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Governed by: China Petrochemical Corporation
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Editor-in-chief: HE Xipeng
eputy Editor-in-chief: GAO Yuqiao; CHEN Zuhua; DING Anxu
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International Standard Serial Number: ISSN 2095-1426
Founded in: 2011
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2026年第16卷第3期
Specialist Forum
摘要：To promote the large-scale and efficient exploitation of shallow shale gas, this study focuses on the complex structural area in the southeastern margin of the Sichuan Basin. The geological characteristics, challenges in efficient exploration and development, countermeasures, and exploration achievements of shallow shale gas were systematically reviewed and analyzed. Theoretical research and exploration practices showed that: (1) Shallow shale gas experienced stronger structural modification and exhibited three key geological characteristics: low formation pressure coefficient (between 0.80 and 1.05), high ratio of adsorbed gas (between 55% and 80%), and high stress difference coefficient (between 0.32 and 0.56). Three types of accumulation models were: shallow monocline type, reverse fault type, and out-of-basin anticline type. Efficient exploration and development faced four major challenges: sweet spot optimization, fast and efficient well completion, full-scale reservoir stimulation, and pressure reduction and drainage. (2) When the burial depth was between 500 and 2 000 m, near-saturated adsorption of shallow shale gas formed a “golden zone” for adsorbed gas enrichment. Reducing the flowing pressure to the sensitive desorption window (pressure between 1.5 and 2.5 MPa) could efficiently activate adsorbed gas desorption. (3) The main controlling factors for the enrichment of the shallow monocline type were formation attitude and burial depth. In response to the characteristics of gentle strata and good self-sealing property of shale, a super-long horizontal well production enhancement technology was developed, thereby increasing the well-controlled reserves and single-well production. In the Nanchuan slope area, the daily gas production of single-well tests ranged from 4.1×104 m3 to 22.1×104 m3, achieving overall proven reserves and efficient development. (4) The main controlling factors for the enrichment of the fault footwall type were fault activity stages and sealing capacity. Considering the characteristics of multi-stage fracture development and moderate in-situ stress, a fracturing technology of “multiple clusters in the middle section, restricted flow perforation, and increased flow rate” was developed to enhance the complexity of the artificial fracture network. In the Daozhen fault footwall area, the daily gas production of single-well tests ranged from 4.5×104 m3 to 13.0×104 m3, achieving a breakthrough in the commercial gas flow threshold for out-of-basin normal-pressure shale gas. (5) The main controlling factors for the enrichment of the out-of-basin anticline type were formation pressure and temperature. Considering the characteristics of high adsorbed gas ratio and weak post-fracturing self-flowing capacity, a “near-zero flowing pressure” production technology was developed to promote adsorbed gas desorption. In the Laochangping anticline type, the daily gas production of single-well tests increased from 0.7×104 m3 to 4.5×104 m3, achieving adsorbed gas desorption and self-flowing production. (6) Adhering to the concept of low-cost and high-quality development, breakthroughs were achieved in fast and efficient drilling and completion technologies centered on the “two-level structure, logging while drilling (LWD), and water-based drilling fluid.” These were integrated with efficient fracturing technologies primarily based on “increased flow rate and net pressure, high intensity and high sand ratio, and multi-stage composite temporary plugging,” resulting in significant production enhancement, cost reduction, and efficiency improvement. Through integrated geological engineering theoretical research and innovative practices, exploration breakthrough and efficient production of shallow out-of-basin shale gas in southeastern Chongqing were achieved, providing theoretical support and practical experience for the efficient development of shallow shale gas in complex structural areas.关键词：shallow shale gas;geology-engineering integration;exploration practices;Wufeng-Longmaxi formation;complex structural area;Southeastern Chongqing;Sichuan Basin176|111|0更新时间：2026-05-09Specialist Forum
摘要：The Lintanchang area of the Sichuan Basin has experienced multiple stages of tectonic movements, resulting in a complex fault and fracture system. Drilling results show that the Upper Ordovician Wufeng Formation-Lower Silurian Longmaxi Formation possesses favorable exploration and development potential. Clarifying the development patterns of faults and associated fractures in these strata is critical for subsequent exploration. In this study, faults in the Lintanchang area were classified into four levels (A, B, C, and D), with three dominant strike directions: NE-trending, near-EW-trending, and near-NS-trending. A-level faults were mainly distributed on the flanks of the anticline, whereas fewer faults developed at the plunging end of the anticline. Using three-dimensional seismic attribute fusion with the fracture development index (FDI), a quantitative study was performed on fault-related fractures in the Wufeng-Longmaxi Formation. The results showed that: (1) The width of fault-related fracture zones exhibited a significant positive correlation with fault displacement. The widths of A-level fracture zones ranged from 510 m to 660 m (average ~600 m), B-level from 160 m to 280 m (average ~220 m), C-level from 130 m to 200 m (average ~168 m), and D-level from 115 m to 170 m (average ~150 m), respectively. Fracture zones in the hanging wall were generally wider than those in the footwall, and fractures were most developed at fault intersections. Among faults of the same level, near-EW-trending faults exhibited the widest fracture zones, followed by near-NS-trending faults, whereas NE-trending faults showed the narrowest zones. (2) Fault-related fracture zones were closely associated with shale gas preservation conditions. Wells located within fracture zones had lower formation pressure coefficients and productivity, whereas wells far from fracture zones exhibited higher pressure coefficients and greater gas production. A significant positive correlation was observed between these two, indicating that fault-related fractures played an important role in controlling pressure maintenance and limiting gas escape. This study reveals the development patterns of faults and associated fractures in the Wufeng-Longmaxi Formation of the Lintanchang area, providing important reference for shale gas sweet-spot selection and well placement in the region.关键词：Lintanchang;Wufeng-Longmaxi formation;shale gas;Attribute Fusion;Fault-Related Fractures;exploration area selection143|324|0更新时间：2026-05-09Oil and Gas Exploration
Fracture stress sensitivity of saline lacustrine shale considering time effect and fluid properties AI导读
摘要：In the process of shale oil and gas development, the fracture network formed by large-scale hydraulic fracturing leads to significant stress sensitivity in the reservoir. The salinity, ion composition, and loading time of fluids may complicate the stress-sensitive behavior of the reservoir, thereby affecting the stimulation performance and the stable production of oil and gas wells. Taking the saline lacustrine shale from the upper part of the fourth member to the lower part of the third member of the Shahejie Formation (Paleogene) in block N, Bohai Bay Basin as the research object, stress sensitivity experiments on fractured shale samples were conducted. The influence mechanism of the coupling of three factors—effective stress, fluid salinity, and loading time—on permeability was systematically analyzed. The results showed that fracture permeability exhibited a two-stage decrease with increasing effective stress, and the rate of decrease gradually slowed down. In the stress range of 3-25 MPa, the permeability decreased rapidly, and the influence of fluid salinity was significant. The permeability of formation water was higher than that of sub-formation water and distilled water. During loading from 5 MPa to 15 MPa, the increases in turbidity and electrical conductivity of the outlet of distilled water were both greater than those of sub-formation water. Moreover, at effective stresses of 10 MPa and 15 MPa, the permeability of distilled water was higher than that of sub-formation water. In the stress range of >25-40 MPa, the rate of permeability decrease slowed down, and the permeabilities of the three fluids tended to converge. Under constant effective stress, the rate of permeability change gradually decreased with prolonged loading time. Additionally, the influence of loading time on permeability diminished as the effective stress increased. Fluid selection for well injection should consider the time-dependent permeability behavior under effective stress. Under low-stress conditions, it is recommended to use high-salinity flowback fluids to prepare injection fluids to reduce stress sensitivity. Under high-stress conditions, it is suggested to use high-strength proppants to prevent fracture closure and to reasonably utilize the salt-dissolving and fracture-enlarging effect of low-salinity fluids to improve seepage channels, thereby ensuring the long-term effectiveness of fracturing stimulation. This study provides an important theoretical basis and practical guidance for the efficient development of lacustrine shale reservoirs and the optimization of fluids for well injection.关键词：shale;stress sensitivity;time effect;fluid salinity;reservoir damage116|141|0更新时间：2026-05-09Oil and Gas Exploration
摘要：The organic-rich deep shale gas reservoirs of the Longmaxi Formation in the Dazu area of western Chongqing exhibit pronounced heterogeneity, which constrains the efficient exploration and development of the Longmaxi Formation shale gas in this region. Three-dimensional seismic data were used to reconstruct the paleogeomorphic pattern of the Early Silurian Longmaxi period in the Dazu area. Combined with lithological and mineralogical data, organic and inorganic geochemical data, well logging-seismic data, and reservoir characterization results, the sedimentary environment, material composition, and reservoir heterogeneity of the Longmaxi Formation under different paleogeomorphic units were investigated, and their genetic mechanisms were explored. The results indicated that: (1) The paleogeomorphology during the deposition of the Longmaxi Formation in the study area showed a step-like pattern, with higher elevations in the north and lower in the south. From north to south, shelf highlands, shelf slopes, and shelf depressions were developed sequentially, and the redox conditions and paleosalinity of the sedimentary water body gradually increased southward. (2) The material composition of shale reservoirs showed a clear co-variation relationship with the secondary paleogeomorphic units. The biogenic quartz content and total organic carbon (TOC) content increased southward, while the clay mineral and terrigenous clastic contents decreased southward. High productivity and good preservation conditions in the shelf depressions favored organic matter enrichment, and diagenetic processes such as feldspar alteration controlled the spatial distribution of mineral composition. (3) The spatial variations in mineral composition and organic matter content further controlled the reservoir characteristics. The porosity of the continental shelf slope was the highest, dominated by intercrystalline pores and organic pores. The porosity of the continental shelf highlands was the second highest, primarily consisting of intergranular and intragranular pores. The porosity of the continental shelf depression was the lowest, which was associated with the small size of organic pores and the filling of intergranular pores by biogenic quartz. (4) Constrained by quantitative inversion and measured data, the thickness of type I shale gas reservoirs gradually increased from the continental shelf highlands to the continental shelf depressions, showing a significant genetic connection with the changes in the sedimentary environment. The differences in sedimentary environment controlled by paleogeomorphology are the fundamental cause of the strong heterogeneity of shale gas reservoirs. The research findings can provide a basis for the efficient exploration and development of heterogeneous shale gas reservoirs.关键词：Dazu Block;Longmaxi Formation;deep shale gas;reservoir heterogeneity;reservoir genesis;paleogeomorphic pattern160|107|0更新时间：2026-05-09Oil and Gas Exploration
摘要：The Wulalike Formation developed in the southwest margin of the Ordos Basin is an important shale gas exploration and development horizon in northern China, characterized by general gas occurrence and local enrichment. Exploring the influencing factors of the development of high-quality source rocks in the Wulalike Formation has important guiding significance for current oil and gas exploration. This study focused on the Wulalike Formation shale from the Shixiagu cross-section in the northern part and the Yindongguanzhuang cross-section in the southern part of the western margin of the basin. A systematic investigation was conducted on the geochemical characteristics of source rocks, the composition of hydrocarbon-generating organisms, and the evolution of the paleoceanic environment to establish the sedimentary model of the Wulalike Formation and identify the influencing factors of the development of high-quality source rocks. The results showed that: (1) The source rocks were primarily developed at the bottom of the Wulalike Formation, with overall low total organic carbon (TOC) content. The thermal maturity ranged from mature to highly mature, and the overall hydrocarbon generation potential was relatively low. (2) The biotic assemblage of the Wulalike Formation included planktonic algae, graptolites, benthic algae, algal sporangia, and radiolarians. Further study confirmed that the hydrocarbon-generating organisms in the source rock intervals were mainly planktic algae bodies and their degraded fragments, with lower contents of graptolites and benthic algae fragments. (3) Trace element geochemical indicators showed that the Wulalike Formation shale was deposited in an anoxic water environment, but the paleoproductivity level was overall low. The sedimentary water body in the northern part of the western margin was anoxic and stagnant, while the sedimentary water body depth in the southern part of the western margin was shallower, with a weaker degree of anoxia. Comprehensive analysis indicates that the organic matter enrichment in the Wulalike Formation shale is influenced by both paleo-marine productivity and the redox conditions of the water body. The overall low paleo-marine productivity level is the primary reason for the low organic matter abundance in the source rocks, while the local redox environment plays a more significant role in regulating the preservation efficiency of organic matter.关键词：Ordos Basin;Wulalike Formation;shale;hydrocarbon-generating organisms;source rock147|156|0更新时间：2026-05-09Oil and Gas Exploration
摘要：Since 2020, exploration of continental shale oil in the second member of the Paleogene Funing Formation (hereinafter referred to as Funing 2 member) in the Qintong Sag, Subei Basin, has continuously yielded discoveries, with proven geological reserves for sub-member Ⅰ exceeding 4 000×104 t for the first time. To systematically reveal the occurrence characteristics and controlling factors of shale oil in sub-member Ⅰ of the Funing 2 member in this sag, analysis techniques such as thin-section observation, scanning electron microscopy, X-ray diffraction, multi-temperature stage rock pyrolysis, low-temperature N2 adsorption, and two-dimensional nuclear magnetic resonance were employed to conduct in-depth research on the mineral composition, pore development characteristics, and pore fluid occurrence state of the shale reservoir. The results indicated that sub-member Ⅰ of the Funing 2 member developed mixed shale, felsic shale, and carbonate shale. The micro-nano scale storage spaces included organic pores, intercrystalline pores, intergranular pores, dissolution pores, clay mineral interlayer fractures, and grain-edge fractures, with clay mineral intercrystalline pores and intergranular pores being the main occurrence sites for shale oil. Shale oil mainly occurred in a free state (accounting for 67%-97%, with an average of 88%). Based on 2D NMR data, the lower limit of oil-bearing pore size was determined to be 5.38 nm, and the lower limit of movable oil pore size was 26.88 nm. The study revealed that organic matter abundance was the core prerequisite for controlling shale oil occurrence, as it determined both the scale of oil generation and dominated the occurrence of adsorbed oil. Mineral composition and occurrence patterns controlled the occurrence of free oil by determining pore types and development scale. When the contents of felsic minerals, clay minerals, and carbonate minerals were in the range of 30%-60%, 20%-40%, and below 30%, respectively, and the ratio of felsic mineral to clay mineral was between 1 and 2, the conditions for free oil occurrence were optimal. The results reveal that intervals with mixed shale and felsic shale, characterized by relatively high organic matter abundance and low carbonate mineral content, have favorable conditions for shale oil occurrence and should be prioritized as the next focus areas for shale oil exploration in the Funing 2 member.关键词：Qintong Sag;second member of Funing Formation;shale oil;occurrence characteristics;controlling factors146|325|0更新时间：2026-05-09Oil and Gas Exploration
摘要：Natural fractures are important reservoir spaces and seepage channels in continental shale reservoirs of the Bonan Subsag, Jiyang Depression. The development characteristics and genetic mechanisms of these fractures directly affect the productivity of single wells. Seismic interpretation, core and thin section observation, scanning electron microscopy, and X-ray diffraction (XRD) analysis were employed to investigate the structural styles, development characteristics of natural fractures, main controlling factors, and the influence of effective fractures on single-well productivity in the lower submember of the third member of the Shahejie Formation in the Bonan Subsag. The results showed that natural fractures in the lower submember of the third member of the Shahejie Formation were classified by genesis into tectonic fractures, diagenetic fractures, and hydrocarbon-generating overpressure fractures. Tectonic fractures were further subdivided based on geological origin into shear fractures, tensile fractures, and bedding-slip fractures. The dominant type of natural fractures was the vertical shear fractures (75°-90°). Overall, the fracture extension lengths were relatively short (5-10 cm), and tensile fractures exhibited slightly larger apertures (0.5-1.0 mm). The fracture fillings were mainly calcite and asphalt, with a high proportion of shear fractures remaining unfilled. The main controlling factors of natural fracture formation included distance from faults, structural combination style, carbonate mineral content, organic matter content, and lithofacies combination types. Natural fractures were more developed near faults, on the fault hanging wall, and in fault-block structural combination styles. Carbonate mineral and organic matter contents were positively correlated with the degree of natural fracture development. Natural fractures were relatively well developed in carbonate-rich shale facies and felsic shale facies. Unfilled and partially filled high-angle shear fractures and tensile fractures were the effective fracture types that contributed most to shale oil productivity, followed by unfilled bedding-slip fractures. This study helps deepen the understanding of the formation mechanisms of natural fractures in eastern continental shale oil, providing an important basis for the exploration and development of fractured shale oil reservoirs in the Bonan Subsag and the entire Jiyang Depression.关键词：Bonan Subsag;lower submember of third member of Shahejie Formation;continental shale;natural fracture;main controlling factors96|564|0更新时间：2026-05-09Oil and Gas Exploration
摘要：The second member of the Paleogene Funing Formation in the Gaoyou Sag, Subei Basin, is one of the key strata for shale oil exploration. Shale reservoir characteristics are important factors influencing oil and gas accumulation, seepage, and migration. To investigate the reservoir characteristics, methods including core observation, X-ray diffraction mineral analysis, N₂ adsorption, scanning electron microscopy, and nuclear magnetic resonance were utilized to study the “four properties” (oil-bearing potential, storage capacity, mobility, and fracturability) of different lithofacies, characterize the reservoir features, and analyze their influencing factors. The results indicated that eight main lithofacies types (Type 1 to Type 8) and four lamination types (felsic lamination, argillaceous lamination, carbonate lamination, and mixed lamination) developed in the study area. The dominant lithofacies were medium-carbon laminated felsic-argillaceous mixed shale, medium-carbon laminated felsic-carbonate mixed shale, and medium-carbon laminated carbonate rock, which were mainly developed in the middle-lower part of sub-member III, sub-member IV, and the middle-lower parts of sub-member V. The storage spaces included pores and fractures. The pores were mainly intergranular (interparticle) pores, while the fractures were mainly tectonic shear fractures, tension-shear fractures, and non-tectonic bedding fractures. The shale reservoirs were influenced by mineral composition, lamination development, and fracture effectiveness. Specifically, intergranular pores in carbonate minerals were relatively small. Higher contents of felsic and argillaceous minerals led to more developed pores and a larger proportion of meso- and macropores. Furthermore, the more uniform the mineral composition of the shale, the better the pore connectivity. Laminated shale exhibited better porosity and permeability, oil-bearing potential, and mobility than other structural types of shale. Unfilled large tectonic shear fractures, bedding fractures, bedding calcite veins, and intralaminar tension-shear fractures constituted effective storage spaces. After fracturing, these could connect pores, forming a complex pore-fracture system. These findings provide support for the evaluation and "sweet spot" selection of shale oil reservoirs in the second member of the Funing Formation, Gaoyou Sag, Subei Basin.关键词：Subei Basin;Gaoyou Sag;second member of Funing Formation;shale oil;storage space;influencing factors107|223|0更新时间：2026-05-09
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- 0 1 Review and prospects of simulation studies on leakage, migration, and transformation of geological CO2 storage 333
- 0 2 Field test effect analysis of CO2 huff and puff for EOR of horizontal wells in tight glutenite reservoir of Mahu Oilfield 327
- 0 3 Research on integrated CO2 huff and puff and displacement for enhanced shale oil recovery in Subei Basin 312
- 0 4 Field application of tight oil factory fracturing in Mahu sag 308
- 0 5 Research progress on machine learning in CO2 enhanced oil and gas recovery and geological storage 291
- 0 6 Characteristics and development practices of CO2 flooding in deep low-permeability reservoirs 290
- 0 7 Application of high pressure water injection expansion in fractured-vuggy carbonate oil reservoir: A case study of well-S1 in Tahe Oilfield 279
- 0 8 Research on high-intensity fracturing stimulation measures for continental shale oil in Subei Basin 272
- 0 9 Different reservoir types of CO2 flooding in Sinopec EOR technology development and application under “dual carbon” vision 258
- 10 Classification and optimization of deep marine shale reservoir facies: A case study of Longmaxi Formation shale in Luzhou block, southern Sichuan Basin 255
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