非常規油氣藏多場耦合滲流理論研究進展

朱維耀; 陳震; 尚新春

doi:10.13374/j.issn2095-9389.2022.03.29.002

非常規油氣藏多場耦合滲流理論研究進展

doi: 10.13374/j.issn2095-9389.2022.03.29.002

北京科技大學土木與資源工程學院，北京 100083

基金項目: 國家自然科學基金資助項目（51974013）

詳細信息

通訊作者:
E-mail: weiyaook@sina.com

中圖分類號: TE122.3
計量
- 文章訪問數: 494
- HTML全文瀏覽量: 220
- PDF下載量: 87
- 被引次數: 0
出版歷程
- 收稿日期: 2022-03-29
- 網絡出版日期: 2022-07-27
- 刊出日期: 2023-05-31

Multiphysical field coupling in unconventional oil and gas reservoirs

School of Civil and Resources Engineering, University of Science and Technology Beijing, Beijing 100083, China

More Information

Corresponding author: E-mail: weiyaook@sina.com

摘要

摘要: 非常規油氣藏是目前世界油氣開發的重點領域，由于非常規油氣藏的儲層條件差，滲流場與應力場、溫度場耦合作用，流體的流動更為復雜，以往對多場耦合理論的運用存在簡易化和適應性缺陷，工程中缺少理論指導下的更有效的開采工藝與開發方法，制約了這類油氣藏的大規模高效開發，亟需對多場耦合滲流力學理論進行深入認識，以對工程問題提供有效指導。從實驗認識、理論分析、仿真模擬三個方面闡述了我國非常規油氣資源開發領域的多場耦合滲流力學理論的研究現狀，重點圍繞多尺度介質力學行為特性表征、巖體和流體的溫度響應機制、耦合作用的概念及數學模型、多場耦合模擬仿真方法等關鍵問題的最新成果、認識展開論述。在此基礎上對地下真實應力及溫度環境的模擬、烴類吸附及置換的熱量測試等問題進行分析，建議針對巖石的塑性應變、重復壓裂后的應力環境變化、混合烴類的輸運模型、以及流動條件隨應力和溫度變化的模型等科學問題進一步深化。旨在為進一步闡明我國非常規油氣藏開發的動用機理、確定高效開發方法提供指導，同時希望能夠促進滲流力學的學科發展。
- 非常規油氣 /
- 多場耦合 /
- 非線性流動 /
- 跨尺度流動 /
- 滲流理論
Abstract: Research in the field of oil and gas development has focused on the production of unconventional reservoirs all over the world. Unconventional oil and gas reservoirs have poor flow conditions, and the interaction of flow, stress, and temperature fields is very complex. Therefore, multiphysical field coupling is essential. The previous application of multiphysical field coupling theory has defects such as oversimplification and inadequate adaptability. Furthermore, the lack of adaptive production practices and effective development plans limits large-scale and efficient development, and there is an urgent necessity to investigate the adaptive multiphysical field coupling theory. Currently, the core rheology in fluid–solid coupling settings can often be measured by a triaxial test system under high temperature and pressure conditions combined with flow experiments. Moreover, the changes in pores and fractures can be tested by micro-CT and SEM. In addition, adsorption is considered an exothermic process, and desorption is deemed a heat-absorbing process, so the reservoir temperature decreases at the location where desorption occurs. Therefore, the production of unconventional oil and gas triggers a series of interactions. As the fluid flows into the wellbore through the fractures, the pressure drop increases the effective stress, decreasing the average pore radius and altering the inherent permeability. Moreover, the change of pressure causes a variation in the micro-flow effect, significantly impacting the apparent permeability, and the heat variation during desorption and adsorption also changes the flow condition as well as the physical properties of the fluid. As a result, these physical fields are closely related. A series of fully coupled partial differential equations are necessary to define the production process by modeling the dynamic porosity and permeability in various flow sectors to distinguish the interactions between different zones and physical fields. These complex interactions generally need to be solved by numerical methods. Thus, a simulator is needed that satisfies the accuracy requirements to match the actual situation. Moreover, adaptability to the decoupling process and acceptable speed requires research for high-performance computing solutions that can perform distributed or cloud computing for a large-scale unconventional reservoir simulation. Future research is necessary for laboratory measurements under realistic stress and temperature environmental conditions of the formation and hydrocarbon adsorption experiments. There should be further understanding of scientific issues such as the plastic strain of the porous rocks, changing stress environment after refracturing, and mixed hydrocarbon transport models with varying stress and temperature. This article further clarifies the dynamics and determines effective production methods of unconventional reservoirs in China to promote the development of flow mechanics.
- unconventional oil and gas reservoirs /
- multiphysical field coupling /
- nonlinear flow /
- multiscale flow /
- porous flow theory

HTML全文

圖 1 裂縫性巖心的CT掃描

Figure 1. CT scan image of a fractured core

下載: 全尺寸圖片幻燈片

圖 2 基質和裂縫巖心的應力敏感性測試

Figure 2. Stress–sensitive experiment of matrix and fractured cores

下載: 全尺寸圖片幻燈片

圖 3 非常規油氣的多物理場之間的相互作用

Figure 3. Interactions between multiphysical fields in unconventional oil and gas reservoirs

下載: 全尺寸圖片幻燈片

圖 4 “三大區，五小區”多尺度模型

Figure 4. Multiscale model of the “three main sectors, five subdivided sectors”

下載: 全尺寸圖片幻燈片

圖 5 多場耦合作用對多尺度流動區域的影響

Figure 5. Multiphysical fields coupling effects on multiscale flow sectors

下載: 全尺寸圖片幻燈片

www.77susu.com

參考文獻(105)

[1]	Kalam S, Afagwu C, Jaberi J A, et al. A review on non-aqueous fracturing techniques in unconventional reservoirs. J Nat Gas Sci Eng, 2021, 95: 104223 doi: 10.1016/j.jngse.2021.104223
[2]	Nikolaev M Y, Kazak A V. Liquid saturation evaluation in organic-rich unconventional reservoirs: A comprehensive review. Earth Sci Rev, 2019, 194: 327 doi: 10.1016/j.earscirev.2019.05.012
[3]	He J M, Li X, Yin C, et al. Propagation and characterization of the micro cracks induced by hydraulic fracturing in shale. Energy, 2020, 191: 116449 doi: 10.1016/j.energy.2019.116449
[4]	Li W, Liu J S, Zeng J, et al. A fully coupled multidomain and multiphysics model for evaluation of shale gas extraction. Fuel, 2020, 278: 118214 doi: 10.1016/j.fuel.2020.118214
[5]	Hudson J A, Stephansson O, Andersson J, et al. Coupled T-H-M issues relating to radioactive waste repository design and performance. Int J Rock Mech Min Sci, 2001, 38(1): 143 doi: 10.1016/S1365-1609(00)00070-8
[6]	Wu K L, Chen Z X, Li X F, et al. Flow behavior of gas confined in nanoporous shale at high pressure: Real gas effect. Fuel, 2017, 205: 173 doi: 10.1016/j.fuel.2017.05.055
[7]	Wang S, Shi J T, Wang K, et al. New coupled apparent permeability models for gas transport in inorganic nanopores of shale reservoirs considering multiple effects. Energy Fuels, 2017, 31(12): 13545 doi: 10.1021/acs.energyfuels.7b02948
[8]	Fan X, Li G S, Shah S N, et al. Analysis of a fully coupled gas flow and deformation process in fractured shale gas reservoirs. J Nat Gas Sci Eng, 2015, 27: 901 doi: 10.1016/j.jngse.2015.09.040
[9]	Zhu W Y, Chen Z, Song Z Y, et al. Research progress in theories and technologies of shale gas development in China. Chin J Eng, 2021, 43(10): 1397 朱維耀, 陳震, 宋智勇, 等. 中國頁巖氣開發理論與技術研究進展. 工程科學學報, 2021, 43(10):1397
[10]	Wang J, Liu H Q, Wang L, et al. Apparent permeability for gas transport in nanopores of organic shale reservoirs including multiple effects. Int J Coal Geol, 2015, 152: 50 doi: 10.1016/j.coal.2015.10.004
[11]	Chen D, Pan Z J, Ye Z H. Dependence of gas shale fracture permeability on effective stress and reservoir pressure: Model match and insights. Fuel, 2015, 139: 383 doi: 10.1016/j.fuel.2014.09.018
[12]	Mi L D, Jiang H Q, Cao Y, et al. Comprehensive apparent permeability model coupled shale gas transfer mechanisms in natural fractures and matrix. J Pet Sci Eng, 2019, 172: 878 doi: 10.1016/j.petrol.2018.08.080
[13]	Cui G L, Liu J S, Wei M Y, et al. Evolution of permeability during the process of shale gas extraction. J Nat Gas Sci Eng, 2018, 49: 94 doi: 10.1016/j.jngse.2017.10.018
[14]	Akkutlu I Y, Fathi E. Multiscale gas transport in shales with local kerogen heterogeneities. SPE J, 2012, 17(4): 1002 doi: 10.2118/146422-PA
[15]	Tang S, Zhu W Y, Zhang J C. Production analysis and fracturing parameter optimization of shale gas from Zhongmou Block in southern North China Basin. Chin J Eng, 2020, 42(12): 1573 唐帥, 朱維耀, 張金川. 中牟區塊過渡相頁巖氣藏產能分析及壓裂參數優選. 工程科學學報, 2020, 42(12):1573
[16]	Nelson P H. Pore-throat sizes in sandstones, tight sandstones, and shales. AAPG Bull, 2009, 93(3): 329 doi: 10.1306/10240808059
[17]	Clarkson C R, Solano N, Bustin R M, et al. Pore structure characterization of North American shale gas reservoirs using USANS/SANS, gas adsorption, and mercury intrusion. Fuel, 2013, 103: 606 doi: 10.1016/j.fuel.2012.06.119
[18]	Yuan B, Su Y L, Moghanloo R G, et al. A new analytical multi-linear solution for gas flow toward fractured horizontal wells with different fracture intensity. J Nat Gas Sci Eng, 2015, 23: 227 doi: 10.1016/j.jngse.2015.01.045
[19]	Zhu W Y, Li H, Deng Q J, et al. Review on mesoscopic flow theory in porous media. Chin J Eng, 2022, 44(5): 951 doi: 10.3321/j.issn.1001-053X.2022.5.bjkjdxxb202205014 朱維耀, 李華, 鄧慶軍, 等. 多孔介質細觀流動理論研究進展. 工程科學學報, 2022, 44(5):951 doi: 10.3321/j.issn.1001-053X.2022.5.bjkjdxxb202205014
[20]	Wang L, Wang S H, Zhang R L, et al. Review of multi-scale and multi-physical simulation technologies for shale and tight gas reservoirs. J Nat Gas Sci Eng, 2017, 37: 560 doi: 10.1016/j.jngse.2016.11.051
[21]	Teklu T W, Li X P, Zhou Z, et al. Experimental investigation on permeability and porosity hysteresis of tight formations. SPE J, 2018, 23(3): 672 doi: 10.2118/180226-PA
[22]	Ping C, Wen Y D, Wang Y X, et al. Study on nonlinear damage creep constitutive model for high-stress soft rock. Environ Earth Sci, 2016, 75(10): 900 doi: 10.1007/s12665-016-5699-x
[23]	Dong J J, Hsu J Y, Wu W J, et al. Stress-dependence of the permeability and porosity of sandstone and shale from TCDP Hole-A. Int J Rock Mech Min Sci, 2010, 47(7): 1141 doi: 10.1016/j.ijrmms.2010.06.019
[24]	Tinni A, Fathi E, Agarwal R, et al. Shale Permeability Measurements on Plugs and Crushed Samples//SPE Canadian Unconventional Resources Conference. Alberta, 2012
[25]	Heller R, Vermylen J, Zoback M. Experimental investigation of matrix permeability of gas shales. AAPG Bull, 2014, 98(5): 975 doi: 10.1306/09231313023
[26]	Wang H L, Xu W Y, Zuo J. Compact rock material gas permeability properties. Phys B:Condens Matter, 2014, 449: 10 doi: 10.1016/j.physb.2014.04.049
[27]	Ghanizadeh A, Bhowmik S, Haeri-Ardakani O, et al. A comparison of shale permeability coefficients derived using multiple non-steady-state measurement techniques: Examples from the Duvernay Formation, Alberta (Canada). Fuel, 2015, 140: 371 doi: 10.1016/j.fuel.2014.09.073
[28]	Zhong X Y, Zhu Y S, Liu L P, et al. The characteristics and influencing factors of permeability stress sensitivity of tight sandstone reservoirs. J Pet Sci Eng, 2020, 191: 107221 doi: 10.1016/j.petrol.2020.107221
[29]	Curtis J B. Fractured shale-gas systems. AAPG Bull, 2002, 86(11): 1921
[30]	Chen T Y, Feng X T, Pan Z J. Experimental study of swelling of organic rich shale in methane. Int J Coal Geol, 2015, 150-151: 64 doi: 10.1016/j.coal.2015.08.001
[31]	Cao P, Liu J, Leong Y K. Combined impact of flow regimes and effective stress on the evolution of shale apparent permeability. J Unconv Oil Gas Resour, 2016, 14: 32 doi: 10.1016/j.juogr.2016.01.004
[32]	Yu J H, Shang X C, Wu P F. Experimental study and theoretical analysis on shale strength. Sci Sin Technol, 2016, 46(2): 135 doi: 10.1360/N092016-00007
[33]	Bera A, Kumar S, Foroozesh J, et al. Multiphysics gas transport in nanoporous unconventional reservoirs: Challenges of mathematical modelling. J Nat Gas Sci Eng, 2022, 103(3): 104649
[34]	Ghaednia H, Pope S A, Jackson R L, et al. A comprehensive study of the elasto-plastic contact of a sphere and a flat. Tribol Int, 2016, 93: 78 doi: 10.1016/j.triboint.2015.09.005
[35]	Wu S C, Sun W, Cheng Z Q. Acoustic emission characteristics of Brazilian test for low-porosity sandstone under different load conditions. Chin J Eng, 2020, 42(8): 988 吳順川, 孫偉, 成子橋. 不同荷載條件下低孔隙率砂巖巴西劈裂試驗的聲發射特性. 工程科學學報, 2020, 42(8):988
[36]	Lyu Q, Shi J D, Gamage R P. Effects of testing method, lithology and fluid-rock interactions on shale permeability: A review of laboratory measurements. J Nat Gas Sci Eng, 2020, 78: 103302 doi: 10.1016/j.jngse.2020.103302
[37]	Feng R M, Liu J, Bernhardt-Barry M L, et al. Transverse permeability measurements of gas shales under replicated in-situ flow conditions: Mathematical modeling and laboratory testing. J Nat Gas Sci Eng, 2021, 95: 104159 doi: 10.1016/j.jngse.2021.104159
[38]	Pan L, Xiao X M, Tian H, et al. Geological models of gas in place of the Longmaxi shale in Southeast Chongqing, South China. Mar Pet Geol, 2016, 73: 433 doi: 10.1016/j.marpetgeo.2016.03.018
[39]	Rogala A, Bernaciak M, Krzysiek J, et al. Non aqueous fracturing technologies for shale gas recovery. Physicochem Probl Miner Process, 2012, 49(1): 31
[40]	Gutierrez M, Lewis R, Masters I. Petroleum reservoir simulation coupling fluid flow and geomechanics. SPE Reserv Eval Eng, 2001, 4(3): 164 doi: 10.2118/72095-PA
[41]	Zhu W C, Wei C H, Liu J, et al. A model of coal-gas interaction under variable temperatures. Int J Coal Geol, 2011, 86(2-3): 213 doi: 10.1016/j.coal.2011.01.011
[42]	Qu H Y, Liu J S, Chen Z W, et al. Complex evolution of coal permeability during CO? injection under variable temperatures. Int J Greenh Gas Control, 2012, 9: 281 doi: 10.1016/j.ijggc.2012.04.003
[43]	Liu Y K, Xiong Y Q, Li Y, et al. Effects of oil expulsion and pressure on nanopore development in highly mature shale: Evidence from a pyrolysis study of the Eocene Maoming oil shale, South China. Mar Pet Geol, 2017, 86: 526 doi: 10.1016/j.marpetgeo.2017.06.012
[44]	Guo H J, Jia W L, Peng P A, et al. Evolution of organic matter and nanometer-scale pores in an artificially matured shale undergoing two distinct types of pyrolysis: A study of the Yanchang Shale with Type II kerogen. Org Geochem, 2017, 105: 56 doi: 10.1016/j.orggeochem.2017.01.004
[45]	Harpalani S, Schraufnagel A. Measurement of parameters impacting methane recovery from coal seams. Int J Min Geol Eng, 1990, 8(4): 369 doi: 10.1007/BF00920648
[46]	Wu X H, Li P, Guo Q F, et al. Research progress on the evolution of physical and mechanical properties of thermally damaged rock. Chin J Eng, 2022, 44(5): 827 doi: 10.3321/j.issn.1001-053X.2022.5.bjkjdxxb202205001 吳星輝, 李鵬, 郭奇峰, 等. 熱損傷巖石物理力學特性演化機制研究進展. 工程科學學報, 2022, 44(5):827 doi: 10.3321/j.issn.1001-053X.2022.5.bjkjdxxb202205001
[47]	Liu X J, Xiong J, Liang L X. Investigation of pore structure and fractal characteristics of organic-rich Yanchang formation shale in central China by nitrogen adsorption/desorption analysis. J Nat Gas Sci Eng, 2015, 22: 62 doi: 10.1016/j.jngse.2014.11.020
[48]	Lin K, Yuan Q Z, Zhao Y P. Using graphene to simplify the adsorption of methane on shale in MD simulations. Comput Mater Sci, 2017, 133: 99 doi: 10.1016/j.commatsci.2017.03.010
[49]	Lin K, Huang X F, Zhao Y P. Combining image recognition and simulation to reproduce the adsorption/desorption behaviors of shale gas. Energy Fuels, 2019, 34(1): 258
[50]	Jin F Y, Jiang T T, Yuan C D, et al. An improved viscosity prediction model of extra heavy oil for high temperature and high pressure. Fuel, 2022, 319: 123852 doi: 10.1016/j.fuel.2022.123852
[51]	Bai F T, Sun Y H, Liu Y M, et al. Evaluation of the porous structure of Huadian oil shale during pyrolysis using multiple approaches. Fuel, 2017, 187: 1 doi: 10.1016/j.fuel.2016.09.012
[52]	Saif T, Lin Q Y, Bijeljic B, et al. Microstructural imaging and characterization of oil shale before and after pyrolysis. Fuel, 2017, 197: 562 doi: 10.1016/j.fuel.2017.02.030
[53]	Zhao J, Yang D, Kang Z Q, et al. A micro-CT study of changes in the internal structure of Daqing and Yan’an oil shales at high temperatures. Oil Shale, 2012, 29(4): 357 doi: 10.3176/oil.2012.4.06
[54]	Tiwari P, Deo M, Lin C L, et al. Characterization of oil shale pore structure before and after pyrolysis by using X-ray micro CT. Fuel, 2013, 107: 547 doi: 10.1016/j.fuel.2013.01.006
[55]	Lan W J, Wang H X, Zhang X, et al. Investigation on the mechanism of micro-cracks generated by microwave heating in coal and rock. Energy, 2020, 206: 118211 doi: 10.1016/j.energy.2020.118211
[56]	Liu H P, Feng S Y, Zhang S Q, et al. Analysis of the pore structure of Longkou oil shale semicoke during fluidized bed combustion. Oil Shale, 2020, 37(2): 89 doi: 10.3176/oil.2020.2.01
[57]	Liu Z J, Yang D, Hu Y Q, et al. Influence of in situ pyrolysis on the evolution of pore structure of oil shale. Energies, 2018, 11(4): 755 doi: 10.3390/en11040755
[58]	Zhang H B, Liu J S, Elsworth D. How sorption-induced matrix deformation affects gas flow in coal seams: A new FE model. Int J Rock Mech Min Sci, 2008, 45(8): 1226 doi: 10.1016/j.ijrmms.2007.11.007
[59]	Peng Y, Liu J S, Pan Z J, et al. A sequential model of shale gas transport under the influence of fully coupled multiple processes. J Nat Gas Sci Eng, 2015, 27: 808 doi: 10.1016/j.jngse.2015.09.031
[60]	Cao P, Liu J S, Leong Y K. A fully coupled multiscale shale deformation-gas transport model for the evaluation of shale gas extraction. Fuel, 2016, 178: 103 doi: 10.1016/j.fuel.2016.03.055
[61]	Zhao Y L, Lu G, Zhang L H, et al. Numerical simulation of shale gas reservoirs considering discrete fracture network using a coupled multiple transport mechanisms and geomechanics model. J Pet Sci Eng, 2020, 195: 107588 doi: 10.1016/j.petrol.2020.107588
[62]	Vernik L, Milovac J. Rock physics of organic shales. Lead Edge, 2011, 30(3): 318 doi: 10.1190/1.3567263
[63]	Islam M A, Skalle P. An experimental investigation of shale mechanical properties through drained and undrained test mechanisms. Rock Mech Rock Eng, 2013, 46(6): 1391 doi: 10.1007/s00603-013-0377-8
[64]	Berryman J G. Extension of poroelastic analysis to double-porosity materials: New technique in microgeomechanics. J Eng Mech, 2002, 128(8): 840
[65]	Lu Y H, Wei S M, Xia Y, et al. Modeling of geomechanics and fluid flow in fractured shale reservoirs with deformable multi-continuum matrix. J Pet Sci Eng, 2021, 196: 107576 doi: 10.1016/j.petrol.2020.107576
[66]	Zhang J, Li Y W, Pan Y S, et al. Experiments and analysis on the influence of multiple closed cemented natural fractures on hydraulic fracture propagation in a tight sandstone reservoir. Eng Geol, 2021, 281: 105981 doi: 10.1016/j.enggeo.2020.105981
[67]	Wang Y J, Zhao B, Zhang Z N. Numerical simulation of stress reorientation around wellbore in production and refracture stimulation. Eng Anal Bound Elem, 2021, 133: 165 doi: 10.1016/j.enganabound.2021.09.005
[68]	Saghafi A, Faiz M, Roberts D. CO? storage and gas diffusivity properties of coals from Sydney Basin, Australia. Int J Coal Geol, 2007, 70(1-3): 240 doi: 10.1016/j.coal.2006.03.006
[69]	Lasseux D, Valdés-Parada F J. On the developments of Darcy’s law to include inertial and slip effects. Comptes Rendus Mecanique, 2017, 345(9): 660 doi: 10.1016/j.crme.2017.06.005
[70]	Zhang L J, Li D L, Lu D T, et al. A new formulation of apparent permeability for gas transport in shale. J Nat Gas Sci Eng, 2015, 23: 221 doi: 10.1016/j.jngse.2015.01.042
[71]	Zhang L H, Shan B C, Zhao Y L, et al. Review of micro seepage mechanisms in shale gas reservoirs. Int J Heat Mass Transf, 2019, 139: 144 doi: 10.1016/j.ijheatmasstransfer.2019.04.141
[72]	Song W H, Yao J, Wang D Y, et al. Nanoscale confined gas and water multiphase transport in nanoporous shale with dual surface wettability. Adv Water Resour, 2019, 130: 300 doi: 10.1016/j.advwatres.2019.06.012
[73]	Sun Z, Li X F, Shi J T, et al. Apparent permeability model for real gas transport through shale gas reservoirs considering water distribution characteristic. Int J Heat Mass Transf, 2017, 115: 1008 doi: 10.1016/j.ijheatmasstransfer.2017.07.123
[74]	Li Y D, Kalantari-Dahaghi A, Zolfaghari A, et al. A new model for the transport of gaseous hydrocarbon in shale nanopores coupling real gas effect, adsorption, and multiphase pore fluid occupancies. Int J Heat Mass Transf, 2020, 148: 119026 doi: 10.1016/j.ijheatmasstransfer.2019.119026
[75]	Beskok A, Karniadakis G E. Report: A model for flows in channels, pipes, and ducts at micro and nano scales. Microscale Thermophys Eng, 1999, 3(1): 43 doi: 10.1080/108939599199864
[76]	Civan F, Rai C S, Sondergeld C H. Shale-gas permeability and diffusivity inferred by improved formulation of relevant retention and transport mechanisms. Transp Porous Med, 2011, 86(3): 925 doi: 10.1007/s11242-010-9665-x
[77]	Akilu S, Padmanabhan E, Sun Z. A review of transport mechanisms and models for unconventional tight shale gas reservoir systems. Int J Heat Mass Transf, 2021, 175: 121125 doi: 10.1016/j.ijheatmasstransfer.2021.121125
[78]	Taghavinejad A, Sharifi M, Heidaryan E, et al. Flow modeling in shale gas reservoirs: A comprehensive review. J Nat Gas Sci Eng, 2020, 83: 103535 doi: 10.1016/j.jngse.2020.103535
[79]	Zhou Y, Rajapakse R K N D, Graham J. A coupled thermoporoelastic model with thermo-osmosis and thermal-filtration. Int J Solids Struct, 1998, 35(34-35): 4659 doi: 10.1016/S0020-7683(98)00089-4
[80]	Zhu W Y, Chen Z, Liu K. A new meshless method to solve the two-phase thermo-hydro-mechanical multi-physical field coupling problems in shale reservoirs. J Nat Gas Sci Eng, 2022, 105: 104683 doi: 10.1016/j.jngse.2022.104683
[81]	Huang Z W, Zhang S K, Yang R Y, et al. A review of liquid nitrogen fracturing technology. Fuel, 2020, 266: 117040 doi: 10.1016/j.fuel.2020.117040
[82]	Jia B, Tsau J S, Barati R. A review of the current progress of CO? injection EOR and carbon storage in shale oil reservoirs. Fuel, 2019, 236: 404 doi: 10.1016/j.fuel.2018.08.103
[83]	Hu L X, Li H Z, Babadagli T, et al. Thermal stimulation of shale formations by electromagnetic heating: A clean technique for enhancing oil and gas recovery. J Clean Prod, 2020, 277: 123197 doi: 10.1016/j.jclepro.2020.123197
[84]	Taheri-Shakib J, Kantzas A. A comprehensive review of microwave application on the oil shale: Prospects for shale oil production. Fuel, 2021, 305: 121519 doi: 10.1016/j.fuel.2021.121519
[85]	Gu F G, Chalaturnyk R. Permeability and porosity models considering anisotropy and discontinuity of coalbeds and application in coupled simulation. J Pet Sci Eng, 2010, 74(3-4): 113 doi: 10.1016/j.petrol.2010.09.002
[86]	Bhandari A R, Flemings P B, Polito P J, et al. Anisotropy and stress dependence of permeability in the Barnett shale. Transp Porous Med, 2015, 108(2): 393 doi: 10.1007/s11242-015-0482-0
[87]	Huang T, Tao Z W, Li E P, et al. Effect of permeability anisotropy on the production of multi-scale shale gas reservoirs. Energies, 2017, 10(10): 1549 doi: 10.3390/en10101549
[88]	Yuan J W, Jiang R Z, Cui Y Z, et al. The numerical simulation of thermal recovery considering rock deformation in shale gas reservoir. Int J Heat Mass Transfer, 2019, 138: 719 doi: 10.1016/j.ijheatmasstransfer.2019.04.098
[89]	Ma Y, Pan Z J, Zhong N N, et al. Experimental study of anisotropic gas permeability and its relationship with fracture structure of Longmaxi Shales, Sichuan Basin, China. Fuel, 2016, 180: 106 doi: 10.1016/j.fuel.2016.04.029
[90]	Qi Q. Multi-field Coupling Nonlinear Seepage Theory of Multistage Fractured Horizontal Wells for Shale Gas Reservoirs [Dissertation]. Beijing: University of Science and Technology Beijing, 2020 亓倩. 頁巖氣儲層多級壓裂水平井多場耦合非線性滲流理論研究[學位論文]. 北京: 北京科技大學, 2020
[91]	Frash L P, Carey J W, Welch N J. Scalable En Echelon Shear‐Fracture Aperture‐Roughness Mechanism: Theory, Validation, and Implications. J Geophys Res Solid Earth, 2019, 124: 957 doi: 10.1029/2018JB016525
[92]	Li W F, Frash L P, Welch N J, et al. Stress-dependent fracture permeability measurements and implications for shale gas production. Fuel, 2021, 290(9): 119984
[93]	Yang S, Wu K L, Xu J Z, et al. Roles of multicomponent adsorption and geomechanics in the development of an Eagle Ford shale condensate reservoir. Fuel, 2019, 242: 710 doi: 10.1016/j.fuel.2019.01.016
[94]	Guo T K, Tang S J, Sun J, et al. A coupled thermal-hydraulic-mechanical modeling and evaluation of geothermal extraction in the enhanced geothermal system based on analytic hierarchy process and fuzzy comprehensive evaluation. Appl Energy, 2019, 258: 113981
[95]	Noorishad J, Tsang C F, Witherspoon P A. Coupled thermal-hydraulic-mechanical phenomena in saturated fractured porous rocks: Numerical approach. J Geophys Res, 1984, 89: 10365 doi: 10.1029/JB089iB12p10365
[96]	Rutqvist J. Status of the TOUGH-FLAC simulator and recent applications related to coupled fluid flow and crustal deformations. Comput Geosci, 2011, 37(6): 739 doi: 10.1016/j.cageo.2010.08.006
[97]	Wang W, Kolditz O. Object-oriented finite element analysis of thermo-hydro-mechanical (THM) problems in porous media. Int J Numer Meth Eng, 2010, 69: 162
[98]	Longuemare P, Mainguy M, Lemonnier P, et al. Geomechanics in reservoir simulation: Overview of coupling methods and field case study. Oil Gas Sci Technol, 2002, 57(5): 471 doi: 10.2516/ogst:2002031
[99]	Minkoff S E, Stone C M, Bryant S, et al. Coupled fluid flow and geomechanical deformation modeling. J Pet Sci Eng, 2003, 38(1-2): 37 doi: 10.1016/S0920-4105(03)00021-4
[100]	Li J W, Wong Z Y, Tomin P, et al. Sequential Implicit Newton Method for Coupled Multi-Segment Wells//SPE Reservoir Simulation Conference. Galveston, 2019
[101]	Zhang R L, Wu Y S. Sequentially coupled model for multiphase flow, mean stress, and reactive solute transport with kinetic chemical reactions: Applications in CO? geological sequestration. J Porous Media, 2016, 19(11): 1001 doi: 10.1615/JPorMedia.v19.i11.60
[102]	Zhang R L, Xiong Y, Winterfeld P H, et al. A novel computational framework for thermal-hydrological-mechanical-chemical processes of CO? geological sequestration into a layered saline aquifer and a naturally fractured enhanced geothermal system. Greenh Gases Sci Technol, 2016, 6(3): 370 doi: 10.1002/ghg.1571
[103]	Settari A, Walters D A. Advances in coupled geomechanical and reservoir modeling with applications to reservoir compaction. SPE J, 2001, 6(3): 334 doi: 10.2118/74142-PA
[104]	Han S C, Cheng Y F, Gao Q, et al. A fully coupled thermo-hydro-mechanical model with ice-water phase change for liquid nitrogen injection simulation. J Pet Sci Eng, 2021, 203(1): 108676
[105]	Fung L S, Dogru A H. Parallel unstructured-solver methods for simulation of complex giant reservoirs. SPE J, 2008, 13(4): 440 doi: 10.2118/106237-PA