The marine-continental transitional shale of the Upper Permian Longtan Formation is widely distributed in Hunan and shows significant exploration potential.Frequent changes in lithofacies have however notably influenc...The marine-continental transitional shale of the Upper Permian Longtan Formation is widely distributed in Hunan and shows significant exploration potential.Frequent changes in lithofacies have however notably influenced the shale gas enrichment.The strata of the Longtan Formation in the Shaoyang Depression,central Hunan,were taken as the study object for this project.Three lithofacies assemblages were identified:shale interbedded with sandstone layer(SAL),sandstone interbedded with shale layer(ASL)and laminated shale layer(LSL).The SAL shale shows significant variability in hydrocarbon generation potential,which leads to shale gas characterized by'hydrocarbon generation in high total organic carbon(TOC)shale,retention in low TOC shale and accumulation in sandstone'.The ASL shale,influenced by the redox conditions of the depositional environment,shows a lower concentration of organic matter.This results in an enrichment model of'hydrocarbon generation and accumulation in shale,with sealing by sandstone'.The laminar structure of LSL shale causes both quartz and clay minerals to control the reservoir.Shale gas is characterized by'hydrocarbon generation in mud laminae,retention and accumulation in silty laminae,with multiple intra-source migration paths'.In the marine-continental transitional shale gas system,the enrichment intervals of different types of shale gas reservoirs exhibit significant variability.展开更多
To clarify the main enrichment-controlling factors and accumulation mechanisms of shale gas in the Permian Dalong Formation within the Western Hubei-Eastern Chongqing complex structural zone,this study systematically ...To clarify the main enrichment-controlling factors and accumulation mechanisms of shale gas in the Permian Dalong Formation within the Western Hubei-Eastern Chongqing complex structural zone,this study systematically reveals the enrichment patterns and accumulation model through analysis of typical drilling data,geochemical testing,scanning electron microscopy(SEM),methane isothermal adsorption experiments,numerical simulations,and research on tectonic evolution and preservation condition.The results are obtained in two aspects.First,the enrichment of shale gas in the Dalong Formation is synergistically controlled by four factors,i.e.rift troughs controlling shale development,provenance controlling reservoir heterogeneity,temperature and pressure controlling gas occurrence,and structure controlling differential enrichment.The geometry and scale of rift troughs(Chengkou-Western Hubei,and Kaijiang-Liangping)determine the development of organic-rich shale(average TOC>6%,thickness of 15-50 m).Multi-source materials lead to strong heterogeneity of the reservoir,with endogenous minerals as the main component(accounting for 74.31%),and the pores mainly organic matter pores(micropores and mesopores accounting for 93.4%).The formation temperature and pressure control the occurrence state of shale gas,with adsorbed gas(higher than 50%)dominantly in 500-2750 m depth,while free gas(higher than 50%)prevailing at depth deeper than 2750 m depth.The uplift,erosion,and fault systems associated with the Yanshanian tectonic activity result in differential enrichment of shale gas,with three structural styles—broad gentle anticlines,residual synclines,and low gentle slopes—exhibiting relatively high shale gas enrichment.Second,the self-sealing mechanism of medium-shallow shale gas in the Western Hubei-Eastern Chongqing complex structural zone is revealed.Specifically,the Dalong Formation shale aquifer forms a lateral seal for shale gas in the downdip direction via water films and capillary forces,and it combines with the overlying Daye Formation limestone and underlying Xiayao Formation tight layers to establish a synclinal/monoclinal self-sealing accumulation model.The geological insights,such as“four-factor synergistic control”and self-sealing accumulation model,provide a dynamic coupling evaluation framework for shale gas in complex structural zones,promoting the transition of shale gas exploration and evaluation from static descriptions to integrated reservoir-tectonic-fluid analysis.展开更多
Based on the analysis of Upper Paleozoic source rocks, source-reservoir-caprock assemblage, and gas accumulation characteristics in the Ordos Basin, the gas accumulation geological model of total petroleum system is d...Based on the analysis of Upper Paleozoic source rocks, source-reservoir-caprock assemblage, and gas accumulation characteristics in the Ordos Basin, the gas accumulation geological model of total petroleum system is determined. Then, taking the Carboniferous Benxi Formation and the Permian Taiyuan Formation and Shanxi Formation as examples, the main controlling factors of gas accumulation and enrichment are discussed, and the gas enrichment models of total petroleum system are established. The results show that the source rocks, faults and tight reservoirs and their mutual coupling relations control the distribution and enrichment of gas. Specifically, the distribution and hydrocarbon generation capacity of source rocks control the enrichment degree and distribution range of retained shale gas and tight gas in the source. The coupling between the hydrocarbon generation capacity of source rocks and the physical properties of tight reservoirs controls the distribution and sweet spot development of near-source tight gas in the basin center. The far-source tight gas in the basin margin is mainly controlled by the distribution of faults, and the distribution of inner-source, near-source and far-source gas is adjusted and reformed by faults. Generally, the Upper Paleozoic gas in the Ordos Basin is recognized in four enrichment models: inner-source coalbed gas and shale gas, inner-source tight sandstone gas, near-source tight gas, and far-source fault-transported gas. In the Ordos Basin, inner-source tight gas and near-source tight gas are the current focuses of exploration, and inner-source coalbed gas and shale gas and far-source gas will be important potential targets in the future.展开更多
The typical characteristics of shale gas and the enrichment differences show that some shale gases are insufficiently explained by the existing continuous enrichment mode. These shale gases include the Wufeng–Longmax...The typical characteristics of shale gas and the enrichment differences show that some shale gases are insufficiently explained by the existing continuous enrichment mode. These shale gases include the Wufeng–Longmaxi shale gas in the Jiaoshiba and Youyang Blocks, the Lewis shale gas in the San Juan Basin. Further analysis reveals three static subsystems（hydrocarbon source rock, gas reservoirs and seal formations） and four dynamic subsystems（tectonic evolution, sedimentary sequence, diagenetic evolution and hydrocarbon-generation history） in shale-gas enrichment systems. Tectonic evolution drives the dynamic operation of the whole shale-gas enrichment system. The shale-gas enrichment modes controlled by tectonic evolution are classifiable into three groups and six subgroups. Group I modes are characterized by tectonically controlled hydrocarbon source rock, and include continuous in-situ biogenic shale gas（Ⅰ_1） and continuous in-situ thermogenic shale gas（Ⅰ_2）. Group Ⅱ modes are characterized by tectonically controlled gas reservoirs, and include anticline-controlled reservoir enrichment（Ⅱ_1） and fracture-controlled reservoir enrichment（Ⅱ_2）. Group Ⅲ modes possess tectonically controlled seal formations, and include faulted leakage enrichment（Ⅲ_1） and eroded residual enrichment（Ⅲ_2）. In terms of quantity and exploitation potential, Ⅰ_1 and Ⅰ_2 are the best shale-gas enrichment modes, followed by Ⅱ_1 and Ⅱ_2. The least effective modes are Ⅲ_1 and Ⅲ_2. The categorization provides a different perspective for deep shale-gas exploration.展开更多
Identification of sweet spot is of great significance in confirming shale gas prospects to realize large-scale economic shale gas development.In this paper,geological characteristics of shale gas reservoirs were compa...Identification of sweet spot is of great significance in confirming shale gas prospects to realize large-scale economic shale gas development.In this paper,geological characteristics of shale gas reservoirs were compared and analyzed based on abundant data of domestic and foreign shale gas reservoirs.Key elements of sweet spots were illustrated,including net thickness of gas shale,total organic carbon(TOC)content,types and maturity(Ro)of organic matters,rock matrix and its physical properties(porosity and permeability),and development characteristics of natural fractures.After the data in Changning and Weiyuan blocks,the Sichuan Basin,were analyzed,the geologic laws of shale gas enrichment were summarized based on the economic exploitation characteristics of shale gas and the correlation between the elements.The elements of favorable“sweet spots”of marine shale gas reservoirs in the Changning block and their distribution characteristics were confirmed.Firstly,the quality of gas source rocks is ensured with the continuous thickness of effective gas shale larger than 30 m,TOC>2.0% and R_(o)=2.4-3.5%.Secondly,the quality of reservoir is ensured with the brittle minerals content being 30-69%,the clay mineral content lower than 30% and a single lamination thickness being 0.1-1.0 m.And thirdly,the porosity is higher than 2.0%,the permeability is larger than 50 nD,gas content is higher than 1.45 m^(3)/t,and formation is under normal pressure-overpressure system,which ensures the production modes and capacities.Finally,the primary and secondary elements that control the“sweet spots”of shale gas reservoirs were further analyzed and their restrictive relationships with each other were also discussed.展开更多
During the progressive exploration of the Jingbian Gas Field in the Ordos Basin,multiple gas-bearing regions have been discovered in the dolomite reservoirs in the Middle Ordovician assemblages of Lower Paleozoic in J...During the progressive exploration of the Jingbian Gas Field in the Ordos Basin,multiple gas-bearing regions have been discovered in the dolomite reservoirs in the Middle Ordovician assemblages of Lower Paleozoic in Jingxi area,but these gas-bearing regions and intervals are significantly different in terms of gas enrichment degrees.So far,however,the reasons for the difference have not been figured out.In this paper,the origin and source of natural gas in the Middle Ordovician assemblages in Jingxi area was investigated on the basis of geochemical data(e.g.natural gas composition and carbon isotope),and then the main factors controlling the gas accumulation were analyzed.It is shown that the natural gas in the Middle Ordovician assemblages in the Middle Ordovician assemblages in Jingxi area is similar to that in the Upper Ordovician assemblages and Upper Paleozoic reservoir in terms of genesis and sources,and they are mainly the Upper Paleozoic coaliferous gas with some oil-derived gas.Under the influence of hydrocarbon generation center of coal source rocks and the source-rock-reservoir contact relationship,the proportion of coaliferous gas increases areally from the north to the south and vertically from Ma55 sub-member of the Lower Ordovician Majiagou Fm.It is concluded that the natural gas enrichment degree is controlled by the gas charging capacity at the hydrocarbon-supplying windows.Second,the vertical migration and distribution of natural gas is dominated by the differences of Ma_(5)^(5)-Ma_(5)^(10)transport pathways.And third,the lateral migration direction of natural gas and the range of gas accumulation are controlled by the superimposition relationship between structures and reservoirs.展开更多
The faults and associated fracture zones in the tight sandstone reservoirs of the fifth member of the Triassic Xujiahe Formation(Xu-5 Member)in the Wubaochang area,northeastern Sichuan Basin,play a critical role in co...The faults and associated fracture zones in the tight sandstone reservoirs of the fifth member of the Triassic Xujiahe Formation(Xu-5 Member)in the Wubaochang area,northeastern Sichuan Basin,play a critical role in controlling gas well productivity.To delineate the distribution patterns of the faults and associated fracture zones in this area,a transfer-trained convolutional neural network(CNN)model and an XGBoost(eXtreme Gradient Boosting)-based intelligent seismic attribute fusion method were employed to identify faults and fracture zones,respectively,enabling precise characterization of their spatial distribution.The faults in the Wubaochang area are classified into first-to fourth-order structures,with the average fracture zone width on the hanging wall exceeding that of the footwall,demonstrating a strong positive correlation between fracture zone width and fault displacement.The study area is divided into three distinct deformation regions(southern,central and northern regions)featuring five fault structural styles(duplex,duplex-backthrust,imbricate thrust,synclinorium imbricate-backthrust,and anticlinorium imbricate-backthrust)and four corresponding fracture zone development patterns(duplex,duplex-backthrust,synclinorium imbricate-backthrust,and anticlinorium imbricate-backthrust).Based on the controlling effects of faults on gas enrichment,the dual-source hydrocarbon-supply zones are interpreted to be distributed in the northern and central regions,while the southern region is identified as gas-escape zones.By integrating the distribution of favorable reservoir development areas and fracture zones,two classes of gas enrichment zones(Class Ⅰ and Ⅱ)are delineated.Class Ⅰ zones are primarily distributed in the northern region and the transitional zone from the southern to central regions,whereas Class Ⅱ zones are concentrated in the central region.Class Ⅰ zones exhibit dual-source hydrocarbon-supply conditions,larger-scale fracture zone development,and higher favorability compared to Class Ⅱ zones.According to the defined gas accumulation effectiveness in different types of fracture zones,a high-productivity gas well model for the Wubaochang area is proposed,emphasizing“dual-source faults controlling enrichment,effective fracture zones controlling high production,and high matrix porosity ensuring sustained production”.Targeted drilling directions for different favorable zones are further optimized based on this model.展开更多
By investigating the evolution of shale gas generation,storage,adjustment and accumulation under different structural settings in superimposed basins,this study elucidates the differential accumulation mechanisms of s...By investigating the evolution of shale gas generation,storage,adjustment and accumulation under different structural settings in superimposed basins,this study elucidates the differential accumulation mechanisms of shale gas.An improved evaluation method of shale gas content evolution in superimposed basins is proposed.This method incorporates the coupling effect of key geological factors such as temperature,pressure,organic matter abundance,maturity,and pore characteristics on the content and occurrence state of shale gas,as well as the configuration relationship between shale gas generation and storage throughout geological history.Using this approach,the gas evolution histories of the Longmaxi Formation shales in wells N201 and PY1 are reconstructed under varying geological conditions.The Longmaxi Formation shales in these wells are dominated by typeⅠkerogen,with original total organic carbon(TOC_(o))contents of 6.20 wt% and 4.92 wt%,respectively,indicating differences in the initial material basis for gas generation.At the maximum burial depth of approximately 5000 m,the Longmaxi Formation shale in well N201 exhibits a formation pressure coefficient of 2.05,an organic matter maturity of 2.2%,and organic pores accounting for 68%of the total porosity.The gas generation quantity(Q_(g))reaches 19.24 m^(3)/t,while the gas storage capacity(Q_(s))is 4.30 m^(3)/t.The actual total gas content(Q_(a)),constrained by Q_(s),is 4.30 m^(3)/t,with free gas comprising 94%.Following relatively moderate tectonic uplift,the Q_(a) in well N201 decreases to 4.03 m^(3)/t,with free gas accounting for 63%.In contrast,the Longmaxi Formation shale in well PY1 reached a maximum burial depth of 6300 m,associated with a formation pressure coefficient of 1.62,organic matter maturity of 2.5%,and organic pore proportion of 67%.Here,Q_(g) is 16.87 m^(3)/t,and both Q_(s) and Q_(a) are 3.65 m^(3)/t,with free gas accounting for 98%.After intense tectonic uplift,Q_(a) declines to 2.72 m^(3)/t,and the proportion of free gas drops to51%.Finally,a four-stage differential accumulation model of shale gas is established:Slow gas generation and only adsorbed gas occur in stageⅠ,which is primarily controlled by TOC content;both adsorbed gas and free gas present in stageⅡ,with free gas becoming dominant;rapid gas generation and free gas predominance are controlled by temperature and porosity in stageⅢ;and gas adjustment and accumulation are primarily controlled by temperature and pressure in stageⅣ.展开更多
The Wufeng–Longmaxi Formation derives its name from the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation,found in sequence in the Sichuan Basin.This formation hosts rich shale gas reservoir...The Wufeng–Longmaxi Formation derives its name from the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation,found in sequence in the Sichuan Basin.This formation hosts rich shale gas reservoirs,and its shale gas enrichment patterns are examined in this study using data from 1197 shale samples collected from 14 wells.Five basic and three key parameters,eight in all,are assessed for each sample.The five basic parameters include burial depth and the contents of four mineral types—quartz,clay,carbonate,and other minerals;the three key parameters,representing shale gas enrichment,are total organic carbon(TOC)content,porosity,and gas content.The SHapley Additive exPlanations(SHAP)analysis originated in game theory is used here in an interpretable machine learning framework,to address issues of heterogeneous data structure,noisy relationships,and multi-objective optimization.An evaluation of the ranking,contribution values,and conditions of changes for these parameters offers new quantitative insights into shale gas enrichment patterns.A quantitative analysis of the relationship between data-sets identifies the primary factors controlling TOC,porosity,and gas content of shale gas reservoirs.The results show that TOC and porosity jointly influence gas content;mineral content has a significant impact on both,TOC and porosity;and the burial depth governs porosity which,in turn,affects the conditions under which shale gas is preserved.Input parameter thresholds are also determined and provide a basis for the establishment of quantitative criteria to evaluate shale gas enrichment.The predictive accuracy of the model used in this study is significantly improved by the step-wise addition of two input parameters,namely TOC and porosity,separately and together.Thus,the game theory method in big data-driven analysis uses a combination of TOC and porosity to evaluate the gas content with encouraging results—suggesting that these are the key parameters that indicate source rock and reservoir properties.展开更多
Decarbonization of energy economy is nowadays a topical theme,and several pathways are under discussion.Gaseous fuels have a fundamental role for this transition,and the production of low carbon-impact fuels is necess...Decarbonization of energy economy is nowadays a topical theme,and several pathways are under discussion.Gaseous fuels have a fundamental role for this transition,and the production of low carbon-impact fuels is necessary to deal with this challenge.The generation of renewable hydrogen is a trusted solution since this energy vector can be promptly produced from electricity and injected into the existing natural gas infrastructure,granting storage capacity and easy transportation.This scenario will lead,in the near future,to hydrogen enrichment of natural gas,whose impact on the infrastructures is being actively studied.The effect on end-user devices such as domestic gas boilers,instead,is still little analyzed and tested,but is fundamental to be assessed.The aim of this research is to generate knowledge on the effect of hydrogen enrichment on the widely used premixed boilers:the investigations include pollutant emissions,efficiency,flashback and explosion hazard,control system and materials selection.A model for calculating several parameters related to combustion of hydrogen enriched natural gas is presented.Guidelines for the design of new components are provided,and an insight is given on the maximum hydrogen blending bearable by the current boilers.展开更多
Tectonism is one of the dominant factors affecting the shale pore structure.However,the control of shale pore structure by tectonic movements is still controversial,which limits the research progress of shale gas accu...Tectonism is one of the dominant factors affecting the shale pore structure.However,the control of shale pore structure by tectonic movements is still controversial,which limits the research progress of shale gas accumulation mechanism in the complex tectonic region of southern China.In this study,34 samples were collected from two exploratory wells located in different tectonic locations.Diverse experiments,e.g.,organic geochemistry,XRD analysis,FE-SEM,low-pressure gas adsorption,and high-pressure mercury intrusion,were conducted to fully characterize the shale reservoir.The TOC,Ro,and mineral composition of the shale samples between the two wells are similar,which reflects that the shale samples of the two wells have proximate pores-generating capacity and pores-supporting capacity.However,the pore characteristics of shale samples from two wells are significantly different.Compared with the stabilized zone shale,the porosity,pore volume,and specific surface area of the deformed zone shale were reduced by 60.61%,64.85%,and 27.81%,respectively.Moreover,the macroscopic and fine pores were reduced by 54.01%and 84.95%,respectively.Fault activity and uplift denudation are not conducive to pore preservation,and the rigid basement of Huangling uplift can promote pore preservation.These three factors are important reasons for controlling the difference in pore structure between two wells shales.We established a conceptual model of shale pores evolution under different tectonic preservation conditions.This study is significant to clarify the scale of shale gas formation and enrichment in complex tectonic regions,and helps in the selection of shale sweet spots.展开更多
基金financial support from the National Natural Science Foundation of China(Grant Nos.U23B20155 and 42202140)the Science and Technology Innovation Program of Hunan Province(2023RC1021)+1 种基金the China Geological Survey(DD20221659)the Science and Technology Bureau,Changsha,China(kq2208261)。
文摘The marine-continental transitional shale of the Upper Permian Longtan Formation is widely distributed in Hunan and shows significant exploration potential.Frequent changes in lithofacies have however notably influenced the shale gas enrichment.The strata of the Longtan Formation in the Shaoyang Depression,central Hunan,were taken as the study object for this project.Three lithofacies assemblages were identified:shale interbedded with sandstone layer(SAL),sandstone interbedded with shale layer(ASL)and laminated shale layer(LSL).The SAL shale shows significant variability in hydrocarbon generation potential,which leads to shale gas characterized by'hydrocarbon generation in high total organic carbon(TOC)shale,retention in low TOC shale and accumulation in sandstone'.The ASL shale,influenced by the redox conditions of the depositional environment,shows a lower concentration of organic matter.This results in an enrichment model of'hydrocarbon generation and accumulation in shale,with sealing by sandstone'.The laminar structure of LSL shale causes both quartz and clay minerals to control the reservoir.Shale gas is characterized by'hydrocarbon generation in mud laminae,retention and accumulation in silty laminae,with multiple intra-source migration paths'.In the marine-continental transitional shale gas system,the enrichment intervals of different types of shale gas reservoirs exhibit significant variability.
基金Supported by the National Natural Science Foundation of China(42472210)Project of the China Geological Survey(DD20221653,DD20230043).
文摘To clarify the main enrichment-controlling factors and accumulation mechanisms of shale gas in the Permian Dalong Formation within the Western Hubei-Eastern Chongqing complex structural zone,this study systematically reveals the enrichment patterns and accumulation model through analysis of typical drilling data,geochemical testing,scanning electron microscopy(SEM),methane isothermal adsorption experiments,numerical simulations,and research on tectonic evolution and preservation condition.The results are obtained in two aspects.First,the enrichment of shale gas in the Dalong Formation is synergistically controlled by four factors,i.e.rift troughs controlling shale development,provenance controlling reservoir heterogeneity,temperature and pressure controlling gas occurrence,and structure controlling differential enrichment.The geometry and scale of rift troughs(Chengkou-Western Hubei,and Kaijiang-Liangping)determine the development of organic-rich shale(average TOC>6%,thickness of 15-50 m).Multi-source materials lead to strong heterogeneity of the reservoir,with endogenous minerals as the main component(accounting for 74.31%),and the pores mainly organic matter pores(micropores and mesopores accounting for 93.4%).The formation temperature and pressure control the occurrence state of shale gas,with adsorbed gas(higher than 50%)dominantly in 500-2750 m depth,while free gas(higher than 50%)prevailing at depth deeper than 2750 m depth.The uplift,erosion,and fault systems associated with the Yanshanian tectonic activity result in differential enrichment of shale gas,with three structural styles—broad gentle anticlines,residual synclines,and low gentle slopes—exhibiting relatively high shale gas enrichment.Second,the self-sealing mechanism of medium-shallow shale gas in the Western Hubei-Eastern Chongqing complex structural zone is revealed.Specifically,the Dalong Formation shale aquifer forms a lateral seal for shale gas in the downdip direction via water films and capillary forces,and it combines with the overlying Daye Formation limestone and underlying Xiayao Formation tight layers to establish a synclinal/monoclinal self-sealing accumulation model.The geological insights,such as“four-factor synergistic control”and self-sealing accumulation model,provide a dynamic coupling evaluation framework for shale gas in complex structural zones,promoting the transition of shale gas exploration and evaluation from static descriptions to integrated reservoir-tectonic-fluid analysis.
基金Supported by the National Natural Science Foundation of China (41872128)the CNPC Major Science and Technology Project (2021DJ0101)。
文摘Based on the analysis of Upper Paleozoic source rocks, source-reservoir-caprock assemblage, and gas accumulation characteristics in the Ordos Basin, the gas accumulation geological model of total petroleum system is determined. Then, taking the Carboniferous Benxi Formation and the Permian Taiyuan Formation and Shanxi Formation as examples, the main controlling factors of gas accumulation and enrichment are discussed, and the gas enrichment models of total petroleum system are established. The results show that the source rocks, faults and tight reservoirs and their mutual coupling relations control the distribution and enrichment of gas. Specifically, the distribution and hydrocarbon generation capacity of source rocks control the enrichment degree and distribution range of retained shale gas and tight gas in the source. The coupling between the hydrocarbon generation capacity of source rocks and the physical properties of tight reservoirs controls the distribution and sweet spot development of near-source tight gas in the basin center. The far-source tight gas in the basin margin is mainly controlled by the distribution of faults, and the distribution of inner-source, near-source and far-source gas is adjusted and reformed by faults. Generally, the Upper Paleozoic gas in the Ordos Basin is recognized in four enrichment models: inner-source coalbed gas and shale gas, inner-source tight sandstone gas, near-source tight gas, and far-source fault-transported gas. In the Ordos Basin, inner-source tight gas and near-source tight gas are the current focuses of exploration, and inner-source coalbed gas and shale gas and far-source gas will be important potential targets in the future.
基金supported by the National Basic Research Program of China(grant No.2014CB239205)the sub-project of the National Science and Technology Major Project(grant No.2017ZX05035003)
文摘The typical characteristics of shale gas and the enrichment differences show that some shale gases are insufficiently explained by the existing continuous enrichment mode. These shale gases include the Wufeng–Longmaxi shale gas in the Jiaoshiba and Youyang Blocks, the Lewis shale gas in the San Juan Basin. Further analysis reveals three static subsystems（hydrocarbon source rock, gas reservoirs and seal formations） and four dynamic subsystems（tectonic evolution, sedimentary sequence, diagenetic evolution and hydrocarbon-generation history） in shale-gas enrichment systems. Tectonic evolution drives the dynamic operation of the whole shale-gas enrichment system. The shale-gas enrichment modes controlled by tectonic evolution are classifiable into three groups and six subgroups. Group I modes are characterized by tectonically controlled hydrocarbon source rock, and include continuous in-situ biogenic shale gas（Ⅰ_1） and continuous in-situ thermogenic shale gas（Ⅰ_2）. Group Ⅱ modes are characterized by tectonically controlled gas reservoirs, and include anticline-controlled reservoir enrichment（Ⅱ_1） and fracture-controlled reservoir enrichment（Ⅱ_2）. Group Ⅲ modes possess tectonically controlled seal formations, and include faulted leakage enrichment（Ⅲ_1） and eroded residual enrichment（Ⅲ_2）. In terms of quantity and exploitation potential, Ⅰ_1 and Ⅰ_2 are the best shale-gas enrichment modes, followed by Ⅱ_1 and Ⅱ_2. The least effective modes are Ⅲ_1 and Ⅲ_2. The categorization provides a different perspective for deep shale-gas exploration.
基金Project supported by the National Natural Science Foundation of China,“Comparative Study on Elements of Sweet Spots of Shale Oil and Shale Gas”(Grant No.41472123).
文摘Identification of sweet spot is of great significance in confirming shale gas prospects to realize large-scale economic shale gas development.In this paper,geological characteristics of shale gas reservoirs were compared and analyzed based on abundant data of domestic and foreign shale gas reservoirs.Key elements of sweet spots were illustrated,including net thickness of gas shale,total organic carbon(TOC)content,types and maturity(Ro)of organic matters,rock matrix and its physical properties(porosity and permeability),and development characteristics of natural fractures.After the data in Changning and Weiyuan blocks,the Sichuan Basin,were analyzed,the geologic laws of shale gas enrichment were summarized based on the economic exploitation characteristics of shale gas and the correlation between the elements.The elements of favorable“sweet spots”of marine shale gas reservoirs in the Changning block and their distribution characteristics were confirmed.Firstly,the quality of gas source rocks is ensured with the continuous thickness of effective gas shale larger than 30 m,TOC>2.0% and R_(o)=2.4-3.5%.Secondly,the quality of reservoir is ensured with the brittle minerals content being 30-69%,the clay mineral content lower than 30% and a single lamination thickness being 0.1-1.0 m.And thirdly,the porosity is higher than 2.0%,the permeability is larger than 50 nD,gas content is higher than 1.45 m^(3)/t,and formation is under normal pressure-overpressure system,which ensures the production modes and capacities.Finally,the primary and secondary elements that control the“sweet spots”of shale gas reservoirs were further analyzed and their restrictive relationships with each other were also discussed.
基金Project supported by the PetroChina's Key Special Petroleum S&T Project“PetroChina's Fourth Assessment of Oil&Gas Resources”(No.2013E-050207).
文摘During the progressive exploration of the Jingbian Gas Field in the Ordos Basin,multiple gas-bearing regions have been discovered in the dolomite reservoirs in the Middle Ordovician assemblages of Lower Paleozoic in Jingxi area,but these gas-bearing regions and intervals are significantly different in terms of gas enrichment degrees.So far,however,the reasons for the difference have not been figured out.In this paper,the origin and source of natural gas in the Middle Ordovician assemblages in Jingxi area was investigated on the basis of geochemical data(e.g.natural gas composition and carbon isotope),and then the main factors controlling the gas accumulation were analyzed.It is shown that the natural gas in the Middle Ordovician assemblages in the Middle Ordovician assemblages in Jingxi area is similar to that in the Upper Ordovician assemblages and Upper Paleozoic reservoir in terms of genesis and sources,and they are mainly the Upper Paleozoic coaliferous gas with some oil-derived gas.Under the influence of hydrocarbon generation center of coal source rocks and the source-rock-reservoir contact relationship,the proportion of coaliferous gas increases areally from the north to the south and vertically from Ma55 sub-member of the Lower Ordovician Majiagou Fm.It is concluded that the natural gas enrichment degree is controlled by the gas charging capacity at the hydrocarbon-supplying windows.Second,the vertical migration and distribution of natural gas is dominated by the differences of Ma_(5)^(5)-Ma_(5)^(10)transport pathways.And third,the lateral migration direction of natural gas and the range of gas accumulation are controlled by the superimposition relationship between structures and reservoirs.
基金Supported by National Natural Science Foundation of China and Enterprise Innovation and Development Joint Fund(U21B2062).
文摘The faults and associated fracture zones in the tight sandstone reservoirs of the fifth member of the Triassic Xujiahe Formation(Xu-5 Member)in the Wubaochang area,northeastern Sichuan Basin,play a critical role in controlling gas well productivity.To delineate the distribution patterns of the faults and associated fracture zones in this area,a transfer-trained convolutional neural network(CNN)model and an XGBoost(eXtreme Gradient Boosting)-based intelligent seismic attribute fusion method were employed to identify faults and fracture zones,respectively,enabling precise characterization of their spatial distribution.The faults in the Wubaochang area are classified into first-to fourth-order structures,with the average fracture zone width on the hanging wall exceeding that of the footwall,demonstrating a strong positive correlation between fracture zone width and fault displacement.The study area is divided into three distinct deformation regions(southern,central and northern regions)featuring five fault structural styles(duplex,duplex-backthrust,imbricate thrust,synclinorium imbricate-backthrust,and anticlinorium imbricate-backthrust)and four corresponding fracture zone development patterns(duplex,duplex-backthrust,synclinorium imbricate-backthrust,and anticlinorium imbricate-backthrust).Based on the controlling effects of faults on gas enrichment,the dual-source hydrocarbon-supply zones are interpreted to be distributed in the northern and central regions,while the southern region is identified as gas-escape zones.By integrating the distribution of favorable reservoir development areas and fracture zones,two classes of gas enrichment zones(Class Ⅰ and Ⅱ)are delineated.Class Ⅰ zones are primarily distributed in the northern region and the transitional zone from the southern to central regions,whereas Class Ⅱ zones are concentrated in the central region.Class Ⅰ zones exhibit dual-source hydrocarbon-supply conditions,larger-scale fracture zone development,and higher favorability compared to Class Ⅱ zones.According to the defined gas accumulation effectiveness in different types of fracture zones,a high-productivity gas well model for the Wubaochang area is proposed,emphasizing“dual-source faults controlling enrichment,effective fracture zones controlling high production,and high matrix porosity ensuring sustained production”.Targeted drilling directions for different favorable zones are further optimized based on this model.
基金funded by the Sinopec Science and Technology Project(No.P23132)the AAPG Foundation Grants-inAid Program(No.18644937)。
文摘By investigating the evolution of shale gas generation,storage,adjustment and accumulation under different structural settings in superimposed basins,this study elucidates the differential accumulation mechanisms of shale gas.An improved evaluation method of shale gas content evolution in superimposed basins is proposed.This method incorporates the coupling effect of key geological factors such as temperature,pressure,organic matter abundance,maturity,and pore characteristics on the content and occurrence state of shale gas,as well as the configuration relationship between shale gas generation and storage throughout geological history.Using this approach,the gas evolution histories of the Longmaxi Formation shales in wells N201 and PY1 are reconstructed under varying geological conditions.The Longmaxi Formation shales in these wells are dominated by typeⅠkerogen,with original total organic carbon(TOC_(o))contents of 6.20 wt% and 4.92 wt%,respectively,indicating differences in the initial material basis for gas generation.At the maximum burial depth of approximately 5000 m,the Longmaxi Formation shale in well N201 exhibits a formation pressure coefficient of 2.05,an organic matter maturity of 2.2%,and organic pores accounting for 68%of the total porosity.The gas generation quantity(Q_(g))reaches 19.24 m^(3)/t,while the gas storage capacity(Q_(s))is 4.30 m^(3)/t.The actual total gas content(Q_(a)),constrained by Q_(s),is 4.30 m^(3)/t,with free gas comprising 94%.Following relatively moderate tectonic uplift,the Q_(a) in well N201 decreases to 4.03 m^(3)/t,with free gas accounting for 63%.In contrast,the Longmaxi Formation shale in well PY1 reached a maximum burial depth of 6300 m,associated with a formation pressure coefficient of 1.62,organic matter maturity of 2.5%,and organic pore proportion of 67%.Here,Q_(g) is 16.87 m^(3)/t,and both Q_(s) and Q_(a) are 3.65 m^(3)/t,with free gas accounting for 98%.After intense tectonic uplift,Q_(a) declines to 2.72 m^(3)/t,and the proportion of free gas drops to51%.Finally,a four-stage differential accumulation model of shale gas is established:Slow gas generation and only adsorbed gas occur in stageⅠ,which is primarily controlled by TOC content;both adsorbed gas and free gas present in stageⅡ,with free gas becoming dominant;rapid gas generation and free gas predominance are controlled by temperature and porosity in stageⅢ;and gas adjustment and accumulation are primarily controlled by temperature and pressure in stageⅣ.
基金funded by the Technical Development(Entrusted)Project of Science and Department of SINOPEC(Grant No.P23240-4)the National Natural Science Foundation of China(Grant Nos.42172165,42272143 and 2025ZD1403901-05)。
文摘The Wufeng–Longmaxi Formation derives its name from the Upper Ordovician Wufeng Formation and the Lower Silurian Longmaxi Formation,found in sequence in the Sichuan Basin.This formation hosts rich shale gas reservoirs,and its shale gas enrichment patterns are examined in this study using data from 1197 shale samples collected from 14 wells.Five basic and three key parameters,eight in all,are assessed for each sample.The five basic parameters include burial depth and the contents of four mineral types—quartz,clay,carbonate,and other minerals;the three key parameters,representing shale gas enrichment,are total organic carbon(TOC)content,porosity,and gas content.The SHapley Additive exPlanations(SHAP)analysis originated in game theory is used here in an interpretable machine learning framework,to address issues of heterogeneous data structure,noisy relationships,and multi-objective optimization.An evaluation of the ranking,contribution values,and conditions of changes for these parameters offers new quantitative insights into shale gas enrichment patterns.A quantitative analysis of the relationship between data-sets identifies the primary factors controlling TOC,porosity,and gas content of shale gas reservoirs.The results show that TOC and porosity jointly influence gas content;mineral content has a significant impact on both,TOC and porosity;and the burial depth governs porosity which,in turn,affects the conditions under which shale gas is preserved.Input parameter thresholds are also determined and provide a basis for the establishment of quantitative criteria to evaluate shale gas enrichment.The predictive accuracy of the model used in this study is significantly improved by the step-wise addition of two input parameters,namely TOC and porosity,separately and together.Thus,the game theory method in big data-driven analysis uses a combination of TOC and porosity to evaluate the gas content with encouraging results—suggesting that these are the key parameters that indicate source rock and reservoir properties.
文摘Decarbonization of energy economy is nowadays a topical theme,and several pathways are under discussion.Gaseous fuels have a fundamental role for this transition,and the production of low carbon-impact fuels is necessary to deal with this challenge.The generation of renewable hydrogen is a trusted solution since this energy vector can be promptly produced from electricity and injected into the existing natural gas infrastructure,granting storage capacity and easy transportation.This scenario will lead,in the near future,to hydrogen enrichment of natural gas,whose impact on the infrastructures is being actively studied.The effect on end-user devices such as domestic gas boilers,instead,is still little analyzed and tested,but is fundamental to be assessed.The aim of this research is to generate knowledge on the effect of hydrogen enrichment on the widely used premixed boilers:the investigations include pollutant emissions,efficiency,flashback and explosion hazard,control system and materials selection.A model for calculating several parameters related to combustion of hydrogen enriched natural gas is presented.Guidelines for the design of new components are provided,and an insight is given on the maximum hydrogen blending bearable by the current boilers.
基金supported by the National Natural Science Foundation of China (42122017,41821002)the Hubei Provincial Natural Science Foundation of China (2020CFB501)+1 种基金the Shandong Provincial Key Research and Development Program (2020ZLYS08)the Independent innovation research program of China University of Petroleum (East China) (21CX06001A)。
文摘Tectonism is one of the dominant factors affecting the shale pore structure.However,the control of shale pore structure by tectonic movements is still controversial,which limits the research progress of shale gas accumulation mechanism in the complex tectonic region of southern China.In this study,34 samples were collected from two exploratory wells located in different tectonic locations.Diverse experiments,e.g.,organic geochemistry,XRD analysis,FE-SEM,low-pressure gas adsorption,and high-pressure mercury intrusion,were conducted to fully characterize the shale reservoir.The TOC,Ro,and mineral composition of the shale samples between the two wells are similar,which reflects that the shale samples of the two wells have proximate pores-generating capacity and pores-supporting capacity.However,the pore characteristics of shale samples from two wells are significantly different.Compared with the stabilized zone shale,the porosity,pore volume,and specific surface area of the deformed zone shale were reduced by 60.61%,64.85%,and 27.81%,respectively.Moreover,the macroscopic and fine pores were reduced by 54.01%and 84.95%,respectively.Fault activity and uplift denudation are not conducive to pore preservation,and the rigid basement of Huangling uplift can promote pore preservation.These three factors are important reasons for controlling the difference in pore structure between two wells shales.We established a conceptual model of shale pores evolution under different tectonic preservation conditions.This study is significant to clarify the scale of shale gas formation and enrichment in complex tectonic regions,and helps in the selection of shale sweet spots.
