Evaluation of CO2 utilization and storage potential in the Jimsar shale play from an optimization study

Tang, Weiyu; Peng, Zesen; Sheng, James J.

doi:10.1016/j.geoen.2023.211607

Cited by 11 publications

(4 citation statements)

References 30 publications

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“…In addition, the implementation of the CO 2 huff and puff project can realize geological storage of CO 2 and alleviate the increasingly serious greenhouse gas emission problem. It has the dual effects of economic benefit and environmental protection, and it is of great significance for the realization of national carbon peak and carbon neutralization. − …”

Section: Introductionmentioning

confidence: 99%

Characteristics of Crude Oil Production in Microscopic Pores of CO₂ Huff and Puff in Shale Oil Reservoirs

Song,

Chang,

Guan

et al. 2024

Energy Fuels

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The conversion coefficient C between relaxation time T 2 value and pore size was calibrated by a high-pressure mercury injection experiment, low-temperature nitrogen adsorption experiment, and NMR experiment for clarifying the effect of CO 2 huff and puff on the production characteristics of crude oil in shale micronano pores. Then, the effects of huff and puff rounds, the soaking time, and injection pressure on the seepage law of crude oil in shale pores from the microscopic scale were studied. The results showed that the pore size of the main occurrence space of shale oil was mainly distributed in the range of 1−100 nm. The oil production of matrix/matrix-fractured shale mainly depended on the first two rounds. Combined with MRI imaging technology, in the initial stage, CO 2 mainly used the crude oil in the surrounding area of the core for matrix shale, and CO 2 mainly used the crude oil in the fracture and the surrounding area of the fracture for matrix-fractured shale. With the increase of huff and puff rounds, the crude oil inside the core was gradually utilized through CO 2 diffusion for matrix shale and matrix-fractured shale. Prolonging the soaking time could significantly improve the recovery degree of crude oil in small pores, which increased by 4.21%, but the lower limit of pore size was reduced by only 2−3.4 nm. Increasing the injection pressure could not only reduce the lower limit of pore size, which was reduced by 2.4−3.9 nm, but also effectively improve the recovery degree of crude oil in different pores. Compared with the matrix shale core, the matrix-fractured shale core was more sensitive to the soaking time and injection pressure. The research results could provide some reference and guidance for the field test of CO 2 huff and puff in shale reservoirs.

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Section: Introductionmentioning

confidence: 99%

Characteristics of Crude Oil Production in Microscopic Pores of CO₂ Huff and Puff in Shale Oil Reservoirs

Song,

Chang,

Guan

et al. 2024

Energy Fuels

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“…There are several distinct methods of CO 2 flooding. The huff and puff process [19,20], the CO 2 foam injection [21,22], and the water-alternating-gas (WAG) injection [16,[23][24][25] method are among the most well known. The latter approach is based on alternating periods of continuous water and gas injection through one group of wells and the oil extraction through another group of wells.…”

Section: Introductionmentioning

confidence: 99%

Monte Carlo Simulation of the CO2 Flooding Efficiency at a Core Scale for Different Oil Compositions

Andreeva,

Afanasyev

2024

Energies

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The evaluation of water-alternating-gas (WAG) efficiency and profitability is complicated by a large number of reservoir, operating, and economic parameters and constraints. This study aims at understanding the influence of the oil composition on different WAG injections. By employing compositional reservoir modeling and the Monte Carlo method to characterize the diversity of oils occurring in nature, we simulate the microscopic displacement efficiency of CO2 flooding when it is applied to both light- and heavy-oil reservoirs. We find that the economic performance of WAG in both miscible and immiscible scenarios is mainly characterized by the dimensionless injection rate and the oil density at surface conditions. Neither the bubble point pressure nor the minimum miscibility pressure can be used for the quantification of the optimal WAG parameters. We present our estimates of the best strategies for the miscible and immiscible injections and verify some of our previous results for randomly sampled oils. In particular, we demonstrate that CO2 flooding is better to apply at higher-dimensionless injection rates. We show that the injection of CO2 organized at a light-oil reservoir results in a higher profitability of WAG, although this comes at the cost of lower carbon storage efficiency.

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“…Processes 2024, 12, 912 2 of 15 Supercritical CO 2 fluid boasts a plethora of unique physical and chemical properties, setting it apart in various applications [6][7][8][9]. Its low viscosity, high diffusion coefficient, and near-zero surface tension make it a standout choice [10][11][12]. Since its introduction into the oil industry, CO 2 fracturing has showcased numerous advantages.…”

Section: Introductionmentioning

confidence: 99%

“…One of its standout benefits lies in the rapid flowback after fracturing, significantly reducing non-production periods for oil and gas, thereby enhancing economic returns [14]. Furthermore, the robust absorption capabilities enable CO 2 to displace methane molecules adsorbed in shale, thereby amplifying production and recovery efficiency while facilitating permanent CO 2 storage [12,[15][16][17]. Consequently, CO 2 -based fracturing technology is lauded as a promising new approach with expansive potential.…”

Section: Introductionmentioning

confidence: 99%

Further Investigation of CO2 Quasi-Dry Fracturing in Shale Reservoirs—An Experimental Study

Zheng,

Tang,

Wang

et al. 2024

Processes

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The physical properties of shale reservoirs are typically poor, necessitating the use of fracturing technology for effective development. However, the high clay content prevalent in shale formations poses significant challenges for conventional hydraulic fracturing methods. To address this issue, CO2-based fracturing fluid has been proposed as an alternative to mitigate the damage caused by water-based fracturing fluids. In this paper, the applicability of quasi-dry CO2 fracturing in shale reservoirs is examined from three key perspectives: the viscosity of CO2 fracturing fluid, the fracture characteristics induced by the CO2 fracture fluid, and the potential reservoir damage caused by the fracturing fluid. Firstly, the viscosity of CO2 fracturing fluid was determined by a rheological experiment. Rheological tests revealed that the viscosity of CO2 fracturing fluid was significantly influenced by the water–carbon ratio. Specifically, when the water–carbon ratio was 30:70, the maximum viscosity observed could reach 104 mPa·s. Moreover, increasing reservoir temperature resulted in decreased fracturing fluid viscosity, with a 40 °C temperature rise causing a 20% viscosity reduction. Secondly, matrix permeability tests were conducted to investigate permeability alteration during CO2 fracturing fluid invasion. Due to the weak acidity of CO2-based fracturing fluid, the permeability reduction induced by clay hydration was inhibited, and an increase in permeability was observed after a 3-day duration. However, the matrix permeability tends to decrease as the interaction time is prolonged, which means prolonged soaking time can still cause formation damage. Finally, triaxial fracturing experiments facilitated by a three-axis servo pressure device were conducted. The fracture properties were characterized using computed tomography (CT), and 3D reconstruction of fractured samples was conducted based on the CT data. The results demonstrate that CO2 fracturing fluid effectively activates weak cementation surfaces in the rock, promoting the formation of larger and more complex fractures. Hence, CO2 quasi-dry fracturing technology emerges as a method with significant potential, capable of efficiently stimulating shale reservoirs, although a reasonable soaking time is necessary to maximize hydrocarbon production.

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Evaluation of CO2 utilization and storage potential in the Jimsar shale play from an optimization study

Cited by 11 publications

References 30 publications

Characteristics of Crude Oil Production in Microscopic Pores of CO₂ Huff and Puff in Shale Oil Reservoirs

Characteristics of Crude Oil Production in Microscopic Pores of CO₂ Huff and Puff in Shale Oil Reservoirs

Monte Carlo Simulation of the CO2 Flooding Efficiency at a Core Scale for Different Oil Compositions

Further Investigation of CO2 Quasi-Dry Fracturing in Shale Reservoirs—An Experimental Study

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Evaluation of CO2 utilization and storage potential in the Jimsar shale play from an optimization study

Cited by 11 publications

References 30 publications

Characteristics of Crude Oil Production in Microscopic Pores of CO2 Huff and Puff in Shale Oil Reservoirs

Characteristics of Crude Oil Production in Microscopic Pores of CO2 Huff and Puff in Shale Oil Reservoirs

Monte Carlo Simulation of the CO2 Flooding Efficiency at a Core Scale for Different Oil Compositions

Further Investigation of CO2 Quasi-Dry Fracturing in Shale Reservoirs—An Experimental Study

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Product

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Characteristics of Crude Oil Production in Microscopic Pores of CO₂ Huff and Puff in Shale Oil Reservoirs

Characteristics of Crude Oil Production in Microscopic Pores of CO₂ Huff and Puff in Shale Oil Reservoirs