Comparison of SO2 with CO2 for recovering shale resources using low-field nuclear magnetic resonance

Huang, Xing; Li, Tiantai; Gao, Hui; Zhao, Jinsheng; Wang, Chen

doi:10.1016/j.fuel.2019.01.135

Cited by 34 publications

(29 citation statements)

References 46 publications

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“…In order to optimize the reservoir performance, the selection of a displacing fluid and a ratio of CO 2 /N 2 mixture gases should be well studied. Meanwhile, nuclear magnetic resonance (NMR) technique is implemented to investigate adsorption isotherms of pure CH 4 , C 2 H 6 , CO 2 , and SO 2 by Huang et al [33]. Their study concluded that SO 2 presents the strongest adsorption capacity among the four gases, and is followed by C 2 H 6 , CO 2 , and CH 4 .…”

Section: Trend and Innovation On The Cs-egr Technologymentioning

confidence: 99%

Will the future of shale reservoirs lie in CO2 geological sequestration?

Zhan

Chen²,

Zhang³

et al. 2020

Sci. China Technol. Sci.

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CO 2 geological sequestration in a depleted shale gas reservoir is a promising method to address the global energy crisis as well as to reduce greenhouse gas emissions. Though improvements have been achieved by many researchers, the carbon sequestration and enhanced gas recovery (CS-EGR) in shale formations is still in a preliminary stage. The current research status of CO 2 sequestration in shale gas reservoirs with potential EGR is systematically and critically addressed in the paper. In addition, some original findings are also presented in this paper. This paper will shed light on the technology development that addresses the dual problem of energy crisis and environmental degradation.

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Section: Trend and Innovation On The Cs-egr Technologymentioning

confidence: 99%

Will the future of shale reservoirs lie in CO2 geological sequestration?

Zhan

Chen²,

Zhang³

et al. 2020

Sci. China Technol. Sci.

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show abstract

“…Carbon capture and storage (CCS) is a technology that can reduce carbon emissions from fossil fuels on a large scale [7]. e technology was developed in the 1970s for oil, geothermal and other energy development, as well as water treatment and other technologies [8][9][10][11][12][13][14][15]. In the process of extracting natural gas hydrates using high-polymer additive carbon dioxide jet, correct prediction of wellbore temperature and pressure is of great signi cance for judging the properties of polymer additive CO 2 uid and analyzing the state of natural gas hydrate.…”

Section: Introductionmentioning

confidence: 99%

Study on Wellbore Temperature and Pressure Distribution in Process of Gas Hydrate Mined by Polymer Additive CO₂ Jet

Wei

Zhou

2020

Advances in Polymer Technology

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In order to solve the problem of hydrate reservoir collapse and hydrate regenerated in the process of solid fluidization of natural gas hydrate, a new method of natural gas hydrate exploit by high‐polymer additive (low viscosity carboxymethyl cellulose LV‐CMC) carbon dioxide jet was proposed. The wellbore temperature and pressure changes during this process are analyzed, and the wellbore temperature and pressure model are established and solved by the state space method. This paper also analyzed the effects of relevant parameters on hydrate decomposition, such as injection flow, temperature, and pressure. The results show that increasing the injection pressure allows the hydrate decomposition site to be closer to the annulus outlet. Compared with water, with polymer additive CO2 fluid as the drilling fluid, the intersection point of phase equilibrium curve and annular pressure curve is closer to annular outlet, which is obviously more conducive to well control. In order to avoid phase changes, the injection pressure of the carbon dioxide fluid of the high‐polymer additive should not be lower than 10 MPa, and the injection temperature should not be higher than 285 K.

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“…As an essential unconventional resource, shale oil has been successfully developed in countries such as USA and Canada (Gale et al., 2007; Huang et al., 2019; Kirschbaum and Mercier, 2013; Kuhn et al., 2012; Liu et al., 2018; Ojha et al., 2017). The shale oil reservoir, which are generally accepted as the storage space in shale, are usually in the micro-nanometers range.…”

Section: Introductionmentioning

confidence: 99%

Comprehensive characterization of nano-pore system for Chang 7 shale oil reservoir in Ordos Basin

Gao

Cao

Wang

et al. 2020

Energy Exploration & Exploitation

Self Cite

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Detailed study on the pore structure of shale oil reservoir is significantly for the exploration and development, and the conventional single pore structure measurement method cannot accurately describe the pore structure characteristics of the shale oil reservoir. In this paper, the Field Emission Scanning Electron Microscope (FESEM), low-pressure nitrogen adsorption (LP-N2A) and mercury injection porosimetry (MIP) techniques are used to comprehensive evaluate the pore structure of Chang 7 shale oil reservoir. The FESEM results show that inter pores, inner pores, organic pores and micro-cracks are developed in Chang 7 shale oil reservoir, and the pore structure can be divided into two groups from the LP-N2A and MIP. A new pore structure comprehensive evaluation method was promoted according to the connection points from the pore sizes distribution curves of LP-N2A and MIP. With this comprehensive analysis of the pore size distribution, the pore size distribution of various shale samples feature as triple-peak pattern. Due to the heterogeneity of the shale oil samples, the corresponding pore apertures of the connection points are various, and the overall pore size distribution of shale oil reservoir samples can also be divided into two types. In Group I, the size distributions exhibited a bimodal feature in a narrow range from 1.71 to 100 nm. The trimodal feature of size distributions was captured in Group II with the pore diameter ranges from 1.71 to 1426.8 nm. Group I features smaller sorting coefficient and good pore connectivity. However, the trimodal corresponds to the complex pore structure and larger sorting coefficient for Group II.

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Comparison of SO2 with CO2 for recovering shale resources using low-field nuclear magnetic resonance

Cited by 34 publications

References 46 publications

Will the future of shale reservoirs lie in CO2 geological sequestration?

Will the future of shale reservoirs lie in CO2 geological sequestration?

Study on Wellbore Temperature and Pressure Distribution in Process of Gas Hydrate Mined by Polymer Additive CO₂ Jet

Comprehensive characterization of nano-pore system for Chang 7 shale oil reservoir in Ordos Basin

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Comparison of SO2 with CO2 for recovering shale resources using low-field nuclear magnetic resonance

Cited by 34 publications

References 46 publications

Will the future of shale reservoirs lie in CO2 geological sequestration?

Will the future of shale reservoirs lie in CO2 geological sequestration?

Study on Wellbore Temperature and Pressure Distribution in Process of Gas Hydrate Mined by Polymer Additive CO2 Jet

Comprehensive characterization of nano-pore system for Chang 7 shale oil reservoir in Ordos Basin

Contact Info

Product

Resources

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Study on Wellbore Temperature and Pressure Distribution in Process of Gas Hydrate Mined by Polymer Additive CO₂ Jet