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油气勘探开发与碳捕集、利用与封存（CCUS）作为保障国家能源安全、推动能源绿色转型的核心领域，一直是油气地质工程研究的前沿与热点。从陆相、海相盆地的沉积特征解析、优质储层成因探索，到 CO₂地质封存工程的水泥环完整性保障、储气库力学安全评价，相关研究的不断突破为油气资源高效勘探开发、碳中和目标落地提供了关键的理论支撑与技术路径。
本期精选《油气藏评价与开发》的 5 篇优质双语研究成果，聚焦黄骅坳陷、高邮凹陷、东海陆架盆地等重点区域的油气勘探核心问题，深入剖析煤系页岩富气潜力、深层异常高孔储层成因、障壁滨岸沉积体系特征；同时围绕 CCUS 与储气库工程实践，开展水泥环应力状态、碳酸盐岩储气库地质力学建模等关键技术研究，精准破解勘探开发与工程安全中的技术难题。接下来，跟随阅读走进这些油气领域的前沿研究，探索能源勘探开发与绿色转型的科学奥秘。
1
黄骅坳陷石炭系—二叠系煤系页岩沉积特征及富气潜力
Sedimentary characteristics and gas enrichment potential of Carboniferous-Permian coal-measure shale in Huanghua Depression
【摘要】为了给渤海湾盆地煤系油气勘探突破提供理论支撑，以黄骅坳陷太原组—山西组页岩为研究对象，利用岩心、薄片、测井、录井和有机地球化学资料，厘定了页岩发育的沉积环境类型，明确了目的层段页岩的沉积演化特征，分析了不同沉积环境页岩的有机地球化学特征，确定页岩气勘探的有利层段。研究结果表明：黄骅坳陷太原组—山西组页岩形成于障壁海岸和三角洲环境，其中太原组下段页岩发育潟湖亚相，上段发育潮坪亚相；山西组下段页岩发育水下分流河道间微相，上段发育分流间湾微相。黄骅坳陷太原组—山西组页岩自下而上总体经历了由障壁海岸相到三角洲相的转变，指示着晚古生代海侵作用由高峰转向衰退的演化过程。页岩有机质丰度以障壁海岸相最高，其次为三角洲相，不同沉积相页岩的有机质类型相近，干酪根均以Ⅲ型为主，包含部分Ⅱ2型，有机质总体处于低成熟—成熟的演化阶段。太原组上段的潮坪页岩为页岩气勘探的有利层段，沧县隆起、东光潜山和北大港潜山等地区是页岩气勘探的有利区。
【Abstract】Shale is at the forefront of oil and gas geological research and a hotspot for exploration; however, research has mainly focused on marine and lacustrine shale systems, while studies on shale within transitional coal-measure strata are relatively limited. The Carboniferous–Permian coal-measure strata in the Bohai Bay Basin are well-developed, characterized by widely distributed, regionally stable, and thick shale layers. These strata represent excellent source rocks and reservoirs, indicating significant potential for oil and gas exploration and development. This study investigated the coal-measure shale of the Carboniferous-Permian Taiyuan and Shanxi Formations in the Huanghua Depression of the Bohai Bay Basin. Using data from core analysis, thin sections, well logging, organic carbon content, Rock-Eval pyrolysis, and vitrinite reflectance (Ro), this study examined the depositional environment types of coal-measure shale, the vertical evolution of the depositional environments, and the organic geochemical properties of the shale from different depositional environments. This research aims to provide a theoretical basis for oil and gas exploration in the Carboniferous-Permian coal-measure strata of the Bohai Bay Basin. The Carboniferous-Permian coal-measure strata in the Huanghua Depression were divided into the Taiyuan Formation and the Shanxi Formation. The Taiyuan Formation was mainly characterized by barrier coastal facies, while the Shanxi Formation was dominated by deltaic facies. The shale of the Taiyuan Formation was primarily deposited in lagoon and tidal flat environments of the barrier coastal system, whereas the shale of the Shanxi Formation was mainly deposited in subaqueous distributary channels and interdistributary bay environments of the deltaic system. The lithological and logging characteristics of shale from different sedimentary facies were identified. Lagoon shale was gray-black, with well-developed horizontal laminations. Under the microscope, felsic material was visible, with fine particle sizes generally at the silt grade. Brownish-red siderite concretions were common, often exhibiting irregular ellipsoidal shapes with their long axes typically aligned parallel to the bedding planes. Lagoon shale exhibited distinct logging responses, characterized by high natural gamma and high resistivity on conventional logs, and bright yellow to bright red backgrounds with faint lamination structures on image logs. Tidal flat shale was mainly deposited in tidal flat environments. It was predominantly gray to black or dark gray. In core samples, well-developed felsic bands with a thickness of approximately 1 mm were visible. These felsic bands were laterally discontinuous and tapered off within the core samples. The particles within the bands were fine-grained, mainly silt-sized. Compared to lagoon shale, the tidal flat shale exhibited significantly lower resistivity. In imaging logs, the color appeared noticeably darker. The low response was attributed to the development of felsic bands within the tidal flat shale. The interbedding of thin sand and mud layers resulted in individual shale layers that were thinner than the vertical resolution of resistivity logging tools, leading to the measured apparent resistivity values being lower than the true formation resistivity. Consequently, the resistivity of tidal flat shale in the study area was significantly lower than that of the lagoon shale. Shale in subaqueous distributary channels was dark gray to gray-black and contained abundant siderite concretions occurring in banded and irregularly massive forms. These concretions mainly consisted of microcrystalline siderite grains, with minor felsic detrital particles, and were commonly associated with carbonaceous debris. Carbon and oxygen isotope analyses indicated that the formation of siderite in the delta front was influenced by organic matter and the water chemistry of the depositional environment. After deposition in the delta front, terrestrial carbonaceous debris decomposed, releasing CO32−, which combined with Fe2+in the pore water to form siderite. The water coverage in the delta front also provided favorable conditions for siderite development. The abundant siderite in the shale reduced the formation conductivity and radioactive element content, resulting in low resistivity, uranium, and thorium readings on logs. Conversely, the high photoelectric absorption cross-section (Pe) of siderite increased the Pevalue of the formation. Shale in interdistributary bays exhibited diverse colors, including dark gray, gray, and variegated colors, indicating strong water-level fluctuations during deposition and the presence of both subaqueous and emergent environments. Siderite was less developed in the interdistributary bay shale. Consequently, its resistivity and radioactive element content were significantly higher, and its Pevalue was significantly lower than those of the subaqueous distributary channel shale. The depositional evolution of the Taiyuan and Shanxi Formations recorded a transition from the peak of the Late Paleozoic marine transgression to subsequent regression. Consequently, the depositional environments of shale transitioned from barrier coastal to deltaic facies, with shale sequentially developing in lagoon, tidal flat, delta front, and delta plain subfacies from bottom to top. The measured total organic carbon content of the shale varied among depositional environments: lagoon shale (0.11%–19.30%, avg. 3.81%), tidal flat shale(0.70%–17.99%, avg. 4.18%), subaqueous distributary channel shale(0.29%–5.91%, avg. 2.45%), and interdistributary bay shale(0.03%–7.36%, avg. 2.21%). A comparison showed that the tidal flat shale had the highest average total organic carbon abundance, followed by lagoon shale, subaqueous distributary channel shale, and interdistributary bay shale. Overall, the organic matter abundance of shale from barrier coastal facies was higher than that from deltaic facies. The organic matter types of shales from different depositional environments were similar, primarily Type Ⅲ kerogen with some Type Ⅱ2, indicating a mixed input of terrestrial higher plants and aquatic lower organisms, with terrestrial higher plants being the dominant source. The measuredRovalues ranged from 0.60 % to 1.12%, indicating that the organic matter was generally in a low-maturity to mature stage. The total organic carbon abundance of tidal flat shale (avg. 4.18%) was slightly higher than that of lagoon shale and significantly higher than that of deltaic shales, making it favorable for shale gas generation. The higher content of felsic particles in tidal flat shale enhanced the development of macropores and micropores, which were beneficial for shale gas storage. Meanwhile, the felsic particles increased the brittle mineral content, thereby enhancing the stimulation potential of the shale. Gas logging data also indicated gas-rich intervals within the shale. Overall, the Taiyuan Formation exhibited stronger gas logging responses than the Shanxi Formation, and tidal flat shale outperformed lagoon shale. These characteristics indicated that the tidal flat shale in the upper Taiyuan Formation was the most promising gas-rich interval. During the Early Permian deposition of the upper Taiyuan Formation, the marine transgression in North China mainly originated from the southeast. Tidal flat deposits were extensively developed across most of the Huanghua Depression, while barrier islands and lagoon deposits were confined to the eastern Chenghai area. Tidal flats were primarily distributed in the western part of the Huanghua Depression, with a northeast-southwest trend. Within this trend, the Cangxian uplift, Dongguang, Wumaying, Kongdian, Beidagang, Qibei, and Qinan buried hills were identified as favorable areas for shale gas exploration.
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2
高邮凹陷阜宁组一段深层异常高孔成因类型及演化模式
Genetic types and evolution models of abnormally high porosity in deep field of first member of Funing Formation, Gaoyou Sag, Subei Basin
【摘要】古近系阜宁组一段（以下简称阜一段）是苏北盆地高邮凹陷油气富集层系之一，深部储层勘探潜力较大，但储层物性整体较差，制约了该领域的勘探拓展。为了明确局部异常高孔发育、储集条件良好的“甜点”储层展布规律和有利区带，有必要系统开展高邮凹陷阜一段深层异常高孔成因类型及储层演化模式研究。研究利用储层物性分析、薄片观察、电镜扫描、阴极发光等手段，并通过剥去盐城组地层厚度及划分构造单元等方法来开展阜一段深层储层物性分析，认为不同区带阜一段异常高孔分布特征存在明显差异，其中，斜坡带发育双异常高孔段，而断阶带仅发育单一异常高孔段，并明确了异常高孔发育区带。针对不同区带异常高孔的差异成因控制因素进行分析，明确了油气伴生、异常高压是控制异常高孔发育成因的关键因素，其中，油气伴生有助于促进溶蚀、抑制胶结等成岩作用，是斜坡带中坡及断阶带地区异常高孔发育的关键控制因素；地层异常高压有利于促进油气伴生，并起到促进溶蚀、抑制胶结、减缓压实等成岩作用，是斜坡带内坡地区异常高孔发育的关键控制因素。根据关键因素差异及地层压力区带分布，将阜一段异常高孔分为油气伴生型和异常高压型两种成因类型，其中，油气伴生型主要分布在埋藏相对较浅、局部处在深部储层的斜坡带中坡及断阶带等地区，而异常高压型主要处在斜坡带内坡地区，是深层储层的主要类型。同时，建立了阜一段深层两类异常高孔演化模式，其中斜坡带中坡、断阶带主要为油气伴生溶孔保孔模式，而斜坡带内坡为油气伴生与异常高压叠合溶孔保孔模式。在此基础上，指出了斜坡带内坡等深部储层构造高带与地层异常高压叠合区内的有效圈闭是“甜点”储层发育的有利位置，为拓展深部储层提供了依据。
【Abstract】The first member of the Paleogene Funing Formation (hereinafter referred to as E1f1) is one of the oil-rich and gas-rich strata in Gaoyou Sag, Subei Basin. It has considerable exploration potential in deep reservoirs, but the overall poor reservoir physical properties have constrained the exploration expansion in this area. To determine the distribution patterns and favorable zones of local “sweet spot” reservoirs with well-developed abnormally high porosity and favorable reservoir conditions, it is necessary to systematically study the genetic types and reservoir evolution models of abnormally high porosity in deep E1f1of Gaoyou Sag. Using reservoir physical property analysis, thin section observation, scanning electron microscopy, and cathodoluminescence, along with stripping the thickness of the Yancheng Formation and dividing tectonic units, this study conducted the physical property analysis of deep reservoirs in E1f1. Significant differences were observed in the distribution characteristics of abnormally high porosity among different zones. Specifically, the slope zone developed two abnormally high-porosity intervals, while the fault-step zone developed only one abnormally high-porosity interval. Additionally, the abnormally highporosity development zones were identified. By analyzing differential genetic controlling factors of abnormally high porosity in different zones, it was determined that oil and gas charging and abnormally high pressure were the two key factors controlling the development zones and genetic types of abnormally high porosity. Oil and gas charging contributed to promoting dissolution and inhibiting cementation, serving as a key controlling factor for the development of abnormally high porosity in the middle slope and fault-step zones. In contrast, abnormally high formation pressure facilitated oil and gas charging, and contributed to diagenetic processes such as promoting dissolution, inhibiting cementation, and slowing compaction, functioning as a key controlling factor for the development of abnormally high porosity in the inner f slope zone. Based on differences in key factors and the distribution of formation pressure zones, abnormally high porosity in E1f1was classified into two genetic types: oil and gas charging type and abnormally high pressure type. The oil and gas charging type was mainly distributed in the middle slope and fault-step zones, characterized by relatively shallow burial depths and local occurrence in the deep field. The abnormally high-pressure type was mainly located in the inner slope zone, representing the main type in the deep field. Two evolution models for abnormally high porosity in deep E1f1were established. Specifically, the middle slope and fault-step zones were mainly characterized by oil and gas charging and a pore-preserving dissolution model, while the inner slope zone was characterized by oil and gas charging and an abnormally high pressure for a pore-preserving superposition dissolution model. On this basis, it is indicated that effective traps in structural high zones overlapping with abnormally high pressure areas of formations in the inner slope and other deep fields are favorable locations for the development of “sweet spot” reservoirs, providing a basis for expanding exploration in deep fields.
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3
东海陆架盆地西湖凹陷障壁滨岸沉积体系及特征——以平北地区平湖组早期为例
Barrier coastal depositional system and its characteristics in Xihu Sag, East China Sea Shelf Basin: A case study of lower Pinghu Formation in Pingbei area
【摘要】西湖凹陷是东海陆架盆地中极具油气勘探价值的富烃凹陷，其始新统平湖组在近年来的勘探工作中持续取得突破，已成为油气勘探开发的重要层位。由于以往研究多基于宏观区域开展且资料分散，致使学术界对平湖组沉积体系的认识存在诸多争议，严重影响后续勘探开发的精准度与效率。研究以西湖凹陷平北地区平湖组早期沉积为切入点，综合运用岩心、测录井、地震等多种资料，深入开展了沉积体系研究，旨在明晰其沉积特征并建立沉积模式。经研究，平湖组下段可划分为层序一、层序二共2个三级层序，二者均展现出显著的潮汐沉积特征，标志性沉积构造包括双向交错层理、再作用面、双黏土层以及脉状—波状—透镜状潮汐复合层理等。其中，层序一时期，研究区呈现典型的障壁滨岸沉积环境。北东—南西走向的障壁砂坝将区域一分为二，西侧形成潟湖—潮坪体系，发育潮道、三角洲前缘等沉积微相；东侧为开阔滨岸体系，发育与障壁岛平行的条带状沿岸砂坝。而在层序二时期，受区域海侵作用的影响，障壁岛—潟湖体系发育受到抑制，沉积环境转变为潮汐主导的开阔潮坪沉积，完整发育砂坪—混合坪—泥坪沉积序列。受潮汐作用影响，潮间带—潮下带发育北西—南东向潮道，潮下带也发育潮汐砂坝和砂坪。进一步通过对砂体类型、形态、展布规律的详细剖析，并结合沉积环境与经典沉积模式，建立了障壁滨岸—潮坪复合沉积模式。模式的建立不仅为理解西湖凹陷沉积演化过程提供了依据，而且对指导西湖凹陷自斜坡带至凹陷区的油气勘探开发具有指导意义。
【Abstract】The Xihu Sag is a hydrocarbon-rich sag with high oil and gas exploration value in the East China Sea Shelf Basin. In recent years, continuous breakthroughs have been achieved in the exploration efforts of the Eocene Pinghu Formation of Xihu Sag, making it an important target for oil and gas exploration and development. However, previous studies were mostly carried out on a macroscopic regional scale with scattered data, resulting in many controversies in the academic community regarding the depositional system of the Pinghu Formation, which seriously affects the accuracy and efficiency of subsequent exploration and development. Focusing on the early deposition of the Pinghu Formation in the Pingbei area of Xihu Sag, this study comprehensively utilized data including core, well logging, and seismic data to conduct an in-depth investigation of the depositional system, aiming to clarify depositional characteristics and establish a depositional model. This study divided the lower Pinghu Formation into two third-order sequences: Sequence 1 (SQ1) and Sequence 2 (SQ2). Both exhibited significant tidal depositional characteristics, with diagnostic depositional structures including bidirectional cross-bedding, reactivation surfaces, double mud layers, and flaserwavy-lenticular tidal composite bedding. During the SQ1 period, the study area exhibited a typical barrier coastal depositional environment. The NE-SW-trending barrier sand bars divided the area into two parts. A lagoon-tidal flat system was formed on the west side, where depositional microfacies such as tidal channels and delta fronts developed. On the east side, there was an open coastal system, where strip-shaped longshore sand bars developed parallel to the barrier island. During the SQ2 period, affected by regional transgression, the development of the barrier island-lagoon system was suppressed, and the depositional environment transformed to a tide-dominated open tidal flat, completely developing a depositional sequence of sand flat-mixed flat-mud flat. Affected by tidal action, NW-SE trending tidal channels developed in the intertidal and subtidal zones, and tidal sand bars and sand flats also developed in the subtidal zone. Furthermore, through a detailed analysis of sand body types, shapes, and distribution patterns, combined with the depositional environment and classic depositional models, a barrier coastal-tidal flat composite depositional model was established. The establishment of this model not only provides a basis for understanding the depositional evolution process of the Xihu Sag but also offers guidance for oil and gas exploration and development from the slope zone to the sag area in Xihu Sag.
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4
东海A区块CCS井固井水泥环应力状态与完整性研究
Study on stress state and integrity of cement sheath in well cementing of CCS pilot well in block A, East China Sea
【摘要】东海A区块浅层CO2地质封存面临着水平地应力差异大、循环应力影响显著等问题，然而现有水泥环完整性模型未有效建立非均匀地应力场与残余应变耦合作用机制，难以有效评估东海A区块浅层低压储层固井水泥环密封失效行为。因此，针对高地应力差的东海A区块CCS先导试验井在间歇性循环加载-卸载工况下的水泥环性能设计及完整性评价问题，在考虑非均匀地应力与水泥环残余应变影响情况下，结合水泥环剪切破坏和拉伸破坏安全系数评价准则，建立套管-水泥环-地层应力计算模型，基于东海A区块CCS先导试验井地质工程参数开展了水泥环力学应力分析与完整性评价，并开展了地应力差、残余应变及水泥环弹性模量等影响因素分析。研究结果表明：沿最小水平地应力方向的套管-水泥环胶结界面是水泥环发生拉伸破坏及剪切破坏的薄弱点；当井口注入压力增加时，水泥环剪切破坏安全系数呈指数式增大而拉伸破坏安全系数呈线性增大，水泥环更倾向于先发生塑性剪切破坏；地应力差有助于提升水泥环破坏安全系数余量，而水泥环残余应变的增加会造成水泥环破坏安全系数增大，水泥环剪切破坏安全系数随弹性模量的增大先增加后减小，因此，须建立注入压力动态调控机制并优化循环加载路径以抑制残余应变累积效应；为降低在水泥环高弹性模量条件下面临的残余应变值高累积风险，避免水泥环弹性模量在较低的水平条件下面临的剪切破坏安全系数余量较低的问题，在工程实践中需结合注入压力工况确定弹性模量阈值，确保在降低应力集中效应的同时避开剪切破坏安全系数的局部极值区域。
【Abstract】The shallow CO2geological storage in block A of the East China Sea faces challenges such as a large difference in horizontal in-situ stress and significant influence of cyclic stress. However, existing cement sheath integrity models have not effectively established the coupling mechanism between the non-uniform in-situ stress field and residual strain, making it difficult to effectively evaluate the sealing failure behavior of the cement sheath in shallow low-pressure reservoirs of block A of the East China Sea. Therefore, aiming at the performance design and integrity evaluation of cement sheath under intermittent cyclic loading-unloading conditions of CCS pilot test well in block A of the East China Sea with high in-situ stress difference, and considering the influence of non-uniform in-situ stress and residual strain of cement sheath, a casing-cement sheath-formation stress calculation model was established based on the evaluation criteria of shear failure and tensile failure safety factors of the cement sheath. Using the geological engineering parameters of CCS pilot test well in block A of East China Sea, mechanical stress analysis and integrity evaluation of cement sheath were conducted, and influencing factors such as in-situ stress difference, residual strain, and elastic modulus of cement sheath were analyzed. The results showed that the casing-cement bonding interface along the direction of minimum horizontal in-situ stress was the weak point for tensile failure and shear failure of cement sheath. When the wellhead injection pressure increased, the shear failure safety factor of cement sheath increased exponentially while the tensile failure safety factor increased linearly, and the cement sheath tended to undergo plastic shear failure first. In addition, the in-situ stress difference helped increase the margin of cement sheath failure safety factor, while the increase in cement sheath residual strain caused the increase in cement sheath failure safety factor. The shear failure safety factor of cement sheath first increased and then decreased with the increase of elastic modulus. Therefore, it is necessary to establish a dynamic control mechanism of injection pressure and optimize the cyclic loading path to suppress the cumulative effects of residual strain. To reduce the high cumulative risk of residual strain under conditions of high elastic modulus of cement, and to avoid the problem of low shear failure safety factor margin under relatively low elastic modulus conditions, it is necessary to determine the threshold of elastic modulus according to the injection pressure conditions in engineering practice, ensuring that the stress concentration effects are reduced while avoiding the local extreme value region of the shear failure safety factor.
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5
枯竭气藏型碳酸盐岩储气库地质力学建模与完整性评价
Geomechanical modeling and integrity evaluation of gas storage rebuilt from depleted carbonate gas reservoir
【摘要】储气库对保障国家能源安全与调峰保供至关重要，储气库在运行中易出现断层活化、局部盖层突破等状况，引发气体泄漏风险，因此有必要分析其力学完整性。为了明确X储气库应力变化的内在规律、提高储气库运行压力上限、提升整体储气效能，综合地质、地震、测井、生产和室内实验数据，建立了X储气库一维、三维地质力学模型，融合生产历史拟合与循环注采情况，建立了四维动态地质力学模型；分析了注采过程中盖层、储层、底托层、断层应力变化规律和力学完整性，并综合注采能力与力学完整性开展注采方案优化。结果表明：(1)X储气库龙潭组盖层杨氏模量较小、泊松比较大、强度较弱，岩性越偏泥岩，模量越小，水平向应力越小；(2)盖层原始地应力呈走滑断层状态，储层原始地应力为逆断层状态；(3)X储气库注采过程中，盖层和底托层应力变化较小、破坏风险低；(4)储层孔隙压力变化明显，且变化幅度大于应力；(5)注采过程中，储层基质破坏风险较低，主要注采区域在注气后破坏风险增大，断层在井底压力高于原始气藏压力约3 MPa时有滑移风险；(6)在保证X储气库力学完整性前提下，优化注采方案后的累计注气量较优化前增加约34%。研究成果可为X储气库地应力分析、力学完整性评价工作提供理论和方法支撑。
【Abstract】Gas storage facilities are crucial for ensuring national energy security and stabilizing supply during peak-demand periods. However, during operation, gas storage facilities are prone to risks such as fault reactivation and local caprock breakthrough, potentially leading to gas leakage. Therefore, it is necessary to analyze their mechanical integrity. To clarify the stress variation patterns of the gas storage X and enhance the upper limit of the operational pressure and overall storage efficiency, this study integrated geological, seismic, logging, production, and laboratory data to establish one-dimensional and three-dimensional geomechanical models of the gas storage X. Based on production history matching and cyclic gas injection and production patterns, a four-dimensional dynamic geomechanical model was established. The stress variation patterns and mechanical integrity of the caprock, reservoir, base support layer, and faults during the injection and production process were analyzed. The injection-production plans were optimized by considering deliverability and mechanical integrity. The results showed that: (1) The Longtan Formation caprock of the gas storage X was characterized by a relatively low Young’s modulus, high Poisson’s ratio, and weak mechanical strength. The more argillaceous the lithology, the lower the modulus and the smaller the horizontal stress. (2) The initial in-situ stress state of the caprock corresponded to a strike-slip faulting regime, while the reservoir corresponded to a reverse faulting stress regime. (3) During the injection-production process of the gas storage X, the caprock and base support layer experienced minimal stress variation and posed low failure risk. (4) The pore pressure of the reservoir changed significantly, and the pressure variation was greater than stress changes. (5) During the injection-production process, the risk of matrix failure in the reservoir was low, but the failure risk increased in the main injection-production area after gas injection. There was a slip risk when the bottom hole pressure exceeded the original gas reservoir pressure by about 3 MPa. (6) Under the condition of ensuring the mechanical integrity of the gas storage X, the optimized injection-production plan yielded an approximately 34% increase in cumulative gas injection compared to pre-optimization. The results provide theoretical and methodological support for in-situ stress analysis and mechanical integrity evaluation of the gas storage X.
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