, Reza

doi:10.1016/j.fuel.2018.08.103

Cited by 505 publications

(271 citation statements)

References 112 publications

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“…41,42 An empirical correlation proposed by Wilke and Chang was used to estimate the diffusion coefficient in mono-phase fluid, which is the most general and best-know equation. [43][44][45] This equation is expressed by: where, the subscript k means the fluid phase (ie, liquid phase and vapor phase). Based on the phase equilibrium state and Equation (9), the CO 2 diffusion coefficients in the respective liquid and vapor phases under different fluid systems were obtained and are shown in Figure 5.…”

Section: The Phase Equilibrium States Have Shown In Figures 3 Andmentioning

confidence: 99%

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Wang

et al. 2019

Energy Science & Engineering

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This paper investigates the CO2/N2 injection process in tight oil reservoirs considering the confinement effect. To study the microscopic physical mechanisms, the confinement effect is characterized by properties shift and capillarity and introduced into the flash calculation to obtain the phase equilibrium of mixture fluids (tight oil/CO2/N2) in tight porous media. The results indicate that the injected nitrogen gas could effectively maintain the reservoir pressure, while it also weakens the effects of the CO2 injection recovery mechanisms, notably diffusivity and viscosity reduction. In addition, a dual‐pore tight oil reservoir model is set up to investigate the CO2/N2 injection with ultra‐low permeability and hydraulic fracturing. The basic CO2 injection parameters are optimized by the orthogonal method. Based on CO2 injection process, three injection schemes of CO2/N2 injection, which are mixed‐gas injection, CO2‐alternating‐N2 (CAN) injection, and N2‐alternating‐CO2 (NAC) injection, were investigated and a comparative analysis was made for the pressure distribution, CO2 mole fraction distribution, and cumulative oil production. Based on this analysis, the CAN injection process proved to be the best injection scheme. A parametric analysis further suggested that the nitrogen gas injection rate was the most important factor. Besides, the effect of gravity drainage, reservoir permeability, nature fractures, and permeability heterogeneity on the oil production of CAN injection process were also investigated in detail. The results show that tight oil reservoir with better vertical connectivity, poor fracture growth, and higher heterogeneity is more favorable for the CO2/N2 injection process.

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Section: The Phase Equilibrium States Have Shown In Figures 3 Andmentioning

confidence: 99%

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Wang

et al. 2019

Energy Science & Engineering

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“…Despite of the huge CBM and shale gas reserves in the unconventional reservoirs, how to improve recovery factors from unconventional oil and gas reservoirs is an inevitable problem. Therefore, it is necessary to conduct research on unconventional oil and gas reservoirs [26]. In order to improve the effect of hydraulic fracturing, primary structural coal was selected to study the damage to coal permeability caused by fracturing fluid.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on the Damage of Artificial Fracture Permeability in Coal during the Flow Back of Guar-Based Fracturing Fluid

et al. 2020

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After the completion of fracturing operation in coalbed methane (CBM), the fracturing fluid needs to flow back to the ground in time to reduce the damage to the coal reservoir. The damage of guar-based fracturing fluid to the coal reservoir has an adverse effect on the fracturing stimulation. A series of flow experiments were carried out with the unconventional natural gas reservoir damage evaluation equipment. This paper investigates the evolution of fracture permeability in coal samples during the process of hydroxypropyl guar (HPG) fracturing fluid flow back. The experimental results show that the fracturing fluid concentration, proppant type, proppant particle size, and proppant concentration all affect fracture permeability. The high concentration of fracturing fluid caused irreversible damage to fracture permeability of coal samples. With the increase of fracturing fluid concentration, the permeability damage rate increased from 65.31% to 84.57%, and the damage degree was strong. KCL brine flushing can only decrease the damage rate of coal sample fracture permeability within a certain range. The proppant embedment and the generation of pulverized coal exacerbated the damage of fracture permeability. The research results can be beneficial for optimizing the type and performance of fracturing fluid for hydraulic fracturing in CBM reservoir.

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“…1-4 CO 2 has good solubility in crude oil, and the solubility of CO 2 increases with the increase of pressure. 5,6 Under reservoir conditions, CO 2 can dissolve in crude oil, expanding crude oil volume, reducing the oil viscosity and oil-gas interfacial tension, and increasing crude oil mobility. 7,8 All these mechanisms provide favorable conditions for crude oil production.…”

Section: Introductionmentioning

confidence: 99%

Experimental investigation of shale oil recovery from Qianjiang core samples by the CO₂ huff-n-puff EOR method

Wang

et al. 2019

RSC Adv.

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CO 2 Huff-n-Puff (HnP) is an effective technique for enhancing oil recovery (EOR) that can be applied to shale oil reservoirs faced with poor natural productivity and low water injectivity. The main objective of this study is to investigate the interactions of CO 2 and formation crude oil, and evaluate the CO 2 HnP performance in shale oil reservoirs in the Qianjiang depression in China. In this study, the variation rules of oil phase behavior, viscosity, saturation pressure, and swelling factor at different CO 2 contents of 0 to 65% were studied. A series of HnP experiments were conducted. The factors affecting the oil recovery were discussed, and Nuclear Magnetic Resonance (NMR) tests were conducted on core samples at different stages of the HnP process. The results show that the injected CO 2 can make an positive change in the crude oil phase behavior. The oil-gas two-phase region enlarges and the saturation pressure increases as more CO 2 is dissolved in the formation oil, which is beneficial to oil production. The dissolution of CO 2 in the oil phase increased the oil swelling degree by 1.492 times, and the viscosity decreased from 1.944 to 0.453 mPa s. The HnP experimental results demonstrate that the soaking time should be determined based on the injection pressure. Miscible conditions is a viable option for CO 2 HnP as 10% more oil can be produced using miscible HnP and save more than half of the soaking time.The results illustrate that fracture is the most important factor affecting oil recovery, and the performance of HnP EOR on core samples with fractures is almost 25% better than those without fractures. However, the core matrix permeability has an almost negligible effect on the performance of CO 2 HnP. The NMR tests show that the oil recovered in the first cycle was dominated by macropores and mesopores, followed by small pores. In the latter HnP cycles, the oil in small pores and micropores becomes the main oil-producing area. This study may provide a better understanding of the CO 2 HnP enhanced recovery strategy for shale reservoirs.

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A review of the current progress of CO2 injection EOR and carbon storage in shale oil reservoirs

Cited by 505 publications

References 112 publications

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Experimental Study on the Damage of Artificial Fracture Permeability in Coal during the Flow Back of Guar-Based Fracturing Fluid

Experimental investigation of shale oil recovery from Qianjiang core samples by the CO₂ huff-n-puff EOR method

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A review of the current progress of CO2 injection EOR and carbon storage in shale oil reservoirs

Cited by 505 publications

References 112 publications

Investigation of CO2/N2 injection in tight oil reservoirs with confinement effect

Investigation of CO2/N2 injection in tight oil reservoirs with confinement effect

Experimental Study on the Damage of Artificial Fracture Permeability in Coal during the Flow Back of Guar-Based Fracturing Fluid

Experimental investigation of shale oil recovery from Qianjiang core samples by the CO2 huff-n-puff EOR method

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Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Investigation of CO₂/N₂ injection in tight oil reservoirs with confinement effect

Experimental investigation of shale oil recovery from Qianjiang core samples by the CO₂ huff-n-puff EOR method