Centering on the critical bottlenecks in the development of shale oil in the Jiyang Depression of Shengli Oilfield,key scientific and engineering issues are proposed in aspects such as the storage space and occurrence...Centering on the critical bottlenecks in the development of shale oil in the Jiyang Depression of Shengli Oilfield,key scientific and engineering issues are proposed in aspects such as the storage space and occurrence state of shale oil,the formation mechanisms of multi-scale flow spaces,the mobilization mechanisms of crude oil in pores and fractures,and the enhanced oil recovery(EOR)mechanisms during the late stage of elastic development.The research progress and mechanistic insights in recent years are reviewed with respect to experimental techniques,characteristics of pore-fracture structure and fluid occurrence,fracture evolution mechanisms,shale oil flow mechanisms and EOR techniques.Through improving the experimental methods,optimizing the testing conditions,and developing new technologies,we deeply understand the occurrence state,storage space and flow pattern of shale oil,and reveal the distribution pattern of“oil-bearing in all pore sizes and oil-rich in large pores”and the differences in fluid phase states under the confinement effect of nano-scale pores in the shales of the Jiyang Depression;depict the characteristics of“restricted vertical expansion and complex fracture networks”of induced fractures and the dynamic evolution of fracture networks during the fracturing-soaking-production process;establish a“easy flow-slow flow-stagnant flow”three-zone model and the elastic drive+imbibition drive synergistic energy replenishment mechanism;and carry out high-pressure injection to further enhance the mass transfer and diffusion capacity of CO_(2)within the shale pore-fracture system,and compete for the desorption of alkanes to improve the mobilization degree of shale oil.The research achievements provide crucial support for the formation of the theory of continental shale oil development and the construction of the technical system.The future research efforts will focus on mine-scale multi-field coupling physical simulation equipment,microscopic to macroscopic multi-scale experimental methods,pore/fracture fine characterization and post-fracturing core fracture description technologies,multi-media fluid-structure coupling numerical simulation algorithms,and low-cost EOR and low-quality shale oil in-situ upgrading technologies,in order to promote the large-scale and profitable development of shale oil in the Jiyang Depression.展开更多
The pore structure of shale oil reservoir significantly affects the occurrence and mobility of hydrocarbons.The potential of a new type of alkaline lake shale oil has been demonstrated,but there are few reports on the...The pore structure of shale oil reservoir significantly affects the occurrence and mobility of hydrocarbons.The potential of a new type of alkaline lake shale oil has been demonstrated,but there are few reports on the pore system of alkaline lake shale,which restricts the efficient exploration and development of shale oil.This study investigates the Fengcheng Formation shale in the Mahu sag of the Junggar Basin,employing methods such as low-temperature nitrogecn adsorption(LTNA),mercury intrusion capillary pressure(MICP),and nuclear magnetic resonance(NMR)to quantitatively characterize the multi-scale pore structure and fractal characteristics of shale,while evaluating the applicability of these methods.Based on a comprehensive analysis of material composition,different pore types,and fractal dimensions,the controlling factors for the development of different pore types and their seepage capacity are discussed.The results indicate that inorganic mineral pores are the main development in alkaline lake shale,with the pore morphology being characterized by slit-like and ink-bottle shapes.The multi-scale pore size distribution(PSD)shows that Ⅱ-micropores(10-100 nm)and mesopores(100–1000 nm)are the main contributors to the pore system.The development of Ⅱ-micropores is associated with feldspar and calcareous minerals,the development of Ⅰ-micropores(<10 nm)and mesopores is related to quartz content,while large pores are mainly found in interlayer fissures of clay minerals.The development of Ⅰ-micropores increases the roughness of pore surface and enhances the adsorption capacity of the pores,while the development of Ⅱ-micropores associated with calcareous minerals hinders pore seepage capacity.Mesopores and macropores(>1000 nm)exhibit good flowability.The high content of siliceous minerals plays a positive role in the pore system of alkaline lake shale.The shale with higher fractal dimension Dmin exhibits greater adsorption capacity,which hinders the accumulation of free-state shale oil.Different types of pore space play different roles in the occurrence of shale oil,with free-state shale oil primarily occurring in micro-fractures and inorganic mineral pores,and the pore size is exceeding 10 nm.展开更多
By reviewing the research progress and exploration practices of shale gas geology in China,analyzing and summarizing the geological characteristics,enrichment laws,and resource potential of different types of shale ga...By reviewing the research progress and exploration practices of shale gas geology in China,analyzing and summarizing the geological characteristics,enrichment laws,and resource potential of different types of shale gas,the following understandings have been obtained:(1)Marine,transitional,and lacustrine shales in China are distributed from old to new in geological age,and the complexity of tectonic reworking and hydrocarbon generation evolution processes gradually decreases.(2)The sedimentary environment controls the type of source-reservoir configuration,which is the basis of“hydrocarbon generation and reservoir formation”.The types of source-reservoir configuration in marine and lacustrine shales are mainly source-reservoir integration,with occasional source-reservoir separation.The configuration types of transitional shale are mainly source-reservoir integration and source-reservoir symbiosis.(3)The resistance of rigid minerals to compression for pore preservation and the overpressure facilitate the enrichment of source-reservoir integrated shale gas.Good source reservoir coupling and preservation conditions are crucial for the shale gas enrichment of source-reservoir symbiosis and source-reservoir separation types.(4)Marine shale remains the main battlefield for increasing shale gas reserves and production in China,while transitional and lacustrine shales are expected to become important replacement areas.It is recommended to carry out the shale gas exploration at three levels:Accelerate the exploration of Silurian,Cambrian,and Permian marine shales in the Upper-Middle Yangtze region;make key exploration breakthroughs in ultra-deep marine shales of the Upper-Middle Yangtze region,the new Ordovician marine shale strata in the North China region,the transitional shales of the Carboniferous and Permian,as well as the Mesozoic lacustrine shale gas in basins such as Sichuan,Ordos and Songliao;explore and prepare for new shale gas exploration areas such as South China and Northwest China,providing technology and resource reserves for the sustainable development of shale gas in China.展开更多
Taking the underground shale of the Silurian Longmaxi Formation in southern Sichuan Basin as the research object,stress-sensitive experiments on self-supporting fractures and micro-visualization experiments on gas-wat...Taking the underground shale of the Silurian Longmaxi Formation in southern Sichuan Basin as the research object,stress-sensitive experiments on self-supporting fractures and micro-visualization experiments on gas-water flow were conducted under simulated reservoir conditions to study the mechanism of microscopic gas-water flow during the fracture closure process and discuss its engineering applications.The results show that as the effective stress gradually increased from 5 MPa to 60 MPa with an increment of 5 MPa per step,the self-supporting fracture closure exhibited a two-stage characteristic of being fast in the early stage and slow in the later stage,with the inflection point stress ranging from 32 MPa to 35 MPa,and the closure degree of 47%-76%.The effective stress increase gradually rose from 5 MPa per step to 20 MPa per step,and the early fracture closure accelerated,with the maximum closure degree increasing by 8.6%.As the fracture width decreased from 500μm to 50μm,the gas-phase shifted from continuous to discontinuous flow,and the proportion of the critical gas-phase flow to maintain the continuous gas-phase flow increased.In the early stage of fracture closure(fracture width greater than 300μm),the continuous gas-phase flow is controlled by the fracture width-the larger the fracture width,the smaller the proportion of the critical gas-phase flow to maintain the continuous gas-phase flow.In the late stage of fracture closure(fracture width less than 300μm),as the fractures continue to close,the dominant role of the surface roughness of the fractures becomes stronger,and the proportion of the critical gas-phase flow to maintain the continuous gas-phase flow exceeds 70%.A reasonable pressure control during stable production and pressure reduction in the early stage(the peak pressure drop at the wellhead is less than 32 MPa)to delay the self-supporting fracture closure is conducive to the stable and increased production of gas wells.展开更多
A critical scientific gap exists in quantifying the intrinsic mechanisms of shale mechanical property degradation induced by the combined effects of perforation(impact)and acidization—two core techniques for shale re...A critical scientific gap exists in quantifying the intrinsic mechanisms of shale mechanical property degradation induced by the combined effects of perforation(impact)and acidization—two core techniques for shale reservoir permeability enhancement.To address this gap,this study proposed an innovative coupled experimental framework integrating dynamic-static cyclic loading(to simulate perforation impact)and acid erosion.Static uniaxial compression tests were performed on treated damaged shale samples,with microstructural characterization via X-ray diffraction(XRD)and scanning electron microscopy(SEM).Key findings include:(1)The damage factor(characterized by longitudinal wave velocity)showed a significant positive correlation with acid concentration;(2)Combined damage(impact+acidization)caused far more severe mechanical deterioration than single damage modes—for instance,samples under combined damage with 20%hydrochloric acid exhibited a strength reduction to 158.97 MPa,with sharp decreases in peak strength and elastic modulus;(3)Damage reduced total energy and elastic strain energy of samples while increasing dissipated energy proportion,leading to more developed internal fractures and severe failure in combined damage samples;(4)Acidization promoted sample fragmentation into smaller debris,resulting in significantly higher fractal dimensions of acidized shale than other damage types under the same acid concentration;(5)XRD and SEM analyses confirmed that high-concentration acid erosion reduced shale carbonate content,and the synergy of mechanical pre-damage and chemical dissolution in combined damage accelerated acid-rock reactions,significantly increasing micro-interfacial pores and degrading shale structural integrity.This study’s innovation lies in establishing a coupled experimental framework that reproduces the actual“perforation-acidization”sequence,quantitatively revealing the synergistic degradation mechanism of shale mechanical properties under combined damage—providing a novel theoretical basis for optimizing shale reservoir stimulation parameters.展开更多
To investigate the long-term fracture conductivity behavior of propped fractures under the high-temperature and high-pressure conditions of deep shale gas reservoirs in the Sichuan Basin,this study systematically anal...To investigate the long-term fracture conductivity behavior of propped fractures under the high-temperature and high-pressure conditions of deep shale gas reservoirs in the Sichuan Basin,this study systematically analyzed the effects of closure stress,proppant concentration,formation temperature,and proppant size combination.Conductivity experiments were conducted using the HXDL-2C long-term proppant conductivity evaluation system under simulated reservoir conditions to determine the time-dependent evolution of fracture conductivity.The results showed that the 50-h conductivity retention of the rock-plate experiments ranged from 22%to 28%.With increasing closure stress,fracture conductivity exhibited a rapid decline.Under a formation temperature of 120℃ and a proppant concentration of 5 kg·m^(-2),the short-term conductivity of 70/140 mesh quartz-sand-propped fractures was 2.37μm^(2)·cm,which decreased to 0.66μm^(2)·cm after long-term testing.When the closure stress increased to 80 MPa,the short-term and long-term conductivities further declined to 1.36μm^(2)·cm and 0.39μm^(2)·cm,respectively.Increasing the proppant concentration from 5 to 7.5 kg·m^(-2)at 120℃ and 80 MPa improved both short-term and long-term conductivities by enlarging the effective fracture width;however,the conductivity decay rate accelerated,and the 50-h retention dropped from 27.2%to 22.8%.Raising the temperature from 120℃ to 140℃ promoted proppant crushing and compaction,intensified shale creep,and accelerated fracture closure,reducing long-term conductivity from 0.37 to 0.30μm^(2)·cm.Under identical conditions,40/70 mesh ceramic proppants maintained significantly higher conductivities than 70/140 mesh quartz sand,with short-term and long-term values of 8.71 and 2.19μm^(2)·cm,respectively,at 120℃,80 MPa,and 5 kg·m^(-2).Pure quartz-sand systems failed to maintain effective conductivity under high-temperature and high-stress conditions,whereas adding 20%40/70 mesh ceramic proppant and thoroughly mixing it,the long-term conductivity has increased by 2.3 times,improving fracture stability while reducing overall cost.A predictive equation was derived from the experimental results to capture the dynamic decay characteristics of fracture conductivity.These outcomes provide a valuable experimental basis and technical support for optimizing fracturing fluid design,proppant selection,and operation parameters in deep shale formations.展开更多
The Liushagang Formation in the Weixinan Depression,Beibu Gulf Basin,southern China,is one of the key stratigraphic units for offshore shale oil exploration in the country.The shale oil reservoirs in the formation are...The Liushagang Formation in the Weixinan Depression,Beibu Gulf Basin,southern China,is one of the key stratigraphic units for offshore shale oil exploration in the country.The shale oil reservoirs in the formation are characterized by low porosity,low permeability and strong heterogeneity,which constrain the precise evaluation of reservoir properties,the accurate prediction of sweet spots,and efficient development.This study integrates core observation,mineralogical analysis,and multi-scale pore characterization to systematically clarify the variations in reservoir properties and their controlling mechanisms.The results show that the physical properties of matrix-type,lamina-type,and interlayer-type reservoirs exhibit distinct stepwise variations:Among these,interlayer-type reservoirs show the greatest development potential(quartz content 65%,average porosity 15%,permeability>10 mD,and mobile fluid saturation 60%),whereas matrix-type reservoirs are the least favorable(dominated by 40 nm nanoscale pores,and clay content 45%).Mineral composition,sedimentary-diagenetic processes,and fault systems collectively control reservoir property heterogeneity.Quartz-rich rigid frameworks resist compaction,resulting in a porosity increase by approximately 2% for every 10%rise in q uartz content.The transformation of clay minerals induces stratified porosity zoning within the layered reservoirs,while fault systems enhance heterogeneity through the development of fracture networks and acid-induced dissolution.This study provides theoretical support for the evaluation and development of shale oil sweet spots in the Weixinan Depression and holds practical significance for the commercial development of shale oil in China's offshore areas.展开更多
Previous studies have shown that the Eocene oil shale sequences in the Green River Basin contain long-period astronomical age information.The fine-scale chronological characteristics of the oil shale laminae remain la...Previous studies have shown that the Eocene oil shale sequences in the Green River Basin contain long-period astronomical age information.The fine-scale chronological characteristics of the oil shale laminae remain largely unexplored.We selected finely laminated oil shales formed in deep-water environments characterized by stable water column stratification as the primary focus of this study,using microscopy and micro-area X-ray fluorescence(μ-XRF)techniques.By integrating high-resolution elemental data with timeseries analysis,we identified significant periodic signals associated with solar activity(Hale and Schwabe cycles)and ENSO.The results indicate that the alternations of light and dark laminae in the Green River Formation oil shale correspond to alternating dry and wet climate regimes:the light laminae are dominated by carbonate minerals,reflecting drier and milder conditions,while the dark laminae are enriched in terrigenous clastics and organic matter,indicating periods of increased precipitation and warmer temperatures.The detected periodicities(23.5 years,13.3 years and 5.8 years)are highly consistent with modern observations,demonstrating that the lower Eocene Green River oil shale effectively records short-term solar activity and climate variability.Furthermore,our findings confirm that a persistent"permanent El Niño"state did not develop under Early Eocene greenhouse conditions,providing a refined chronological framework for highresolution paleoclimate studies during greenhouse intervals.展开更多
To quantify the acid corrosion characteristics and shear creep behavior of carbonaceous shale under acid corrosion,immersion tests and acid corrosion shear creep tests were conducted at different pH values.The shear f...To quantify the acid corrosion characteristics and shear creep behavior of carbonaceous shale under acid corrosion,immersion tests and acid corrosion shear creep tests were conducted at different pH values.The shear fracture surface characteristics of the damaged samples were observed using scanning electron microscopy(SEM).The mechanisms of acid corrosion and its shear creep effects on carbonaceous shale were elucidated.The results indicate that the higher the initial concentration of H+,the greater the wave velocity degradation rate and mass damage rate of the sample after acid etching reaction.The mass damage rate,wave velocity degradation rate of carbonaceous shale,and the pH of the solution first increased linearly and rapidly with time,followed by a nonlinear decrease,and finally reached a stable state.When the number of dry-wet cycles is constant,the higher the H+concentration,the greater the creep deformation,the longer the decelerating creep time,the higher the steady-state creep rate,and the lower the long-term strength.Acid corrosion induces mineral dissolution,increasing pore density.The products of acid corrosion reactions and clay minerals migrate and precipitate along paths influenced by dry-wet cycles,resulting in overall structural damage and decreased mechanical strength in carbonaceous shale.展开更多
The shale gas development in China faces challenges such as complex reservoir conditions and high development costs.Based on the pore pressure and geostress coupling theory,this paper studies the geostress evolution l...The shale gas development in China faces challenges such as complex reservoir conditions and high development costs.Based on the pore pressure and geostress coupling theory,this paper studies the geostress evolution laws and fracture network characteristics of shale gas infill wells.A mechanism model of CN platform logging data and geomechanical parameters is established to simulate the influence of parent well’s production on the geostress in the infill well area.It is suggested that with the increase of production time,normal fault stress state and horizontal stress deflection will occur.The smaller the parent well spacing and the longer the production time,the earlier the normal fault stress state appears and the larger the range.Based on the model,the fracture network morphology and construction parameters of infill wells are optimized.parentparentparentparent The results indicate that:1:A well spacing of 500 m achieves a Pareto optimum between“full reserve coverage”and“stress barrier”;2:A parent well recovery degree of 30%corresponds to the critical point of stress reversal,where the lateral deflection rate of the infill fracture is less than 8%and the SRV loss is minimized;3:6-cluster intensive completion with twice the liquid intensity increases the fracture complexity index by 1.7 times,enhances well group EUR by 15.4%,and reduces single-well cost by 22%.This research fills the theoretical gap in the collaborative optimization of“multi-parameter,multi-objective and multi-constraint”and provide parameter optimization basis for shale gas infill well development in China and help to improve the development efficiency and economic benefits.展开更多
The use of Al-V alloys as intermediate additives is pivotal for producing high-performance Ti alloys.Traditionally,the synthesis of these alloys relies on high-purity V_(2)O_(5),with sodium metavanadate as an essentia...The use of Al-V alloys as intermediate additives is pivotal for producing high-performance Ti alloys.Traditionally,the synthesis of these alloys relies on high-purity V_(2)O_(5),with sodium metavanadate as an essential intermediate in V_(2)O_(5)production.This study explores an alternative approach utilizing sodium metavanadate directly,offering an aluminothermic process to alleviate the environmental impact and reduce the time required for V_(2)O_(5)preparation.Al-V alloys are synthesized using sodium metavanadate derived from a shale V-rich solution,and the impurity-migration behaviors are comprehensively analyzed,specifically focusing on Fe,Al,and Na.The result sreveal that Al interacts with CaO to form a slag phase that is different from the alloy,whereas Na undergoes a sequence of reductions (NaVO_(3)→Na_(2)V_(2)O_(5)→NaVO_(2)→Na)and volatilizes at 25-1200℃,thereby avoiding incorporation into the alloy.Fe,reduced by Al,enriches the alloy phase and induces a phase transition(Al-V→Al-Fe→Fe-V)in the presence of excess Fe.Sodium metavanadate(Fe≤0.05wt%)derived from the shale V-rich solution enables the production of a uniform AlV65 alloy with 66.56wt%V,33.14wt%Al,0.08wt%Fe,0.07wt%C,0.02wt%N,and 0.12wt%O.These results establish a streamlined,efficient framework for the future preparation of Al-V alloys from shale V-rich solutions.展开更多
This paper systematically analyzes the reservoir-forming characteristics and cretaceous shale oil types in four major hydrocarbon-generating sags(Qingxi,Ying'er,Huahai,and Shida)of the Jiuquan Basin,based on the d...This paper systematically analyzes the reservoir-forming characteristics and cretaceous shale oil types in four major hydrocarbon-generating sags(Qingxi,Ying'er,Huahai,and Shida)of the Jiuquan Basin,based on the data of experiments for microscopic and geochemical analysis of reservoirs.The hydrothermal alteration-induced reservoir-forming model and its reservoir-controlling effect in the Qingxi Sag are discussed,and the exploration potential of shale oil in these four sags are evaluated.(1)The Qingxi Sag is widely developed with mud shale,dolomitic shale,and laminated argillaceous dolomite in the Cretaceous,which can be defined as mixed shale as a whole.The source rocks in this area are of good quality and high maturity,formed in a saline water sedimentary environment,and rich in dolomite,with a strong hydrocarbon generation capacity and excellent oil generation conditions.The reservoir space has been significantly modified by hydrothermal process,with well-developed dissolution pores and microfractures,recording favorable reservoir conditions for shale oil enrichment.Overall,this sag has large reservoir thickness and large resource volume,making it the most realistic shale oil exploration target in the Jiuquan Basin.However,it faces challenges such as great burial depth(deeper than 4500 m)and strong tectonic stress.(2)The Ying'er,Huahai,and Shida sags all feature sand-mud interbeds consisting of fan delta front thin sandbodies and lacustrine mud shale in the Cretaceous,having good source rock quality and favorable conditions for interbedded-type shale oil accumulation.The source rocks are insufficient in thermal evolution degree and unevenly distributed,and favorable shale oil resources are mainly endowed near the center of the sags.Reservoirs are primarily composed of siltstone to fine sandstone,suggesting relatively good reservoir conditions,generally with small burial depth(3000-4000 m)and the possibility of local sweet spots.It is noted that the Ying'er Sag has already produced low-mature to mature oil,qualifying it as a near-term realistic shale oil exploration area.展开更多
To clarify the thermal evolution characteristics of organic matter in the ZizhongWeiyuan area in Sichuan Basin,solid bitumen reflectance of the Lower Cambrian Qiongzhusi Formation(QFm)shale was measured by Raman Spect...To clarify the thermal evolution characteristics of organic matter in the ZizhongWeiyuan area in Sichuan Basin,solid bitumen reflectance of the Lower Cambrian Qiongzhusi Formation(QFm)shale was measured by Raman Spectroscopy(RS)method.Constrained by vitrinite reflectance(Ro)data,burial and thermal evolution histories of QFm shale were reconstructed through basin numerical simulation technology.The evolution model of and critical period of organic matter was determined,and its dominant drivers were analyzed.The results show that the asphalt Raman vitrinite reflectance(_(Rmc)Ro)ranges from 3.21%to 4.15%.Thermal maturity within the trough follows a southern part>central part>northern part trend.Thermal maturity is moderate within the paleo-uplift,whereas organic matter outside the paleo-uplift has undergone graphitization.Two types of thermal evolution imprints were established:a continuous heating type and a stop heating type of Silurian–Permian.Sedimentary burial,paleogeomorphology,tectonic movement and Emeishan mantle plume are the dominant drivers of multi-stage thermal imprints of the QFm shale.The three factors are coupled with each other.The Late Caledonian and Late Indosinian are the key periods of organic matter thermal evolution.The Leshan-Longnüsi paleo-uplift weakens the thermal effect of the Permian Emeishan mantle plume.The current thermal evolution pattern of the QFm is mainly determined by the continuous subsidence of the Triassic–Cretaceous.Stop heating model of Silurian–Permian locks the maturity of organic matter in the gold window,thus controlling the enrichment of QFm shale gas.It provides new insights for shale gas migration,enrichment and effective exploration and development of shale gas in the Lower Paleozoic QFm.展开更多
Characterization of mechanical alterations of shale constituent phases is critical for an in-depth understanding of the underlying mechanisms of shale softening.In this study,a hydro-thermal reaction system is set up ...Characterization of mechanical alterations of shale constituent phases is critical for an in-depth understanding of the underlying mechanisms of shale softening.In this study,a hydro-thermal reaction system is set up to mimic the interactions between shale and water-based fluids under the subsurface environment in shale formations.Using a coupled analysis of grid nanoindentation and in situ mineralogical identification,mechanical alterations of shale constituent mineral phases are revealed.Mechanical degradation of carbonate and clay phases is 10 times greater than quartz,pyrite and organic phases.The KCl additive greatly mitigates mechanical degradation of the clay phase.The high temperature and pressure results in a mechanical degradation of carbonate minerals as much as three times of that occurs at room temperature and atmospheric pressure.Multiscale mechanical models,which are established based on Mori-Tanaka(MT)and self-consistent(SC)schemes,predict more accurate elastic softening of shale composite than the microindentation experiments,due to the microcracks generated in the experiments.Based on the calculation of the multiscale mechanical model,under the subsurface environment of shale formations(e.g.80℃ and 8 MPa),the carbonate dissolution leads to a reduction in Young's modulus of shale composite by about 30%,while the degradation of clay minerals only causes a reduction by up to 9%.展开更多
Methane in-situ deflagration fracturing in shale is a revolutionary anhydrous technology.This paper selects shale samples from the Longmaxi Formation in Southern Sichuan to conduct deflagration fracturing tests with p...Methane in-situ deflagration fracturing in shale is a revolutionary anhydrous technology.This paper selects shale samples from the Longmaxi Formation in Southern Sichuan to conduct deflagration fracturing tests with pressures ranging from 25 MPa to 91 MPa.Pore structure changes were experimentally measured to explore the modification differences of nanoscale pore characteristics under varying deflagration pressures.The results show that within the deflagration pressure range examined in this study,(1)Deflagration fracturing can alter the pore volume and specific surface area but does not affect the distribution characteristics of the pore size's peak position.The maximum increments of total pore volume occur at a pressure of 45 MPa.(2)When the deflagration pressure is less than 45 MPa,porosity gradually increases with rising deflagration pressure.When it is greater than 45 MPa,the porosity does not change significantly.With increasing deflagration pressure,it gradually increases:from nanopores,such as mesopores and macropores,to large pores and microcracks.(3)At the low deflagration pressure stage,under the influence of high temperature,slippage pores gradually increase,which is conducive to gas desorption and diffusion migration.As pressure increases,the impact of the explosion shock wave gradually increases,the volume of seepage pores increases significantly,and seepage dominates the migration mode.展开更多
To clarify fluid flow mechanisms and establish effective development conditions in continental shale oil reservoirs,a high-temperature,high-pressure steady-state flow system integrated with nuclear magnetic resonance(...To clarify fluid flow mechanisms and establish effective development conditions in continental shale oil reservoirs,a high-temperature,high-pressure steady-state flow system integrated with nuclear magnetic resonance(NMR)technology has been developed.The apparatus combines sample evacuation,rapid pressurization and saturation,and controlled displacement,enabling systematic investigation of single-phase shale oil flow under representative reservoir conditions.Related experiments allow proper quantification of the activation thresholds and relative contributions of different pore types to flow.A movable fluid index(MFI),defined using dual T_(2) cutoff values,is introduced accordingly and linked to key flow parameters.The results reveal distinct multi-scale characteristics of single-phase shale oil transport,namely micro-scale graded displacement and macro-scale segmented nonlinear behavior.As the injection-production pressure difference increases,flow pathways are activated progressively,beginning with fractures,followed by large and then smaller macropores,leading to a pronounced enhancement in apparent permeability.Although mesopores and micropores contribute little to direct flow,their indirect influence becomes increasingly important,and apparent permeability gradually approaches a stable limit at higher pressure difference.It is also shown that the MFI exhibits a strong negative correlation with the starting pressure gradient and a positive correlation with apparent permeability,providing a rapid and reliable indicator of shale oil flow capacity.Samples containing through-going fractures display consistently higher MFI values and superior flowability compared with those dominated by laminated fractures,highlighting the pivotal role of well-connected fracture networks generated by large-scale hydraulic fracturing in improving shale oil production.展开更多
This paper proposes an approach to determing the optimal cluster spacing for volume fracturing in shale oil reservoirs based on three scales,i.e.microscopic capillary displacement,large-scale core imbibition,and macro...This paper proposes an approach to determing the optimal cluster spacing for volume fracturing in shale oil reservoirs based on three scales,i.e.microscopic capillary displacement,large-scale core imbibition,and macroscopic reservoir nuclear magnetic resonance(NMR)logging.Through flow experiments using capillary with different diameters and lengths,and large-scale core counter-current and dynamic imbibition tests,and combing with the NMR logging data of single wells,a graded optimization criterion for cluster spacing is established.The proposed approach was tested in the shale oil reservoir in the seventh member of the Triassic Yanchang Formation(Change 7 Member),the Ordos Basin.The following findings are obtained.First,in the Chang 7 reservoir,oil in pores smaller than 8μm requires a threshold pressure,and for 2-8μm pores,the movable drainage distance ranges from 0.7 m to 4.6 m under a pressure difference of 27 mPa.Second,the large-scale core imbibition tests show a counter-current imbibition distance of only 10 cm,but a dynamic imbibition distance up to 30 cm.Third,in-situ NMR logging results verified that the post-fracturing matrix drainage radius around fractures is 0-4 m,which is consistent with those of capillary flow experiments and large-scale core imbibition tests.The main pore-size range(2-8μm)of the Chang 7 reservoir corresponds to a permeability interval of(0.1-0.4)×10^(-3)μm^(2).Accordingly,a graded optimization criterion for cluster spacing is proposed as follows:for reservoirs with permeability less than 0.20×10^(-3)μm^(2),the cluster spacing should be reduced to smaller than 4.2 m;for reservoirs with permeability of(0.2-0.4)×10^(-3)μm^(2),the cluster spacing should be designed as 4.2-9.2 m.Field application on a pilot platform,where the cluster spacing was reduced to 4.0-6.0 m,yielded an increased initial oil production by approximately 36.6%over a 100-m horizontal reservoir section as compared with untested similar platforms.展开更多
In the Jimusaer Sag of the Junggar Basin,crude oils from the upper and lower sweet-spot intervals of the Permian Lucaogou Formation display a pronounced“light-heavy reversal”in oil properties that indicates a fundam...In the Jimusaer Sag of the Junggar Basin,crude oils from the upper and lower sweet-spot intervals of the Permian Lucaogou Formation display a pronounced“light-heavy reversal”in oil properties that indicates a fundamental mismatch between oil composition and host rock maturity.To resolve this anomaly,this study integrates geological,geochemical,and petrophysical datasets and systematically evaluates the combined roles of thermal evolution,organofacies,wettability,abnormal overpressure,and migration-related fractionation on shale oil composition.On this basis,a“staged charging-cumulative charging”model is proposed to explain compositional heterogeneity in lacustrine shale oils.The results demonstrate that crude-oil compositions are jointly controlled by the extent of biomarker depletion,the temporal evolution of hydrocarbon charging,and the openness of the source-reservoir system,rather than by thermal maturity or organofacies alone.The upper sweet-spot interval is interpreted to have functioned as a semi-open system during early stages,in which hydrocarbon generation and expulsion were broadly synchronous,leading to preferential loss of early-generated,biomarker-rich heavy components,whereas progressive shale diagenesis at later stages promoted the retention of highly mature,light hydrocarbons.In contrast,the lower sweet-spot interval represents a relatively closed system,where hydrocarbons generated during multiple stages continuously accumulated and were preserved as mixed charges;overprinting by multi-phase fluids progressively weakened sterane isomerization signals,rendering them unreliable indicators of individual charging events or final thermal maturity.This charging behavior provides a reasonable explanation for anomalously low or distorted biomarker parameters observed in intervals of low or similar maturity.Overall,the proposed charging model reconciles the observed reversal in crude-oil properties and,by shifting the interpretive focus from static maturity assessment to charging dynamics,offers a new theoretical basis for understanding lacustrine shale oil accumulation processes,and guiding sweet-spot selection and exploration-development strategies.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
基金Supported by the China National Science and Technology Major Project(2024ZD1405103)SINOPEC Science and Technology Major Project(P25184)。
文摘Centering on the critical bottlenecks in the development of shale oil in the Jiyang Depression of Shengli Oilfield,key scientific and engineering issues are proposed in aspects such as the storage space and occurrence state of shale oil,the formation mechanisms of multi-scale flow spaces,the mobilization mechanisms of crude oil in pores and fractures,and the enhanced oil recovery(EOR)mechanisms during the late stage of elastic development.The research progress and mechanistic insights in recent years are reviewed with respect to experimental techniques,characteristics of pore-fracture structure and fluid occurrence,fracture evolution mechanisms,shale oil flow mechanisms and EOR techniques.Through improving the experimental methods,optimizing the testing conditions,and developing new technologies,we deeply understand the occurrence state,storage space and flow pattern of shale oil,and reveal the distribution pattern of“oil-bearing in all pore sizes and oil-rich in large pores”and the differences in fluid phase states under the confinement effect of nano-scale pores in the shales of the Jiyang Depression;depict the characteristics of“restricted vertical expansion and complex fracture networks”of induced fractures and the dynamic evolution of fracture networks during the fracturing-soaking-production process;establish a“easy flow-slow flow-stagnant flow”three-zone model and the elastic drive+imbibition drive synergistic energy replenishment mechanism;and carry out high-pressure injection to further enhance the mass transfer and diffusion capacity of CO_(2)within the shale pore-fracture system,and compete for the desorption of alkanes to improve the mobilization degree of shale oil.The research achievements provide crucial support for the formation of the theory of continental shale oil development and the construction of the technical system.The future research efforts will focus on mine-scale multi-field coupling physical simulation equipment,microscopic to macroscopic multi-scale experimental methods,pore/fracture fine characterization and post-fracturing core fracture description technologies,multi-media fluid-structure coupling numerical simulation algorithms,and low-cost EOR and low-quality shale oil in-situ upgrading technologies,in order to promote the large-scale and profitable development of shale oil in the Jiyang Depression.
基金financially supported by the National Natural Science Foundation of China(Nos.42272137,42202160)AAPG Foundation Grants-in-Aid and the Strategic Cooperation Technology Projecti of CNPC and CUPB(No.ZLZX2020-01-05)。
文摘The pore structure of shale oil reservoir significantly affects the occurrence and mobility of hydrocarbons.The potential of a new type of alkaline lake shale oil has been demonstrated,but there are few reports on the pore system of alkaline lake shale,which restricts the efficient exploration and development of shale oil.This study investigates the Fengcheng Formation shale in the Mahu sag of the Junggar Basin,employing methods such as low-temperature nitrogecn adsorption(LTNA),mercury intrusion capillary pressure(MICP),and nuclear magnetic resonance(NMR)to quantitatively characterize the multi-scale pore structure and fractal characteristics of shale,while evaluating the applicability of these methods.Based on a comprehensive analysis of material composition,different pore types,and fractal dimensions,the controlling factors for the development of different pore types and their seepage capacity are discussed.The results indicate that inorganic mineral pores are the main development in alkaline lake shale,with the pore morphology being characterized by slit-like and ink-bottle shapes.The multi-scale pore size distribution(PSD)shows that Ⅱ-micropores(10-100 nm)and mesopores(100–1000 nm)are the main contributors to the pore system.The development of Ⅱ-micropores is associated with feldspar and calcareous minerals,the development of Ⅰ-micropores(<10 nm)and mesopores is related to quartz content,while large pores are mainly found in interlayer fissures of clay minerals.The development of Ⅰ-micropores increases the roughness of pore surface and enhances the adsorption capacity of the pores,while the development of Ⅱ-micropores associated with calcareous minerals hinders pore seepage capacity.Mesopores and macropores(>1000 nm)exhibit good flowability.The high content of siliceous minerals plays a positive role in the pore system of alkaline lake shale.The shale with higher fractal dimension Dmin exhibits greater adsorption capacity,which hinders the accumulation of free-state shale oil.Different types of pore space play different roles in the occurrence of shale oil,with free-state shale oil primarily occurring in micro-fractures and inorganic mineral pores,and the pore size is exceeding 10 nm.
基金Supported by the National Natural Science Foundation of China(42172165,42272143)Project of SINOPEC Science and Technology Department(P24181,KLP24017).
文摘By reviewing the research progress and exploration practices of shale gas geology in China,analyzing and summarizing the geological characteristics,enrichment laws,and resource potential of different types of shale gas,the following understandings have been obtained:(1)Marine,transitional,and lacustrine shales in China are distributed from old to new in geological age,and the complexity of tectonic reworking and hydrocarbon generation evolution processes gradually decreases.(2)The sedimentary environment controls the type of source-reservoir configuration,which is the basis of“hydrocarbon generation and reservoir formation”.The types of source-reservoir configuration in marine and lacustrine shales are mainly source-reservoir integration,with occasional source-reservoir separation.The configuration types of transitional shale are mainly source-reservoir integration and source-reservoir symbiosis.(3)The resistance of rigid minerals to compression for pore preservation and the overpressure facilitate the enrichment of source-reservoir integrated shale gas.Good source reservoir coupling and preservation conditions are crucial for the shale gas enrichment of source-reservoir symbiosis and source-reservoir separation types.(4)Marine shale remains the main battlefield for increasing shale gas reserves and production in China,while transitional and lacustrine shales are expected to become important replacement areas.It is recommended to carry out the shale gas exploration at three levels:Accelerate the exploration of Silurian,Cambrian,and Permian marine shales in the Upper-Middle Yangtze region;make key exploration breakthroughs in ultra-deep marine shales of the Upper-Middle Yangtze region,the new Ordovician marine shale strata in the North China region,the transitional shales of the Carboniferous and Permian,as well as the Mesozoic lacustrine shale gas in basins such as Sichuan,Ordos and Songliao;explore and prepare for new shale gas exploration areas such as South China and Northwest China,providing technology and resource reserves for the sustainable development of shale gas in China.
基金Supported by the National Science and Technology Major Project of New-Type Oil and Gas Exploration and Development(2025ZD14041)National Science and Technology Major Project of China(2025ZD14053)+2 种基金Science and Technology Project of CNPC(2023ZZ21)Youth Science and Technology Project of CNPC(2024DQ03241)Postdoctoral Research Project of PetroChina Southwest Oil and Gas Field Company(20230304-13)。
文摘Taking the underground shale of the Silurian Longmaxi Formation in southern Sichuan Basin as the research object,stress-sensitive experiments on self-supporting fractures and micro-visualization experiments on gas-water flow were conducted under simulated reservoir conditions to study the mechanism of microscopic gas-water flow during the fracture closure process and discuss its engineering applications.The results show that as the effective stress gradually increased from 5 MPa to 60 MPa with an increment of 5 MPa per step,the self-supporting fracture closure exhibited a two-stage characteristic of being fast in the early stage and slow in the later stage,with the inflection point stress ranging from 32 MPa to 35 MPa,and the closure degree of 47%-76%.The effective stress increase gradually rose from 5 MPa per step to 20 MPa per step,and the early fracture closure accelerated,with the maximum closure degree increasing by 8.6%.As the fracture width decreased from 500μm to 50μm,the gas-phase shifted from continuous to discontinuous flow,and the proportion of the critical gas-phase flow to maintain the continuous gas-phase flow increased.In the early stage of fracture closure(fracture width greater than 300μm),the continuous gas-phase flow is controlled by the fracture width-the larger the fracture width,the smaller the proportion of the critical gas-phase flow to maintain the continuous gas-phase flow.In the late stage of fracture closure(fracture width less than 300μm),as the fractures continue to close,the dominant role of the surface roughness of the fractures becomes stronger,and the proportion of the critical gas-phase flow to maintain the continuous gas-phase flow exceeds 70%.A reasonable pressure control during stable production and pressure reduction in the early stage(the peak pressure drop at the wellhead is less than 32 MPa)to delay the self-supporting fracture closure is conducive to the stable and increased production of gas wells.
基金funded by the National Natural Science Foundation of China(No.52474120)the National Key Research and Development Program of China—2023 Key Special Project(No.2023YFC2907400)+1 种基金the Fundamental Research Funds for the Central Universities(No.2023CXQD045)the Hunan Provincial Natural Science Foundation for Distinguished Young Scholars(No.2023JJ10072).
文摘A critical scientific gap exists in quantifying the intrinsic mechanisms of shale mechanical property degradation induced by the combined effects of perforation(impact)and acidization—two core techniques for shale reservoir permeability enhancement.To address this gap,this study proposed an innovative coupled experimental framework integrating dynamic-static cyclic loading(to simulate perforation impact)and acid erosion.Static uniaxial compression tests were performed on treated damaged shale samples,with microstructural characterization via X-ray diffraction(XRD)and scanning electron microscopy(SEM).Key findings include:(1)The damage factor(characterized by longitudinal wave velocity)showed a significant positive correlation with acid concentration;(2)Combined damage(impact+acidization)caused far more severe mechanical deterioration than single damage modes—for instance,samples under combined damage with 20%hydrochloric acid exhibited a strength reduction to 158.97 MPa,with sharp decreases in peak strength and elastic modulus;(3)Damage reduced total energy and elastic strain energy of samples while increasing dissipated energy proportion,leading to more developed internal fractures and severe failure in combined damage samples;(4)Acidization promoted sample fragmentation into smaller debris,resulting in significantly higher fractal dimensions of acidized shale than other damage types under the same acid concentration;(5)XRD and SEM analyses confirmed that high-concentration acid erosion reduced shale carbonate content,and the synergy of mechanical pre-damage and chemical dissolution in combined damage accelerated acid-rock reactions,significantly increasing micro-interfacial pores and degrading shale structural integrity.This study’s innovation lies in establishing a coupled experimental framework that reproduces the actual“perforation-acidization”sequence,quantitatively revealing the synergistic degradation mechanism of shale mechanical properties under combined damage—providing a novel theoretical basis for optimizing shale reservoir stimulation parameters.
基金funding for this research comes fromHubei Provincial Natural Science Foundation(2022CFB690)the Open Foundation(UOG2024-03)of Cooperative Innovation Center of Unconventional Oil+1 种基金Gas,Yangtze University(Ministry of Education&Hubei Province)and the Open Foundation(YQZC202302)of Hubei Key Laboratory of Oil and Gas Drilling and Production Engineering(Yangtze University)the National Natural Science Foundation of China(Grant no.U23B20156).
文摘To investigate the long-term fracture conductivity behavior of propped fractures under the high-temperature and high-pressure conditions of deep shale gas reservoirs in the Sichuan Basin,this study systematically analyzed the effects of closure stress,proppant concentration,formation temperature,and proppant size combination.Conductivity experiments were conducted using the HXDL-2C long-term proppant conductivity evaluation system under simulated reservoir conditions to determine the time-dependent evolution of fracture conductivity.The results showed that the 50-h conductivity retention of the rock-plate experiments ranged from 22%to 28%.With increasing closure stress,fracture conductivity exhibited a rapid decline.Under a formation temperature of 120℃ and a proppant concentration of 5 kg·m^(-2),the short-term conductivity of 70/140 mesh quartz-sand-propped fractures was 2.37μm^(2)·cm,which decreased to 0.66μm^(2)·cm after long-term testing.When the closure stress increased to 80 MPa,the short-term and long-term conductivities further declined to 1.36μm^(2)·cm and 0.39μm^(2)·cm,respectively.Increasing the proppant concentration from 5 to 7.5 kg·m^(-2)at 120℃ and 80 MPa improved both short-term and long-term conductivities by enlarging the effective fracture width;however,the conductivity decay rate accelerated,and the 50-h retention dropped from 27.2%to 22.8%.Raising the temperature from 120℃ to 140℃ promoted proppant crushing and compaction,intensified shale creep,and accelerated fracture closure,reducing long-term conductivity from 0.37 to 0.30μm^(2)·cm.Under identical conditions,40/70 mesh ceramic proppants maintained significantly higher conductivities than 70/140 mesh quartz sand,with short-term and long-term values of 8.71 and 2.19μm^(2)·cm,respectively,at 120℃,80 MPa,and 5 kg·m^(-2).Pure quartz-sand systems failed to maintain effective conductivity under high-temperature and high-stress conditions,whereas adding 20%40/70 mesh ceramic proppant and thoroughly mixing it,the long-term conductivity has increased by 2.3 times,improving fracture stability while reducing overall cost.A predictive equation was derived from the experimental results to capture the dynamic decay characteristics of fracture conductivity.These outcomes provide a valuable experimental basis and technical support for optimizing fracturing fluid design,proppant selection,and operation parameters in deep shale formations.
基金jointly supported by the National Natural Science Foundation of China(42474156)the Technical Service Project of China Oilfield Services Limited(YJB23YF001)。
文摘The Liushagang Formation in the Weixinan Depression,Beibu Gulf Basin,southern China,is one of the key stratigraphic units for offshore shale oil exploration in the country.The shale oil reservoirs in the formation are characterized by low porosity,low permeability and strong heterogeneity,which constrain the precise evaluation of reservoir properties,the accurate prediction of sweet spots,and efficient development.This study integrates core observation,mineralogical analysis,and multi-scale pore characterization to systematically clarify the variations in reservoir properties and their controlling mechanisms.The results show that the physical properties of matrix-type,lamina-type,and interlayer-type reservoirs exhibit distinct stepwise variations:Among these,interlayer-type reservoirs show the greatest development potential(quartz content 65%,average porosity 15%,permeability>10 mD,and mobile fluid saturation 60%),whereas matrix-type reservoirs are the least favorable(dominated by 40 nm nanoscale pores,and clay content 45%).Mineral composition,sedimentary-diagenetic processes,and fault systems collectively control reservoir property heterogeneity.Quartz-rich rigid frameworks resist compaction,resulting in a porosity increase by approximately 2% for every 10%rise in q uartz content.The transformation of clay minerals induces stratified porosity zoning within the layered reservoirs,while fault systems enhance heterogeneity through the development of fracture networks and acid-induced dissolution.This study provides theoretical support for the evaluation and development of shale oil sweet spots in the Weixinan Depression and holds practical significance for the commercial development of shale oil in China's offshore areas.
基金Supported by National Natural Science Foundation of China(Nos.42372125 and 41772092)。
文摘Previous studies have shown that the Eocene oil shale sequences in the Green River Basin contain long-period astronomical age information.The fine-scale chronological characteristics of the oil shale laminae remain largely unexplored.We selected finely laminated oil shales formed in deep-water environments characterized by stable water column stratification as the primary focus of this study,using microscopy and micro-area X-ray fluorescence(μ-XRF)techniques.By integrating high-resolution elemental data with timeseries analysis,we identified significant periodic signals associated with solar activity(Hale and Schwabe cycles)and ENSO.The results indicate that the alternations of light and dark laminae in the Green River Formation oil shale correspond to alternating dry and wet climate regimes:the light laminae are dominated by carbonate minerals,reflecting drier and milder conditions,while the dark laminae are enriched in terrigenous clastics and organic matter,indicating periods of increased precipitation and warmer temperatures.The detected periodicities(23.5 years,13.3 years and 5.8 years)are highly consistent with modern observations,demonstrating that the lower Eocene Green River oil shale effectively records short-term solar activity and climate variability.Furthermore,our findings confirm that a persistent"permanent El Niño"state did not develop under Early Eocene greenhouse conditions,providing a refined chronological framework for highresolution paleoclimate studies during greenhouse intervals.
基金supported by the National Natural Science Foundation of China(Grant Nos.42307252 and U1802243)the Technology Projects of WUST(Wuhan University of Science and Technology)Cultivate Innovation Teams(Grant No.2018TDX01).
文摘To quantify the acid corrosion characteristics and shear creep behavior of carbonaceous shale under acid corrosion,immersion tests and acid corrosion shear creep tests were conducted at different pH values.The shear fracture surface characteristics of the damaged samples were observed using scanning electron microscopy(SEM).The mechanisms of acid corrosion and its shear creep effects on carbonaceous shale were elucidated.The results indicate that the higher the initial concentration of H+,the greater the wave velocity degradation rate and mass damage rate of the sample after acid etching reaction.The mass damage rate,wave velocity degradation rate of carbonaceous shale,and the pH of the solution first increased linearly and rapidly with time,followed by a nonlinear decrease,and finally reached a stable state.When the number of dry-wet cycles is constant,the higher the H+concentration,the greater the creep deformation,the longer the decelerating creep time,the higher the steady-state creep rate,and the lower the long-term strength.Acid corrosion induces mineral dissolution,increasing pore density.The products of acid corrosion reactions and clay minerals migrate and precipitate along paths influenced by dry-wet cycles,resulting in overall structural damage and decreased mechanical strength in carbonaceous shale.
文摘The shale gas development in China faces challenges such as complex reservoir conditions and high development costs.Based on the pore pressure and geostress coupling theory,this paper studies the geostress evolution laws and fracture network characteristics of shale gas infill wells.A mechanism model of CN platform logging data and geomechanical parameters is established to simulate the influence of parent well’s production on the geostress in the infill well area.It is suggested that with the increase of production time,normal fault stress state and horizontal stress deflection will occur.The smaller the parent well spacing and the longer the production time,the earlier the normal fault stress state appears and the larger the range.Based on the model,the fracture network morphology and construction parameters of infill wells are optimized.parentparentparentparent The results indicate that:1:A well spacing of 500 m achieves a Pareto optimum between“full reserve coverage”and“stress barrier”;2:A parent well recovery degree of 30%corresponds to the critical point of stress reversal,where the lateral deflection rate of the infill fracture is less than 8%and the SRV loss is minimized;3:6-cluster intensive completion with twice the liquid intensity increases the fracture complexity index by 1.7 times,enhances well group EUR by 15.4%,and reduces single-well cost by 22%.This research fills the theoretical gap in the collaborative optimization of“multi-parameter,multi-objective and multi-constraint”and provide parameter optimization basis for shale gas infill well development in China and help to improve the development efficiency and economic benefits.
基金funded by the National Key R&D Pro-gram of China (No.2023YFC3903903)the Science and Technology Innovation Talent Program of Hubei Province,China (No.2022EJD002).
文摘The use of Al-V alloys as intermediate additives is pivotal for producing high-performance Ti alloys.Traditionally,the synthesis of these alloys relies on high-purity V_(2)O_(5),with sodium metavanadate as an essential intermediate in V_(2)O_(5)production.This study explores an alternative approach utilizing sodium metavanadate directly,offering an aluminothermic process to alleviate the environmental impact and reduce the time required for V_(2)O_(5)preparation.Al-V alloys are synthesized using sodium metavanadate derived from a shale V-rich solution,and the impurity-migration behaviors are comprehensively analyzed,specifically focusing on Fe,Al,and Na.The result sreveal that Al interacts with CaO to form a slag phase that is different from the alloy,whereas Na undergoes a sequence of reductions (NaVO_(3)→Na_(2)V_(2)O_(5)→NaVO_(2)→Na)and volatilizes at 25-1200℃,thereby avoiding incorporation into the alloy.Fe,reduced by Al,enriches the alloy phase and induces a phase transition(Al-V→Al-Fe→Fe-V)in the presence of excess Fe.Sodium metavanadate(Fe≤0.05wt%)derived from the shale V-rich solution enables the production of a uniform AlV65 alloy with 66.56wt%V,33.14wt%Al,0.08wt%Fe,0.07wt%C,0.02wt%N,and 0.12wt%O.These results establish a streamlined,efficient framework for the future preparation of Al-V alloys from shale V-rich solutions.
基金Supported by the CNPC Science and Technology Project(2023YQX10110)。
文摘This paper systematically analyzes the reservoir-forming characteristics and cretaceous shale oil types in four major hydrocarbon-generating sags(Qingxi,Ying'er,Huahai,and Shida)of the Jiuquan Basin,based on the data of experiments for microscopic and geochemical analysis of reservoirs.The hydrothermal alteration-induced reservoir-forming model and its reservoir-controlling effect in the Qingxi Sag are discussed,and the exploration potential of shale oil in these four sags are evaluated.(1)The Qingxi Sag is widely developed with mud shale,dolomitic shale,and laminated argillaceous dolomite in the Cretaceous,which can be defined as mixed shale as a whole.The source rocks in this area are of good quality and high maturity,formed in a saline water sedimentary environment,and rich in dolomite,with a strong hydrocarbon generation capacity and excellent oil generation conditions.The reservoir space has been significantly modified by hydrothermal process,with well-developed dissolution pores and microfractures,recording favorable reservoir conditions for shale oil enrichment.Overall,this sag has large reservoir thickness and large resource volume,making it the most realistic shale oil exploration target in the Jiuquan Basin.However,it faces challenges such as great burial depth(deeper than 4500 m)and strong tectonic stress.(2)The Ying'er,Huahai,and Shida sags all feature sand-mud interbeds consisting of fan delta front thin sandbodies and lacustrine mud shale in the Cretaceous,having good source rock quality and favorable conditions for interbedded-type shale oil accumulation.The source rocks are insufficient in thermal evolution degree and unevenly distributed,and favorable shale oil resources are mainly endowed near the center of the sags.Reservoirs are primarily composed of siltstone to fine sandstone,suggesting relatively good reservoir conditions,generally with small burial depth(3000-4000 m)and the possibility of local sweet spots.It is noted that the Ying'er Sag has already produced low-mature to mature oil,qualifying it as a near-term realistic shale oil exploration area.
基金funded by the Innovative Research Group Project of the National Natural Science Foundation of China(Nos.U24A20592 and 42272137)Guizhou Province Science and Technology Innovation Talent Team,Construction of the Science and Technology Innovation Talent Team for the Evaluation and Development of Unconventional Natural Gas Resources in Complex Structural Areas(No.Qian Ke He Platform Talent-CXTD[2023]013)。
文摘To clarify the thermal evolution characteristics of organic matter in the ZizhongWeiyuan area in Sichuan Basin,solid bitumen reflectance of the Lower Cambrian Qiongzhusi Formation(QFm)shale was measured by Raman Spectroscopy(RS)method.Constrained by vitrinite reflectance(Ro)data,burial and thermal evolution histories of QFm shale were reconstructed through basin numerical simulation technology.The evolution model of and critical period of organic matter was determined,and its dominant drivers were analyzed.The results show that the asphalt Raman vitrinite reflectance(_(Rmc)Ro)ranges from 3.21%to 4.15%.Thermal maturity within the trough follows a southern part>central part>northern part trend.Thermal maturity is moderate within the paleo-uplift,whereas organic matter outside the paleo-uplift has undergone graphitization.Two types of thermal evolution imprints were established:a continuous heating type and a stop heating type of Silurian–Permian.Sedimentary burial,paleogeomorphology,tectonic movement and Emeishan mantle plume are the dominant drivers of multi-stage thermal imprints of the QFm shale.The three factors are coupled with each other.The Late Caledonian and Late Indosinian are the key periods of organic matter thermal evolution.The Leshan-Longnüsi paleo-uplift weakens the thermal effect of the Permian Emeishan mantle plume.The current thermal evolution pattern of the QFm is mainly determined by the continuous subsidence of the Triassic–Cretaceous.Stop heating model of Silurian–Permian locks the maturity of organic matter in the gold window,thus controlling the enrichment of QFm shale gas.It provides new insights for shale gas migration,enrichment and effective exploration and development of shale gas in the Lower Paleozoic QFm.
基金funded by the Open Research Fund Programof State Key Laboratory of Hydroscience and Engineering(Project No.sklhse-2023-D-04)the National Natural Science Foundation of China(Project No.51979144).
文摘Characterization of mechanical alterations of shale constituent phases is critical for an in-depth understanding of the underlying mechanisms of shale softening.In this study,a hydro-thermal reaction system is set up to mimic the interactions between shale and water-based fluids under the subsurface environment in shale formations.Using a coupled analysis of grid nanoindentation and in situ mineralogical identification,mechanical alterations of shale constituent mineral phases are revealed.Mechanical degradation of carbonate and clay phases is 10 times greater than quartz,pyrite and organic phases.The KCl additive greatly mitigates mechanical degradation of the clay phase.The high temperature and pressure results in a mechanical degradation of carbonate minerals as much as three times of that occurs at room temperature and atmospheric pressure.Multiscale mechanical models,which are established based on Mori-Tanaka(MT)and self-consistent(SC)schemes,predict more accurate elastic softening of shale composite than the microindentation experiments,due to the microcracks generated in the experiments.Based on the calculation of the multiscale mechanical model,under the subsurface environment of shale formations(e.g.80℃ and 8 MPa),the carbonate dissolution leads to a reduction in Young's modulus of shale composite by about 30%,while the degradation of clay minerals only causes a reduction by up to 9%.
基金supported by the National Key Research and Development Program of China(Grant No.2020YFA0711800)the National Natural Science Foundation of China(Grant No.42372159).
文摘Methane in-situ deflagration fracturing in shale is a revolutionary anhydrous technology.This paper selects shale samples from the Longmaxi Formation in Southern Sichuan to conduct deflagration fracturing tests with pressures ranging from 25 MPa to 91 MPa.Pore structure changes were experimentally measured to explore the modification differences of nanoscale pore characteristics under varying deflagration pressures.The results show that within the deflagration pressure range examined in this study,(1)Deflagration fracturing can alter the pore volume and specific surface area but does not affect the distribution characteristics of the pore size's peak position.The maximum increments of total pore volume occur at a pressure of 45 MPa.(2)When the deflagration pressure is less than 45 MPa,porosity gradually increases with rising deflagration pressure.When it is greater than 45 MPa,the porosity does not change significantly.With increasing deflagration pressure,it gradually increases:from nanopores,such as mesopores and macropores,to large pores and microcracks.(3)At the low deflagration pressure stage,under the influence of high temperature,slippage pores gradually increase,which is conducive to gas desorption and diffusion migration.As pressure increases,the impact of the explosion shock wave gradually increases,the volume of seepage pores increases significantly,and seepage dominates the migration mode.
基金supported by the National Science and Technology Major Project of China(Grant No.2024ZD 1004302)the Key Scientific and Technological Research project of SINOPEC(Grant No.P25186).
文摘To clarify fluid flow mechanisms and establish effective development conditions in continental shale oil reservoirs,a high-temperature,high-pressure steady-state flow system integrated with nuclear magnetic resonance(NMR)technology has been developed.The apparatus combines sample evacuation,rapid pressurization and saturation,and controlled displacement,enabling systematic investigation of single-phase shale oil flow under representative reservoir conditions.Related experiments allow proper quantification of the activation thresholds and relative contributions of different pore types to flow.A movable fluid index(MFI),defined using dual T_(2) cutoff values,is introduced accordingly and linked to key flow parameters.The results reveal distinct multi-scale characteristics of single-phase shale oil transport,namely micro-scale graded displacement and macro-scale segmented nonlinear behavior.As the injection-production pressure difference increases,flow pathways are activated progressively,beginning with fractures,followed by large and then smaller macropores,leading to a pronounced enhancement in apparent permeability.Although mesopores and micropores contribute little to direct flow,their indirect influence becomes increasingly important,and apparent permeability gradually approaches a stable limit at higher pressure difference.It is also shown that the MFI exhibits a strong negative correlation with the starting pressure gradient and a positive correlation with apparent permeability,providing a rapid and reliable indicator of shale oil flow capacity.Samples containing through-going fractures display consistently higher MFI values and superior flowability compared with those dominated by laminated fractures,highlighting the pivotal role of well-connected fracture networks generated by large-scale hydraulic fracturing in improving shale oil production.
基金Supported by the China National Oil and Gas Major Project(2025ZD1404800)PetroChina Science and Technology Major Project(2023ZZ15YJ03)CNPC Changqing Oilfield Company Major Special Project(2023DZZ04)。
文摘This paper proposes an approach to determing the optimal cluster spacing for volume fracturing in shale oil reservoirs based on three scales,i.e.microscopic capillary displacement,large-scale core imbibition,and macroscopic reservoir nuclear magnetic resonance(NMR)logging.Through flow experiments using capillary with different diameters and lengths,and large-scale core counter-current and dynamic imbibition tests,and combing with the NMR logging data of single wells,a graded optimization criterion for cluster spacing is established.The proposed approach was tested in the shale oil reservoir in the seventh member of the Triassic Yanchang Formation(Change 7 Member),the Ordos Basin.The following findings are obtained.First,in the Chang 7 reservoir,oil in pores smaller than 8μm requires a threshold pressure,and for 2-8μm pores,the movable drainage distance ranges from 0.7 m to 4.6 m under a pressure difference of 27 mPa.Second,the large-scale core imbibition tests show a counter-current imbibition distance of only 10 cm,but a dynamic imbibition distance up to 30 cm.Third,in-situ NMR logging results verified that the post-fracturing matrix drainage radius around fractures is 0-4 m,which is consistent with those of capillary flow experiments and large-scale core imbibition tests.The main pore-size range(2-8μm)of the Chang 7 reservoir corresponds to a permeability interval of(0.1-0.4)×10^(-3)μm^(2).Accordingly,a graded optimization criterion for cluster spacing is proposed as follows:for reservoirs with permeability less than 0.20×10^(-3)μm^(2),the cluster spacing should be reduced to smaller than 4.2 m;for reservoirs with permeability of(0.2-0.4)×10^(-3)μm^(2),the cluster spacing should be designed as 4.2-9.2 m.Field application on a pilot platform,where the cluster spacing was reduced to 4.0-6.0 m,yielded an increased initial oil production by approximately 36.6%over a 100-m horizontal reservoir section as compared with untested similar platforms.
基金Supported by the National Natural Science Foundation of China(42173030,42302161,42473034)State Science and Technology Major Project for New Oil and Gas Exploration and Development,Ministry of Science and Technology(2025ZD1400803)。
文摘In the Jimusaer Sag of the Junggar Basin,crude oils from the upper and lower sweet-spot intervals of the Permian Lucaogou Formation display a pronounced“light-heavy reversal”in oil properties that indicates a fundamental mismatch between oil composition and host rock maturity.To resolve this anomaly,this study integrates geological,geochemical,and petrophysical datasets and systematically evaluates the combined roles of thermal evolution,organofacies,wettability,abnormal overpressure,and migration-related fractionation on shale oil composition.On this basis,a“staged charging-cumulative charging”model is proposed to explain compositional heterogeneity in lacustrine shale oils.The results demonstrate that crude-oil compositions are jointly controlled by the extent of biomarker depletion,the temporal evolution of hydrocarbon charging,and the openness of the source-reservoir system,rather than by thermal maturity or organofacies alone.The upper sweet-spot interval is interpreted to have functioned as a semi-open system during early stages,in which hydrocarbon generation and expulsion were broadly synchronous,leading to preferential loss of early-generated,biomarker-rich heavy components,whereas progressive shale diagenesis at later stages promoted the retention of highly mature,light hydrocarbons.In contrast,the lower sweet-spot interval represents a relatively closed system,where hydrocarbons generated during multiple stages continuously accumulated and were preserved as mixed charges;overprinting by multi-phase fluids progressively weakened sterane isomerization signals,rendering them unreliable indicators of individual charging events or final thermal maturity.This charging behavior provides a reasonable explanation for anomalously low or distorted biomarker parameters observed in intervals of low or similar maturity.Overall,the proposed charging model reconciles the observed reversal in crude-oil properties and,by shifting the interpretive focus from static maturity assessment to charging dynamics,offers a new theoretical basis for understanding lacustrine shale oil accumulation processes,and guiding sweet-spot selection and exploration-development strategies.
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.
