煤层气开发有助于推动我国早日实现碳达峰碳中和目标。我国煤层气开发已基本实现产业化，但受理论技术等因素制约，发展规模与丰富的资源条件不匹配。“十四五”以来，我国煤层气勘探开发取得5个方面的新进展：一是我国开始进入深层煤层气规模开发新阶段，煤层气产量增速明显加快；二是深层煤层气勘探开发取得重大突破，极大拓展了产业发展空间；三是老气田低效区、薄煤层等难采资源增产改造效果显著；四是与“十三五”期间相比，攻关领域由中—浅层煤层气为主转为以深层煤层气为主，以水平井大规模分段压裂技术为代表的煤层气理论技术在地质认识、钻完井、压裂、排采四大关键环节均取得重大创新，产气效果明显提升；五是煤层气产业发展政策环境持续优化。初步研判，我国深层煤层气资源丰富，埋深大于1500m的煤层气资源量约是1500m以浅的资源量2倍以上；我国已探明煤层气储量以中—浅层为主，但采出程度仅为7%，剩余资源规模可观，而老气田还发育丰富的薄煤层气，已证实是现实接替资源。因此，深层煤层气的重大突破和老气田增产改造的成功成为引领我国煤层气产业加速发展的主要推动力，发展前景良好。在综合多家机构和专家研究结果的基础上，研究认为我国煤层气产量2025年有望达到100×10⁸m³，2035年达到300×10⁸m³。但我国煤层气快速发展面临着深煤层、薄煤层等新领域煤层气地质理论认识有待深入系统研究，深层煤层气勘探开发工程技术仍处于攻关阶段，产业发展政策支持力度仍有待完善等挑战。因此，建议加强新领域煤层气风险勘探和选区评价、加强高效勘探开发理论技术攻关以及加强煤层气产业政策支持和发展引导。

中国深部煤层气（埋深>1 500 m）资源丰富，具有吸附气与游离气共存的赋存特征，其赋存状态、成藏特征和开发规律与中—浅部煤层气存在显著差异，成藏演化规律尚不清晰制约了其高效勘探与开发。以鄂尔多斯盆地东缘大宁—吉县区块深部8号煤层为例，通过精细刻画深部煤层气的成藏特征，模拟深部煤层的埋藏演化史、热演化史、生烃演化史，完善了深部煤层气的富集成藏规律和成藏模式，并提出了针对性勘探开发对策。研究结果表明，大宁—吉县区块深部8号煤层全区发育、有机质热演化程度高、干酪根类型为Ⅲ型、生烃潜力大，总生烃强度为（20.2~34.7）×10⁸m³/km²；深部煤储层发育割理、裂隙、组织孔、胞腔孔、气孔、晶间孔和溶蚀孔等储集空间，为深部游离态煤层气提供了良好的储集条件；构造-岩性-水动力耦合封闭利于深部煤层气保存。研究区深部煤层的成藏演化可以划分为初始生烃阶段（阶段Ⅰ，306~251 Ma）、第1次热成因生烃阶段（阶段Ⅱ，251~203 Ma）、有机质热演化作用减缓阶段（阶段Ⅲ，203~145 Ma）、生烃高峰阶段（阶段Ⅳ，145~130 Ma）和成藏状态定型阶段（阶段Ⅴ，130 Ma至今）5个阶段。研究区深部煤层气表现为游离态与吸附态共存，提出了深部煤层气"广覆式生烃、箱式封闭、微构造调整、自生自储、毯式成藏"的富集成藏规律，建立了微幅褶皱与物性耦合控藏（Ⅰ型）、微幅单斜与水动力耦合控藏（Ⅱ型）、物性与水动力耦合控藏（Ⅲ型）3类深部煤层气成藏模式。研究认识有效指导了大宁—吉县区块深部煤层气勘探有利区的优选，建立了深部煤储层有利区评价指标体系，针对不同成藏模式发育区，提出了差异化开发方案，助力研究区实现了深部煤层气真正意义上的效益开发。研究认识对于中国其他区块开展深部煤层气勘探与开发具有重要参考与借鉴意义。

China's deep coalbed methane (CBM) resources, with the burial depths exceeding 1 500 m, are abundant and coexist with adsorbed and free gases. The occurrence state, accumulation characteristics, and development laws of deep CBM differ significantly from those of mid-shallow CBM, and the unclear evolution patterns have restricted its efficient exploration and development. Taking the No.8 deep coal seam in Daning-Jixian block on the eastern margin of Ordos Basin for example, this study finely characterizes the accumulation characteristics of deep CBM and simulates the burial evolution history, thermal evolution history, and hydrocarbon generation history of deep coal seams, thus improving the deep CBM enrichment and accumulation laws and patterns; moreover, the targeted exploration and development strategies are proposed. The results show that the No.8 deep coal seam is widespread in Daning-Jixian block, with high organic matter thermal maturity and Type III kerogen. This indicates significant hydrocarbon generation potential, with the total hydrocarbon intensity of (20.2-34.7) ×10⁸m³/km². The deep coal reservoir develops cleats, fractures, texture pores, cell pores, gas pores, intergranular pores, and dissolution pores, providing favorable conditions for the accumulation of deep free-state CBM. The structural-lithologic-hydrodynamic coupling closure is favorable for the preservation of deep CBM. The evolution stages of hydrocarbon accumulation in deep coal seams in the study area include the initial hydrocarbon generation stage (Stage I, 306-251 Ma), the first thermal hydrocarbon generation stage (Stage II, 251-203 Ma), the decreasing stage of organic matter thermal evolution (Stage III, 203-145 Ma), the hydrocarbon generation peak stage (Stage IV, 145-130 Ma), and the final formation stage of the oil/gas accumulation pattern (Stage V, 130 Ma to present). The deep CBM under free and adsorbed states coexist in the study area. On this basis, the paper proposes the hydrocarbon enrichment and accumulation pattern of "wide covering hydrocarbon generation, box-type closure, microstructure adjustment, self-generation and self-storage, and blanket-type accumulation", and establishes three types of deep CBM accumulation models:microfold and physical property coupling control (Type I), microfault monocline and hydrodynamic force coupling control (Type II), and physical property and hydrodynamic force coupling control (Type III) on reservoir accumulation. These understandings can effectively guide the selection of favorable areas for deep CBM exploration in Daning-Jixian block, establish an evaluation index system for favorable areas in deep coal reservoirs, propose differentiated development plans for exploration areas with different accumulation models, and help achieve the truly efficient and low-cost development of deep CBM in the study area. The research findings have important reference significance for carrying out deep CBM exploration and development in other blocks in China.

本文利用红外热成像手段，对微小煤样内的甲烷吸附区进行了观察，并评估其吸附特征与在煤中的分布规律.研究表明煤中存在不同尺度与甲烷吸附能力的甲烷富集区，吸附/解吸甲烷时，甲烷富集区比邻近区域具有更明显的升温/降温现象.通过图像处理的方法对不同吸附压力条件下的红外热像图中的甲烷富集区进行提取，采用盒维数进行统计发现甲烷富集区符合分形规律.试验表明随着吸附压力升高，甲烷富集区的分形维数增大，分布初值减小.对两个不同煤田的煤层气富集区进行统计表明：从微米级到千米级尺度范围内，甲烷富集区分布具有分形特征，且分形维数均在1.5~2.00之间.

深部煤层气是中国未来天然气规模性增储上产的重要领域，回顾深部煤层气地质研究历史与进展，评述面临问题和探索方向，可为发展适应性勘探开发技术提供借鉴。分析表明，中国在20余年的深部煤层气地质研究中主要取得3方面进展。第一，界定了深部煤层气基本概念及其科学内涵，发现深部煤层吸附气含量存在临界深度，这一深度主要取决于地温梯度和地应力梯度两者的耦合关系，其他地质因素对临界深度具有调整作用；吸附气含量降低可能导致游离气含量随之增高，结果是形成煤层气在深度序列上的有序聚集，在深部形成富含游离气的高饱和—超饱和煤层气藏。第二，对深部煤层地质属性的研究进展显著，认识到深部煤层吸附性减弱及游离气含量增高是地层压力正效应与地层温度负效应之间动态平衡的结果；发现在深度剖面上地应力状态转折带附近存在煤层"高渗窗"，与深部煤层可改造性相关的地层温度、压力指标可能具有"门限"性质，温度补偿效应和变孔隙压缩系数效应可能使得深部煤层渗透率衰减速率显著降低。第三，对深部煤层气成藏作用与地质评价的研究逐渐深入，对成藏作用原理的探讨聚焦在由埋深变化引起的煤层含气性、渗透率垂向分布及其地质控制等5个方面，初步揭示了煤层气成藏"深度效应"。对现场案例进行的剖析经历了由盆地到有利区、由有利区到"甜点"、由控藏到控产的认识深化过程。分析认为，基础地质（成藏作用）、勘查地质（评价优选）、开发地质（动态过程）3方面有机衔接和深度耦合，是面向深部煤层气勘探开发地质—工程一体化所需探索的关键方向，建议未来研究应聚焦"深度效应"，包括深部煤层气藏特征的系统描述和气藏工程对地质条件响应的刻画。

Deep coalbed methane (CBM) will become an important field for China to increase the large-scale natural gas reserves and production in the future. It is of great significance to review the history and progress of the geological research on deep CBM propose and evaluate the existing problems and exploration directions, which can provide a reference for developing applicable exploration and development technologies. Analyses reveal that China has made three major advances in the geological research of deep CBM in the past 20 years. First, the basic concept and its scientific connotation of deep CBM have been defined. It is found that there is a critical depth for the absorbed gas content of deep coalbeds, which mainly depends on the coupling relationship between geothermal gradient and geo-stress gradient, and other geological factors can adjust the critical depth. A decrease in the adsorbed gas content may lead to an increase in free gas content, resulting in the orderly accumulation of CBM in the depth sequence and the formation of highly to super saturated reservoirs with abundant free gas in the deep coal. Second, remarkable progress has been made in research of the geological properties of deep coal reservoirs, and it has been recognized that the weakening adsorption of deep coal reservoirs and the increase of free gas content are resulted from the dynamic equilibrium between the positive effect of pressure and the negative effect of temperature. Moreover, it has been found that there is a "highly permeability window" of coal reservoirs near the transition zone of geo-stress state on the depth profile, and the formation temperature and pressure indices related to the reconstruction of deep coal reservoirs may have a threshold property, and the temperature compensation and variable pore compressibility effects may significantly lower the decay rate of permeability for deep coal reservoirs. Third, an in-depth research is gradually implemented on the accumulation and geological evaluation of deep CBM reservoirs, and the exploration on accumulation mechanism focuses on CBM gas-bearing property formed by buried depth changes, vertical permeability distribution and its geological control, thus initially revealing the "depth effect" for CBM reservoir formation. Through on-site case analysis, the relevant understandings have been deepened and expanded from basin to favorable zone, then to sweet spot and from reservoir control to production control. The analyses suggest that the organic connection and deep coupling of basic geology (reservoir-forming process), exploration geology (evaluation optimization) and development geology (dynamic process) are key directions for the geological-engineering integration in deep CBM exploration and development. Therefore, it is suggested future research should focus on "depth effect", including the systematic description of deep CBM reservoir and the characterization of gas reservoir engineering responses to geological conditions.

库车坳陷北部构造带是塔里木盆地油气增储上产的重要领域。利用最新的露头、钻井等资料，结合前人的研究成果，通过系统梳理和总结库车坳陷北部构造带的基础地质特征和石油地质条件，分析油气成藏模式和勘探潜力，并与邻区克拉苏构造带进行类比，明确了目前勘探需要解决的关键问题。结果表明，库车坳陷北部构造带的主要含油气层系为下侏罗统阿合组辫状河三角洲平原沉积、下侏罗统阳霞组—中侏罗统克孜勒努尔组辫状河三角洲下平原、三角洲前缘和滨、浅湖沉积；巴什构造段和迪北—吐孜构造段分别发育复杂和简单的基底卷入冲断构造，吐格尔明构造段发育古隆起背景下的基底卷入背斜；新近系库车组沉积期—第四纪为构造定型期；烃源岩主要为三叠系—侏罗系湖相泥岩和煤系地层，中—下侏罗统储层为裂缝性致密砂岩储层；发育3套主要的生-储-盖组合，"源、储、盖"紧邻的组合模式是形成致密砂岩气藏的有利条件；发育3类油气藏，构造-岩性油气藏主要分布在吐格尔明背斜及周缘地区，裂缝性连续型致密砂岩凝析气藏主要分布在迪北—吐孜地区，构造型致密砂岩油气藏主要分布在巴什构造段，均具有"先致密后成藏"的特点。库车坳陷北部构造带整体具备形成规模连片油气藏的潜力，新发现油气圈闭22个，总面积为240 km²，预测石油资源量为3 200×10⁴t、天然气资源量为3 500×10⁸m³，随着全区三维地震部署的实施，有望发现更多圈闭。库车坳陷北部构造带与克拉苏构造带一样，具备形成大—中型油气田的地质基础。对于库车坳陷北部构造带的油气勘探，需要在油气保存条件、构造精细建模、储层成因机制、钻完井与储层改造工艺优化方面开展进一步的系统研究；勘探层位应以中—下侏罗统为主，兼顾浅层、深层多目的层系，拓宽油气勘探领域。

The northern tectonic belt of Kuqa depression is a key field for increasing oil and gas reserves and production in Tarim Basin. Using the latest data of outcrop and drilling, in combination with previous research results, this paper analyzes hydrocarbon accumulation models and exploration potentials by systematically summarizing the basic geological characteristics and petroleum geological conditions of the northern tectonic belt of Kuqa depression, then makes a comparison between it and the Kelasu tectonic belt in the adjacent area, and further clarifies the key issues that need to be solved in the current exploration. The results show that the main hydrocarbon-bearing series in the northern tectonic belt of Kuqa depression includes the braided river delta plain deposits in the Lower Jurassic Ahe Formation, the braided river lower delta plain, delta front, shore-shallow lacustrine deposits in the Lower Jurassic Yangxia Formation and Middle Jurassic Kezilenur Formation. Complex and simple basement-involved thrust structures are developed in Bashi tectonic segment and Dibei-Tuzi tectonic section, respectively, and basement-involved anticlines are developed in Tugeerming tectonic segment under the background of paleohigh. The structural forming stage is from the deposition period of Neogene Kuqa Formation to the Quaternary. The source rocks are mainly Triassic-Jurassic lacustrine mudstone and coal-measure strata, and the Middle-Lower Jurassic reservoirs are fractured tight sandstone reservoirs. There are three main sets of source-reservoir-cap assemblages. The combination mode of the adjacent source, reservoir and cap is favorable for the formation of tight sandstone gas reservoirs. There are three types of reservoirs. The structural-lithological reservoirs are mainly distributed in the Tugeerming anticline and its peripheral areas, the fractured continuous tight sandstone condensate gas reservoirs are mainly in the Dibei-Tuzi area, and the structural tight sandstone reservoirs are mainly in the Bashi tectonic segment. They are characterized by "densification first and accumulation later". As a whole, the northern tectonic belt of Kuqa depression has the potential to form large-scale contiguous reservoirs. Twenty-two new oil and gas traps have been discovered, with the total area of 240 km². The predicted oil resources are 3 200×10⁴t, and the natural gas resources are 3 500×10⁸m³. With the implementation of 3D seismic deployment in the whole region, more traps are expected to be discovered. The northern tectonic belt of Kuqa depression, like the Kelasu tectonic belt, has the geological basis for the formation of large-medium-sized oil and gas fields. For the oil and gas exploration in the northern tectonic belt of Kuqa depression, it is required to carry out further systematic studies on oil and gas preservation conditions, fine structure modeling, reservoir genesis, drilling and completion, and improvement of reservoir reconstruction technology. The exploration should focus on the Middle-Lower Jurassic horizons, taking into account both shallow and deep target strata, thus broadening the field of oil and gas exploration.

塔里木盆地库车坳陷南部斜坡带温宿—西秋地区托探1井在寒武系潜山白云岩储层获得重大突破，对库车南斜坡迎烃面多目的层潜山勘探具有重要意义。受制于地质条件复杂，该地区的油气富集规律认识不清、地质结构落实及圈闭刻画难度大，制约了潜山油气勘探。基于构造特征、潜山地层分布、生—储—盖组合、油气输导体系及勘探实践的系统分析，探讨了潜山油气成藏新模式。温宿—西秋地区古生界构造为受前冲断裂沙井子—西秋断裂和反冲断裂乌什南断裂控制的背冲式构造，F1和F2两条次级反冲断裂使得背冲构造复杂化，形成3排古生界潜山构造，每排构造自近断层到远断层区古生界潜山地层由老变新。其中寒武系潜山地层分布范围最广、呈北东东向大面积展布，潜山储层以局限台地颗粒滩相白云岩为主，受多期构造活动、长时期暴露溶蚀叠加改造，裂缝—孔洞型白云岩优质储层规模连片发育。潜山油气藏表现为三叠系黄山街组和侏罗系恰克马克组泥岩联合供烃、裂缝—孔洞型白云岩成储、上覆古近系膏盐岩封盖的生—储—盖组合样式；成藏具有“库车油气远源供烃、不整合面输导、迎烃面构造富集”的特征，主要成藏期在喜马拉雅晚期（4—1Ma）。托探1井的成功钻探，证实了温宿—西秋地区多排多类型潜山巨大的勘探潜力，重新刻画潜山圈闭面积近840km²、石油资源量约2.0×10⁸t、天然气资源量约590×10⁸m³，有望成为油气增储上产新的战略接替区。

针对实验方法获取孔隙度存在单点性和成本昂贵等问题，文章在核磁共振实验分析煤储层孔隙结构和探讨阿尔奇公式在煤层评价中适用性的基础上，创新性地提出了利用核磁数据校正电阻率资料求取的煤储层裂隙孔隙度，获得了电阻率资料有效评价煤储层裂隙孔隙度的方法，取得了较好的效果。实例工区的研究结果表明：该地区核磁T2谱呈现明显的双峰形态，左峰表示吸附孔隙，在离心前后变化小;阿尔奇法计算得到的孔隙度主要反映的是煤储层的裂隙孔隙度;通过核磁技术校正的煤储层裂隙孔隙度精度更高。

如何客观评价页岩油层中的孔隙流体，准确测量和定量表征页岩油及致密油储层含油饱和度与可动油含量等参数，已经成为当前急需解决的重要技术难题。通过率先在国内引入车载移动式全直径岩心核磁共振测量仪，开展了页岩油岩心现场测试分析和评价研究工作，实现了现场对钻井取心进行连续、高精度、无损的快速核磁共振扫描，弥补了核磁共振测井和室内岩心实验的不足，填补了国内页岩油全直径岩心现场测量技术空白。结合现场岩心描述、其他配套实验数据及试油验证，系统总结出不同流体组分的二维核磁共振T₁—T₂图谱特征，明确了不同孔径中油、水信号的T₁/T₂比值变化规律，建立了基于全直径岩心二维核磁共振谱特征的孔隙流体组分分析方法及识别标准，实现页岩油、致密油及复杂碎屑岩等储层孔隙流体组分准确识别与流体饱和度定量解释。车载移动式全直径岩心二维核磁共振测量技术方法在松辽盆地古龙页岩油、鄂尔多斯盆地长7₃页岩油、河套盆地勘探评价中发挥了重要作用，在大庆、长庆、西南、华北、新疆等致密油气田已规模应用，取得良好效果。