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Governed by: China Petrochemical Corporation
Sponsored by: East China Petroleum Bureau
Editor-in-chief: HE Xipeng
eputy Editor-in-chief: GAO Yuqiao; CHEN Zuhua; DING Anxu
National Unified Continuous Number: CN 32-1825/TE
International Standard Serial Number: ISSN 2095-1426
Founded in: 2011
Frequency: bimonthly (on 26th each even-number month)
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2026年第16卷第2期
Specialist Forum
摘要：To address the core challenges such as rapid decline and low recovery factor during depletion development after volume fracturing, this study investigated the feasibility and optimization strategies of integrated CO2 huff and puff and displacement for enhancing shale oil recovery in the Subei Basin, following a research approach of mechanism experiments-model construction-field verification. First, multi-mechanism seepage experiments, including shale core imbibition, dissolution, and CO2 huff and puff and displacement, were conducted to reveal pore structure evolution and differences in imbibition and displacement efficiency under the influence of different fluids. The characteristics of hydrocarbon mobilization, pressure propagation, and sweep efficiency in the integrated CO2 huff and puff and displacement mode were quantitatively characterized. Finally, based on the experimental mechanisms and numerical simulation, key technical policies for CO2 injection development (e.g., huff and puff cycles and water-alternating-gas (WAG) timing) were optimized. The experimental results showed that: (1) Under carbonated water conditions, shale pore structures were significantly improved, and the imbibition-displacement equilibrium time was shortened to 15% of that under formation water. (2) CO2 huff and puff preferentially mobilized light hydrocarbon components, and the oil increment increased rapidly at first and then slowed as the huff and puff cycles increased, with the first three cycles accounting for over 90% of the total oil increment. (3) After huff and puff, imbibition pretreatment of the shale cores resulted in a higher CO2 displacement pressure gradient, enabling CO2 to enter smaller pore spaces, strengthening gas channeling suppression and expanding the sweep range, and increasing displacement efficiency by 4.24%. Based on these results, a shale oil development mode of “three-cycle huff and puff + WAG drive” was proposed and optimized using a compositional numerical model, and the end of natural-flow production was selected as the timing for huff and puff and displacement gas injection. This mode fully leveraged miscibility, WAG-driven sweep expansion, and gas channeling suppression, thereby further expanding the extent and degree of CO2 mobilization and increasing recovery by 12.1% compared with depletion development. Pilot injection tests in two wells confirmed that Subei shale oil had favorable gas injection capability. For well LY1-1, the peak daily oil production in the first huff and puff cycle reached 27.9 t, the cumulative oil increment was estimated to be 2 500 t, and the oil exchange ratio was 0.25 t/t (oil produced per 1 t of CO₂ injected), meeting the phased expected targets and confirming the promising development prospects of CO2 injection in Subei shale oil.关键词：shale oil;CO2;integrated huff and puff and displacement;numerical simulation;enhanced oil recovery191|44|0更新时间：2026-03-10Specialist Forum
摘要：Continental fine-grained muddy-laminated shale oil is widely developed in eastern China’s faulted lacustrine basins such as the Bohai Bay Basin and Subei Basin. It is characterized by “fine grain size and numerous laminae”, representing a significant new frontier in shale oil exploration and development. However, the complex formation conditions and enrichment patterns of laminated shale oil constrain its effective exploration and development. This study aims to systematically reveal the main controlling factors of the enrichment of this shale oil type, establish corresponding geological theories and reservoir formation models, and develop a supporting key technology system to guide exploration practices and evaluate its resource potential. By comprehensively utilizing core data, well logs, 3D seismic data, geochemical experiments, and production performance data, the geological characteristics, formation conditions, enrichment patterns, and key exploration and development technologies for laminated shale oil were systematically analyzed. The study clarified the advantageous composition of “high brittleness minerals + high-frequency laminae”, the optimal thermal evolution window (maturity between 0.7% and 1.2%), and the enrichment patterns of “medium-to-high matching” (source-to-reservoir lamina thickness ratio of 1∶1.5) that yielded the highest oil content in muddy-laminated shale oil. Two types of micro-migration reservoir formation models were established: felsic + organic matter and calcareous-dolomitic + organic matter. A quantitative standard for identifying Class I enrichment layers was developed, focusing on free hydrocarbon (S1), volume fraction of brittle minerals, resistivity ratio, and natural gamma. A key technology system was developed, centering on geology-logging-seismic integrated “sweet spot” characterization, optimization of horizontal well group parameters, efficient volume fracturing, and controlled pressure production techniques. After the application of this technology system, breakthroughs in high-yield shale oil were achieved in depressions such as Huanghua, Jiyang, Liaohe, Jizhong, and Dongtai. The geological resources of shale oil in eastern faulted basins were estimated to exceed 100×108 t, demonstrating promising development prospects. Additionally, the study identified challenges of shale oil from faulted lacustrine basins, including small “sweet spot” scale, great burial depth, inter-well interference, and rapid decline. It proposed research directions such as cost reduction and efficiency improvement, digitalization, and in-situ conversion. By 2030, continental shale oil production in China would account for about 8% of China’s total production.关键词：faulted basin;continental shale oil;medium-to-high matching;micro-migration reservoir formation model;development practices100|133|0更新时间：2026-03-10Specialist Forum
摘要：Accelerating digital and intelligent transformation is a crucial measure for oil and gas enterprises to advance industrial transformation and upgrading and foster new productive forces. Sinopec’s upstream sector in China has thoroughly implemented the “Digital and Intelligent Sinopec” initiative, focusing on supporting corporate reform and management. By closely aligning with the development trends of digital and intelligent technologies and the demands of exploration and production operations, the digital and intelligent transformation has been steadily advanced. A group-level Exploration and Development Data Center (EPDC) has been established, aggregating 17.2 PB of various types of exploration and development data, which has enabled centralized data management and shared applications. An Internet of Things network covering oil and gas production sites has been nearly completed, with digital coverage rates for oil, gas, and water wells, and station facilities reaching 94.90% and 92.30%, respectively. This has fundamentally transformed the traditional manual management model of stationing personnel at wells and stations, effectively supporting the reform of production operation modes and labor organization under digital and intelligent conditions. The construction and deepened application of unified systems have been advanced coordinately, continuously improving the digital coverage across all exploration and development business operations. Sinopec has also actively promoted the construction of artificial intelligence (AI) scenarios and their pilot applications, achieving notable results in scenarios such as intelligent seismic processing and interpretation, intelligent rock thin-section identification and analysis, intelligent reservoir numerical simulation, intelligent drilling, intelligent fracturing, and intelligent well condition diagnosis. Looking ahead to the “15th Five-Year Plan”, Sinopec’s upstream sector in China aims to build intelligent oil and gas fields, accelerate the integration of data flow, business flow, value flow, and supervision flow (“four flows in one”), and promote the construction and application of high-value AI scenarios across the entire business chain. These efforts will support the deeper and more substantive integration of digitalization and intellectualization, enhancing the operational efficiency, economic benefits, and management capability of oil and gas exploration, development, and production.关键词：Internet of Things;data governance;digital and intelligent transformation;architecture of intelligent oil and gas fields;“four flows in one”129|317|0更新时间：2026-03-10Oil and Gas Exploration
摘要：Given the difficulty in accurately determining the total amount of retained hydrocarbons in shale with current experimental techniques, this study aims to achieve a precise evaluation of shale oil content. Using sealed core samples from well H in the Subei Basin as the subjects, this study employed multiple experimental methods, including freeze pyrolysis, multi-temperature step pyrolysis, sealed thermal release, and two-dimensional nuclear magnetic resonance (2D-NMR) to systematically evaluate the oil content and mobility. Through comparative pyrolysis experiments at different storage times and sealed thermal release experiments, the light hydrocarbon recovery coefficient for shale oil in the second member of the Funing Formation was determined to be 1.99. Combined with the difference in pyrolysis S2 peak areas before and after extraction, a heavy hydrocarbon correction formula was established (0.452 6×S2-0.307 9), enabling accurate calculation of the total retained hydrocarbons. Furthermore, 2D-NMR technology was used to calibrate crude oil of different qualities, and a standard curve between hydrogen nucleus signal intensity and oil mass was established, enabling non-destructive and rapid determination of oil content. By comparing NMR spectra before and after oil washing, the T₂ cutoff values for movable and adsorbed oil were identified, facilitating the calculation of free oil content and its proportion. The experimental results showed that the oil content measured by the 2D-NMR method was highly consistent with the recovered oil content, and the proportion of free oil showed a good correlation with results from multi-temperature step pyrolysis. The technical framework of “light hydrocarbon recovery-heavy hydrocarbon correction-NMR calibration-movable oil identification” established in this study offers advantages such as relative operational simplicity, a broad detection range, and non-destructiveness to samples. Overall, it significantly improves the accuracy and efficiency of shale oil content and mobility evaluation, providing crucial experimental support for shale oil sweet spot identification, reserve calculation, and development potential assessment.关键词：shale oil;light hydrocarbon recovery;heavy hydrocarbon correction;oil content;two-dimensional nuclear magnetic resonance (2D-NMR)66|97|0更新时间：2026-03-10Oil and Gas Exploration
摘要：Exploration breakthroughs of shale oil have been successively achieved in the second member of the Paleogene Funing Formation in four main sags (Qintong, Gaoyou, Jinhu, and Haian) of the Subei Basin, marking an important area for future increases in reserves and production. The evolution of shale oil accumulation processes differs greatly among major sags. The unclear understanding of the differences in preservation conditions, controlling factors, and the development patterns of formation overpressure for shale oil has constrained further exploration deployment. Starting from the differential evolution processes of the major sags, and combined with a comparative analysis of the top-bottom conditions, fault development, and fault activity, the differences in shale oil preservation conditions and their influencing factors across various sags were clarified. Additionally, the preservation mechanisms of abnormal overpressure in complex fault-block areas was revealed. The results indicated that the differences in the sedimentary facies belts of the second member of the Paleogene Funing Formation’s base in the eastern and western parts of the basin formed the basis for current differences in formation overpressure. The activity and development degree of faults within each sag during the Wubao event, as well as the differential controlling effect of the Tan-Lu fault zone on the western part of the basin on each sag (manifested as a gradual weakening of late-stage fault activity in the second member of the Paleogene Funing Formation from west to east), constituted the core of current differences in formation overpressure across the sags. During the middle to late stage of sedimentation of the Yancheng Formation, the Haian and Yancheng Sags in the eastern part of the basin first entered the hydrocarbon generation threshold, while the Qintong, Gaoyou, and Jinhu Sags in the central and western part experienced local deepening, increased thermal maturity, and secondary hydrocarbon generation. This process was crucial in the current differences in formation overpressure across the sags. For medium-to-high maturity shale oil, the preferred favorable exploration areas were located in the deep and stable zones of the Jinhu, Gaoyou, and Qintong Sags. For low to medium maturity shale oil, the preferred favorable exploration areas were located in the deep zones of the Haian and Yancheng Sags. Moreover, within a sag, larger fault scales and closer proximity to faults were less favorable for shale oil preservation. The research findings provide guidance for shale oil exploration in continental fault-depression basins.关键词：Subei Basin;second member of Funing Formation;shale oil;preservation conditions;formation overpressure77|47|0更新时间：2026-03-10Oil and Gas Exploration
摘要：Porosity and oil saturation are critical parameters in shale oil reservoir evaluation, but current laboratory measurements face challenges. In contrast, using wellsite mobile two-dimensional nuclear magnetic resonance (2D NMR) measurements can minimize the impact of light hydrocarbon loss, allowing for timely measurements of shale cores and the acquisition of relatively accurate parameters of porosity, oil saturation, and movable oil saturation. First, based on the geological characteristics of shale oil reservoirs in the second member of the Funing Formation (Fu-2 member) in the Subei Basin, a 2D NMR fluid type identification chart was constructed under laboratory conditions based on specialized experiments. This chart enabled the identification of fluid components including adsorbed oil, bound oil, movable oil, capillary-bound water, and clay water. Laboratory measurements were conducted under the same temperature and pressure conditions as wellsite measurements. The relaxation-time cutoff values for each fluid component, determined by high-precision laboratory 2D NMR measurements, were used to calibrate the field 2D NMR spectra. Then, a wellsite mobile 2D NMR fluid identification chart was established, leading to the development of evaluation models for porosity, oil saturation, and movable oil saturation. Both wellsite and downhole 2D NMR measurements employed the same echo spacing and resonance frequency to ensure consistent shapes of their 2D NMR spectra. Then, with the wellsite 2D NMR spectrum as a reference, a translation method was applied to correct the downhole NMR spectra for temperature and pressure effects. Consequently, a fluid identification chart and quantitative evaluation model for shale oil reservoirs based on downhole 2D NMR logging were established. This technique was applied and validated through comparison in four wells within the shale oil reservoir area of the Fu-2 member in the Subei Basin. The results demonstrated consistency between wellsite and downhole NMR measurements and showed a high agreement with laboratory results. These findings demonstrate the broad application prospects of mobile 2D NMR measurement technology for evaluating shale porosity, oil saturation, and movable oil content.关键词：second member of Funing Formation;shale oil;two-dimensional nuclear magnetic resonance (2D NMR);porosity;oil saturation89|66|0更新时间：2026-03-10Oil and Gas Exploration
摘要：In the exploration and development of marine shale gas in southern China, traditional lithofacies classification does not fully account for the effect of thermal maturity on reservoir space, resulting in suboptimal development of thermally mature marine shales. Therefore, a reservoir facies classification method based on thermal maturity, organic matter content, and mineral composition was proposed to improve the accuracy of reservoir evaluation and identify optimal reservoir facies types. Thin section observation, scanning electron microscopy (SEM), and various experimental tests were conducted to systematically analyze the reservoir facies characteristics of the Lower Silurian Longmaxi Formation shale in the southern Sichuan Basin, and a comprehensive reservoir evaluation was conducted. The research results showed that the reservoir facies of the Longmaxi Formation shale in southern Sichuan were mainly overmature organic-rich siliceous shale (OR-S) and overmature organic-rich mixed shale (OR-M). Vertically, the reservoir facies showed a transition from overmature organic-rich siliceous shale (OR-S) at the bottom to overmature organic-rich mixed shale (OR-M) at the top. Laterally, the reservoir facies exhibited significant heterogeneity, and the siliceous mineral content gradually decreased from southwest to northeast, showing a transition from overmature organic-rich siliceous shale (OR-S) to overmature organic-rich mixed shale (OR-M) and overmature organic-rich argillaceous shale (OR-A). Through grey correlation analysis, a reservoir facies index grading standard was established. Total organic carbon (TOC) content, gas content, porosity, reservoir facies thickness ratio, siliceous mineral content, and clay mineral content were selected as key evaluation indicators, identifying overmature organic-rich siliceous shale (OR-S) as the optimal reservoir facies. This reservoir facies is characterized by moderate thermal maturity, high TOC content, high gas content, large porosity, high siliceous mineral content, and large reservoir facies thickness, exhibiting superior reservoir performance.关键词：Luzhou Block;Longmaxi Formation;thermal maturity;shale reservoir facies;reservoir characteristics103|48|0更新时间：2026-03-10Oil and Gas Exploration
摘要：The Middle-Upper Permian marine shale formations in the middle Yangtze region are an important replacement field for shale gas exploration and development in China, with great resource potential. However, their reservoir development is complex. Based on previous studies, this study systematically summarizes the reservoir characteristics and research progress of three sets of shale formations from the Middle-Upper Permian: Gufeng, Wujiaping, and Dalong Formations in the middle Yangtze region. The results show that: (1) All three sets of shale formations are characterized by high total organic carbon (TOC) contents, moderate thermal maturity, and well-developed nanopores, exhibiting favorable reservoir quality. Among them, the Gufeng Formation shale exhibits the highest TOC content, with kerogen dominated by Type I. The Wujiaping and Dalong Formations show relatively lower TOC contents, and their kerogen is mainly Type II. In terms of lithofacies, the Gufeng and Dalong Formations are dominated by siliceous shale, whereas the Wujiaping Formation exhibits complex lithofacies and significant heterogeneity due to variable depositional environments. In terms of pore structure, the Gufeng Formation shale displays a wide pore-size range, with development from the nanoscale to the microscale, whereas the Wujiaping and Dalong Formation shales are dominated by micropores and mesopores. (2) The three sets of shale reservoirs are complex, characterized by diverse lithofacies, multiple pore types, and strong multi-scale heterogeneity. (3) Overall research on the Middle-Upper Permian marine shale reservoirs in the middle Yangtze region remains relatively limited. Therefore, it is recommended to carry out quantitative reservoir characterization through integrated multi-scale analysis of outcrops, cores, and experiments, promote interdisciplinary collaboration, introduce techniques such as artificial intelligence and big data analysis, establish a comprehensive shale reservoir evaluation system tailored to the geological characteristics of this region, and conduct graded optimization and evaluation of “sweet spot” intervals and areas, thereby providing solid theoretical support and decision-making guidance for large-scale exploration and effective development of Middle-Upper Permian marine shale gas in the middle Yangtze region.关键词：shale reservoir;Gufeng Formation;Wujiaping Formation;Dalong Formation;Middle-Upper Permian;middle Yangtze region65|161|0更新时间：2026-03-10
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- 0 1 Research progress on machine learning in CO2 enhanced oil and gas recovery and geological storage 238
- 0 2 Characteristics and development practices of CO2 flooding in deep low-permeability reservoirs 237
- 0 3 Review and prospects of simulation studies on leakage, migration, and transformation of geological CO2 storage 231
- 0 4 Application of high pressure water injection expansion in fractured-vuggy carbonate oil reservoir: A case study of well-S1 in Tahe Oilfield 214
- 0 5 Field test effect analysis of CO2 huff and puff for EOR of horizontal wells in tight glutenite reservoir of Mahu Oilfield 212
- 0 6 Field application of tight oil factory fracturing in Mahu sag 210
- 0 7 Study on plume evolution and influencing factors of reservoir and caprock integrity in CO2 deep saline aquifer storage: A case study of Shenhua CCS project 207
- 0 8 Different reservoir types of CO2 flooding in Sinopec EOR technology development and application under “dual carbon” vision 203
- 0 9 Practice of potential tapping of remaining gas in channel sandstone gas reservoir under the background of mudstone interlayers development: A case study of JS22 gas layer in Xinchang Gas Filed 202
- 10 Study on main controlling factors of CO2 huff-n-puff for enhanced oil recovery and storage in shale oil reservoirs 198
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Master Lectures
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00:15:45INTERVIEW: Professor Guo Tonglou, Chief Engineering Master of Sinopec Corp.
2025-08-18播放量： 13 - 00:27:28
INTERVIEW: Professor Guo Jianchun, Vice President of Southwest Petroleum University
2025-08-18播放量： 9
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PRED Talent Showcase
- 00:29:35
ZHANG Tao: Geoscience and Engineering Integration in Unconventional Oil and Gas Exploration and Development — Conceptual Model and Implementation Pathway
2025-10-31播放量： 5 - 00:25:39
Sinopec Shengli Oilfield Company HU Jintao "Methods and Practice of Economic Evaluation for Oil and Gas Reservoir Development"
2025-10-11播放量： 9
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