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Near Gas-Water Contact Sequestration of Carbon Dioxide to Improve the Performance of Water Drive Gas Reservoir: Case Study

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Computational Water, Energy, and Environmental Engineering 2025年第1期14卷 1-15页

作者： Mohammad Amin Safarzadeh Hossein Zangeneh Javad Kasravi University of Calgary Calgary Canada Research Institute of petroleum Industry Tehran Iran National Iranian Drilling company Ahwaz Iran

This study investigates the application of carbon dioxide (CO2) sequestration to address challenges in water-drive gas reservoirs, specifically focusing on improving gas recovery and mitigating water invasion. Traditional methods like blow-down and co-production have limitations, including sand production, water coning, and inefficiency in strong aquifers. To overcome these issues, this research explores CO2 injection near the edge aquifer, aiming to reduce water influx and enhance gas recovery through the propagation of a CO2 plume in the gas-water contact zone. Both synthetic and real compositional reservoir models were studied, with CO2 injection performed while maintaining reservoir pressure below 90% of the initial level. Results show that CO2 sequestration significantly improved recovery, particularly in higher permeability reservoirs, where it reduced aquifer influx and increased gas production by 26% under challenging conditions. While CO2 dissolution in water decreased aquifer influx by 39%, its adverse effect on sweep efficiency led to a reduction in gas and water production by 4.2% and 10%, respectively. The method's effectiveness was not significantly impacted by aquifer permeability, but it was sensitive to vertical-to-horizontal permeability ratios. When applied to a real gas reservoir, the proposed method increased gas production by 14% compared to conventional techniques, with minimal CO2 production over a 112-year period. This study demonstrates the potential of CO2 sequestration as a comprehensive solution for enhancing gas recovery, reducing water production, and mitigating environmental impacts in water-drive gas reservoirs.

关键词： Gas Reservoir Water Encroachment Residual Gas Saturation Aquifer Influx Carbon Dioxide Sequestration Hazardous Water Production

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Effect of preprocessing on performances of machine learning-based mineral composition analysis on gas hydrate sediments, Ulleung Basin, East Sea

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petroleum Science 2025年第1期22卷 151-162页

作者： Hongkeun Jin Ju Young Park Sun Young Park Byeong-Kook Son Baehyun Min Kyungbook Lee Department of Geoenvironmental Sciences Kongju National University Tunnel & Underground Facility Division ESCO Consultant & Engineers Company Yellow Sea Institute of Geoenvironmental Sciences petroleum and Marine Research Division Korea Institute of Geoscience and Mineral Resources Department of Climate and Energy Systems Engineering Ewha Womans University Center for Climate/Environment Change Prediction Research Ewha Womans University

Gas hydrate(GH) is an unconventional resource estimated at 1000-120,000 trillion *** on GH is ongoing to determine its geological and flow characteristics for commercial production. After two large-scale drilling expeditions to study the GH-bearing zone in the Ulleung Basin, the mineral composition of 488 sediment samples was analyzed using X-ray diffraction(XRD). Because the analysis is costly and dependent on experts, a machine learning model was developed to predict the mineral composition using XRD intensity profiles as input data. However, the model's performance was limited because of improper preprocessing of the intensity profile. Because preprocessing was applied to each feature, the intensity trend was not preserved even though this factor is the most important when analyzing mineral composition. In this study, the profile was preprocessed for each sample using minmax scaling because relative intensity is critical for mineral analysis. For 49 test data among the 488data, the convolutional neural network(CNN) model improved the average absolute error and coefficient of determination by 41% and 46%, respectively, than those of CNN model with feature-based preprocessing. This study confirms that combining preprocessing for each sample with CNN is the most efficient approach for analyzing XRD data. The developed model can be used for the compositional analysis of sediment samples from the Ulleung Basin and the Korea Plateau. In addition, the overall procedure can be applied to any XRD data of sediments worldwide.

关键词： Sample-based preprocessing X-ray diffraction (XRD) Machine learning Mineral composition Gas hydrate (GH) Ulleung basin

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The Water Flooding Seepage Mechanism in the Inter-Fractures of Horizontal Wells in Tight Oil Reservoirs

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Fluid Dynamics & Materials Processing 2025年第2期21卷 427-444页

作者： Xinli Zhao Qianhua Xiao Xuewei Liu Yu Shi Xiangji Dou Guoqiang Xing School of petroleum and Natural Gas Engineering Changzhou UniversityChangzhou213164China School of Oil and Gas Engineering Chongqing University of Science&TechnologyChongqing401331China Research Institute of petroleum Exploration&Development PetroChina Company LimitedBeijing100083China College of petroleum Engineering Xi’an Shiyou UniversityXi’an710065China

Tight oil reservoirs face significant challenges,including rapid production decline,low recovery rates,and a lack of effective energy replenishment *** this study,a novel development model is proposed,based on inter-fracture injection following volumetric fracturing and relying on a high-temperature and high-pressure large-scale physical simulation ***,the CMG(Computer Modelling Group Ltd.,Calgary City,Canada)software is also used to elucidate the impact of various single factors on the production of horizontal wells while filtering out the interference of *** effects of fracture spacing,fracture half-length,and the injection-production ratio are *** indicate that under rejection pressures of 6.89,3.45,and 1.88 MPa,the times to establish stable flow are 50,193,and 395 min,*** injection pressures lead to an increased oil recovery efficiency,with the highest observed efficiency at 16.93%.This indicates that,compared with conventional medium and high permeability reservoirs,tight oil reservoirs exhibit similar pore throats and larger capillary forces when oil and water flow in both *** pressures reduce capillary forces,displacing more oil droplets,thus enhancing oil recovery ***,under inter-fracture displacement conditions,the pressure gradient at both the injection and production ends remain consistent,with minimal pressure loss near the *** feature ensures that the crude oil in the middle of the reservoir also possesses displacement energy,thereby enhancing overall crude oil displacement efficiency.

关键词： Tight oil reservoir volumetric fracturing inter-fracture injection and production oil drive efficiency waterflooding

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Production analysis and permeability evolution of fractured horizontal wells of coalbed methane reservoir

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Meitan Xuebao/Journal of the China Coal Society 2025年第1期50卷 516-531页

作者： Guo, Jianchun Zhang, Tao Wu, Xi Zhao, Zhihong Li, Zongyuan Zeng, Jie National Key Laboratory of Oil and Gas Reservoir Geology and Exploitation Southwest Petroleum University Chengdu610500 China PetroChina Huabei Oilfield company Renqiu062552 China

Massive hydraulic fracturing has changed the status of low-productivity and low development efficiency for coalbed methane (CBM) reservoirs. However, the production dynamics of fractured wells and the permeability evolution mechanisms in CBM reservoirs are unclear, which significantly limits the efficient development of CBM reservoirs. Therefore, this study incorporates the total strain evolution under the conditions of gas-adsorption-induced swelling, fracture compression, and unsteady creep, uses the cubic law to establish the permeability model, and obtains the pressure and flow fields via the finite volume method (FVM) and the transient embedded discrete fracture model (tEDFM). Based on the embedded mass exchange law, an adsorbed-free phase multiple-mechanism recovery calculation framework is established to realize production dynamic analysis and productivity calculation. Results show that the production dynamics of CBM fractured wells include five stages: the initial high production stage, desorption-induced productivity increasing stage, mid-time stable production stage, production decline stage, and the final depleted stage. The larger the Langmuir pressure is, the faster sorbed gas production would be. When the Langmuir pressure is 2.6 MPa, after 1 800-day production, adsorbed gas dominates production. When the Langmuir volume is increased to 15 m3/t, desorbed gas’s contribution continuously increases. Adsorbed gas becomes the main gas source after 560-day production. The denser the hydraulic fractures are, the larger the drainage area is, the significantly higher the initial production would be, and the later the production decline occurs. When the fracture spacing is 3 times larger, the maximum gas production decreases by about 48%. When the fracture half-length is increased by 50 m, the initial production would nearly be doubled. The permeability evolution includes three stages: loss, recovery, and enhancement. When the fracture compressibility coefficien

关键词： Gas adsorption

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Estimated Ultimate Recovery and Productivity of Deep Shale Gas Horizontal Wells

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Fluid Dynamics & Materials Processing 2025年第1期21卷 221-232页

作者： Haijie Zhang Haifeng Zhao Ming Jiang Junwei Pu Yuanping Luo Weiming Chen Tongtong Luo Zhiqiang Li Xinan Yu Exploration and Development Department Chongqing Shale Gas Exploration and Development Co.Ltd.Chongqing401120China Oil&Gas Technology Research Institute Changqing Oilfield CompanyXi’an710018China Exploration and Development Research Institute Zhejiang Oilfield CompanyHangzhou310023China Geological Exploration and Development Research Institute Chuanqing Drilling Engineering Co.Ltd.Chengdu610056China School of petroleum and Natural Gas Engineering Chongqing University of Science and TechnologyChongqing401331China Technology Department Chongqing University of Science and TechnologyChongqing401331China

Pressure control in deep shale gas horizontal wells can reduce the stress sensitivity of hydraulic fractures and improve the estimated ultimate recovery(EUR).In this study,a hydraulic fracture stress sensitivity model is proposed to characterize the effect of pressure drop rate on fracture ***,a production prediction model is introduced accounting for a non-uniform hydraulic fracture conductivity *** results reveal that increasing the fracture conductivity leads to a rapid daily production increase in the early ***,above 0.50 D·cm,a further increase in the fracture conductivity has a limited effect on shale gas production *** initial production is lower under pressure-controlled conditions than that under *** extended pressure control durations,the cumulative production initially increases and then *** a fracture conductivity of 0.10 D·cm,the increase in production output under controlled-pressure conditions is~35%.For representative deep shale gas wells(Southern Sichuan,China),if the pressure drop rate under controlled-pressure conditions is reduced from 0.19 to 0.04 MPa/d,the EUR increase for 5 years of pressure-controlled production is 41.0 million,with an increase percentage of~29%.

关键词： Deep shale gas fracture stress sensitivity pressure-controlled production production prediction

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Phase Behavior and Dew Point Pressure of Multicomponent Condensate Gas in Nanopores

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Fluid Dynamics & Materials Processing 2025年第2期21卷 279-292页

作者： Jichao Zhao Xu Yan Jing Sun Sheng Li petroleum Engineering College Yangtze UniversityWuhan430199China Hubei Key Laboratory of Oil and Gas Drilling and Production Engineering(Yangtze University) Wuhan430199China Exploration&Development Project Department of Mahu Area of Xinjiang Oilfield company China National Petroleum CorporationKaramay834000China

Shale gas reservoirs typically contain numerous nanoscale pores,with pore size playing a significant role in influencing the gas *** better understand the related mechanisms,this study employs the Gauge-GEMC molecular simulation method to systematically analyze the effects of various pore sizes(5,10,20,and 40 nm)on the phase behavior and dew point pressure of the shale gas reservoir *** simulation results reveal that when pore sizes are smaller than 40 nm,the dew point pressure increases significantly as the pore size *** instance,the dew point pressure in 5 nmpores is 20.3%higher than undermacroscopic ***,larger hydrocarbon molecules exhibit a tendency to aggregate in smaller pores,particularly in the 5–10 nm range,where the relative concentration of heavy hydrocarbons(C_(4+))increases ***,as the pore size becomes larger,the component distribution gradually aligns with experimental results observed under macroscopic *** study demonstrates that pore effects are more pronounced for smaller sizes,directly influencing the aggregation of heavy hydrocarbons and the rise in dew point *** phenomena could significantly impact the diffusivity of shale gas reservoirs and the recovery of condensate *** findings provide new theoretical insights into phase behavior changes in nanopores,offering valuable guidance for optimizing shale gas reservoir extraction strategies.

关键词： Condensate gas nanopores molecular simulation dew point pressure confinement effect

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Study on the Fluid-Solid Coupling Seepage of the Deep Tight Reservoir Based on 3D Digital Core Modeling

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Energy Engineering 2025年第2期122卷 537-560页

作者： Haijun Yang Zhenzhong Cai Hui Zhang Chong Sun Jing Li Xiaoyu Meng Chen Liu Chengqiang Yang PetroChina Tarim Oilfield company Korla841000China CNPC R&D Center for Ultra-Deep Complex Reservoir Exploration and Development Korla841000China National Key Laboratory of Deep Oil and Gas China University of Petroleum(East China)Qingdao266580China Structure and Shipping Department Offshore Oil Engineering(Qingdao)Co.Ltd.Qingdao266520China

Deep tight reservoirs exhibit complex stress and seepage fields due to varying pore structures,thus the seepage characteristics are significant for enhancing oil *** study conducted triaxial compression and permeability tests to investigate the mechanical and seepage properties of tight sandstone.A digital core of tight sandstone was built using Computed Tomography(CT)scanning,which was divided into matrix and pore phases by a pore equivalent diameter threshold.A fluid-solid coupling model was established to investigate the seepage characteristics at *** results showed that increasing the confining pressure decreased porosity,permeability,and flow velocity,with the pore phase becoming the dominant seepage *** and large pores closed first under increasing pressure,resulted in a steep drop in ***,permeability slightly decreased under high confining pressure,which followed a first-order exponential *** velocity increased with seepage *** the damage mainly occurred in stress-concentration regions under low seepage *** behavior followed linear Darcy flow,the damage emerged at seepage entrances under high pressure,which decreased rock elastic modulus and significantly increased permeability.

关键词： Digital core fluid-solid coupling pore structure microscopic seepage

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SGP-GCN:A Spatial-Geological Perception Graph Convolutional Neural Network for Long-Term petroleum Production Forecasting

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Energy Engineering 2025年第3期122卷 1053-1072页

作者： Xin Liu Meng Sun Bo Lin Shibo Gu Qingdao Institute of Software College of Computer Science and TechnologyChina University of Petroleum(East China)Qingdao266580China Offshore Oil Production Plant Shengli Oilfield Branch CompanySINOPECDongying257237China

Long-termpetroleum production forecasting is essential for the effective development andmanagement of *** to its ability to extract complex patterns,deep learning has gained popularity for production ***,existing deep learning models frequently overlook the selective utilization of information from other production wells,resulting in suboptimal performance in long-term production forecasting across multiple *** achieve accurate long-term petroleum production forecast,we propose a spatial-geological perception graph convolutional neural network(SGP-GCN)that accounts for the temporal,spatial,and geological dependencies inherent in petroleum *** the attention mechanism,the SGP-GCN effectively captures intricate correlations within production and geological data,forming the representations of each production *** on the spatial distances and geological feature correlations,we construct a spatial-geological matrix as the weight matrix to enable differential utilization of information from other ***,a matrix sparsification algorithm based on production clustering(SPC)is also proposed to optimize the weight distribution within the spatial-geological matrix,thereby enhancing long-term forecasting *** evaluations have shown that the SGP-GCN outperforms existing deep learning models,such as CNN-LSTM-SA,in long-term petroleum production *** demonstrates the potential of the SGP-GCN as a valuable tool for long-term petroleum production forecasting across multiple wells.

关键词： petroleum production forecast graph convolutional neural networks(GCNs) spatial-geological rela-tionships production clustering attention mechanism

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Fracture geometry and breakdown pressure of radial borehole fracturing in multiple layers

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petroleum Science 2024年第1期21卷 430-444页

作者： Yu-Ning Yong Zhao-Quan Guo Shou-Ceng Tian Lu-Yao Ma Tian-Yu Wang Mao Sheng National Key Laboratory of petroleum Resources and Engineering China University of Petroleum(Beijing)Beijing102249China Beijing petroleum machinery company Limited CNPC Engineering Technology R&D Company LimitedBeijing102206China Smart Energy Co. LtdChina Xiongan GroupXiong’an New Area071000HebeiChina

Radial borehole fracturing that combines radial boreholes with hydraulic fracturing is anticipated to improve the output of tight oil and gas *** paper aims to investigate fracture propagation and pressure characteristics of radial borehole fracturing in multiple layers.A series of laboratory experiments with artificial rock samples(395 mm×395 mm×395 mm)was conducted using a true triaxial fracturing *** crucial factors corresponding to the vertical distance of adjacent radial borehole layers(vertical distance),the azimuth and diameter of the radial borehole are *** results show that radial borehole fracturing in multiple layers generates diverse fracture *** types of fractures are identified based on the connectivity between hydraulic fractures and radial *** vertical distance significantly influences fracture propagation perpendicular to the radial borehole *** increase in the vertical distance impedes fracture connection across multiple radial borehole layers and reduces the fracture propagation distance along the radial borehole *** azimuth also influences fracture propagation along the radial borehole *** the azimuth reduces the guiding ability of radial boreholes,which makes the fracture quickly curve to the maximum horizontal stress *** breakdown pressure correlates with diverse fracture geometries *** the fractures connect multi-layer radial boreholes,increasing the vertical distance decreases the breakdown *** the azimuth and increasing the diameter also decrease the breakdown *** extrusion force exists between the adjacent fractures generated in radial boreholes in multiple rows,which plays a crucial role in enhancing the guiding ability of radial boreholes and results in higher breakdown *** research provides valuable theoretical insights for the field application of radial borehole fracturing technology in tight oil and g

关键词： Multi-layer radial boreholes Hydraulic fracturing Fracture propagation Pressure characteristic

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The impact of cleats on hydraulic fracture initiation and propagation in coal seams

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petroleum Science 2014年第4期11卷 532-539页

作者： Fan Tiegang Zhang Guangqing Cui Jinbang College of Mechanical and Transportation Engineering China University of Petroleum College of petroleum Engineering China University of Petroleum Beijing CBM Branch company Huabei Oilfield Company

Cleats are systematic, natural fractures in coal seams. They account for most of the permeability and much of the porosity of coalbed methane reservoirs and can have a significant effect on the success of hydraulic fracturing stimulation. Laboratory hydraulic fracturing experiments were conducted on coal blocks under true tri-axial stress to simulate fracturing stimulation of coal seams. Fractures were initiated by injecting a water gel with luminous yellow fluorescent dye into an open hole section of a wellbore. The impact of cleats on initiation and propagation of hydraulic fractures in coal seams is discussed. Three types of hydraulic fracture initiation and propagation pattern were observed in this study： 1） The hydraulic fracture initiated and then grew along the cleat. 2） The hydraulic fracture initiated along a butt cleat or a fracture （natural or induced by drilling） oriented roughly in the minimum horizontal stress direction, then turned to propagate along the first face cleat that it encountered or gradually turned towards the maximum horizontal stress direction. 3） The hydraulic fracture initiated perpendicular to the minimum stress and, when it encountered a face cleat, tended to propagate along the cleats if the extension direction does not deviate greatly （〈20° as determined in this paper） from the maximum horizontal stress direction. When a coal seam is hydraulically fractured, the resulting fracture network is controlled by the combined effect of several factors： cleats determine the initiation and extension path of the fracture, the in-situ stress state dominates the main direction of the fracture zone and bedding planes impede fracture height growth.

关键词： Cleats coalbed methane hydraulic fracturing coal seam simulation experiment

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