Hydraulic fracturing is a crucial technique for efficient development of coal reservoirs.Coal rocks typically contain a high density of natural fractures,which serve as conduits for fracturing fluid.Upon injection,the...Hydraulic fracturing is a crucial technique for efficient development of coal reservoirs.Coal rocks typically contain a high density of natural fractures,which serve as conduits for fracturing fluid.Upon injection,the fluid infiltrates these natural fractures and leaks out,resulting in complex fracture morphology.The prediction of hydraulic fracture network propagation for coal reservoirs has important practical significance for evaluating hydraulic fracturing.This study proposes a novel inversion method for predicting fracture networks in coal reservoirs,explicitly considering the distribution of natural fractures.The method incorporates three distinct natural fracture opening modes and employs a fractal probability function to constrain fracture propagationmorphology.Based on thismethod,the study compares hydraulic fracture networkmorphologies in coal reservoirs with andwithout the presence of natural fractures.Theresults showthatwhile both reservoir types exhibitmulti-branch fracture networks,reservoirs containing natural fractures demonstrate greater branching and a larger stimulated reservoir volume(SRV).Additionally,the study employs a fractal dimension calculation method to quantitatively describe the geometric distribution characteristics of fractures.The analysis reveals that the geometry and distribution of natural fractures,as well as reservoir geological parameters,significantly influence the fracture networkmorphology and fractal dimension.The contact angle between natural and hydraulic fractures affects propagation direction;specifically,when the contact angle isπ/2,the fractal dimension of the hydraulic fracture network is maximized.Moreover,smaller lengths and spacings of natural fracture led to higher fractal dimensions,which can significantly increase the SRV.The proposed method offers an effective tool for evaluating the hydraulic fracturing of coal reservoirs.展开更多
Lacustrine shale oil reservoirs of the Upper Triassic Chang 7 Member in the Ordos Basin have demonstrated significant potential for hydrocarbon resources.Natural fractures play a crucial role in hydrocarbon enrichment...Lacustrine shale oil reservoirs of the Upper Triassic Chang 7 Member in the Ordos Basin have demonstrated significant potential for hydrocarbon resources.Natural fractures play a crucial role in hydrocarbon enrichment and production.Outcrops,cores,borehole image logs,thin sections,and FE-SEM images were used to investigate the types and characteristics of natural fractures in the Chang 7 Member.The factors controlling fracture development and the mechanisms of bedding-parallel fracture formation were revealed by integrating TOC analysis,XRD analysis,and rock pyrolysis.Results show that natural fractures in the study area include high-angle tectonic fractures and nearly horizontal bedding-parallel fractures.Brittle minerals and bed thickness control the occurrence and attributes of tectonic fractures.High TOC content and thermal maturity positively affect the development of bedding-parallel fractures,formed through the conversion of organic matter to hydrocarbons or the smectite-to-illite transformation.Additionally,the dominant orientations of tectonic fractures intersect the present-day maximum horizontal principal stress at a small angle,resulting in large apertures and good effectiveness.Bedding-parallel fractures contribute to enhance porosity and provide favorable pathways for lateral hydrocarbon migration.Collectively,this study could provide valuable insights for finding promising exploration areas in lacustrine shale oil reservoirs in the Ordos Basin and worldwide.展开更多
Natural fractures controlled by faults in ultradeep carbonate strata play substantial roles as both fluid migration channels and storage spaces.However,characterizing the heterogeneous distribution of underground frac...Natural fractures controlled by faults in ultradeep carbonate strata play substantial roles as both fluid migration channels and storage spaces.However,characterizing the heterogeneous distribution of underground fractures within the complex three-dimensional geometry of strike-slip fault zones remains challenging.This study investigates the characteristics of natural fractures controlled by strike-slip faults in the fractured Middle and Lower Ordovician reservoirs of the central and northern Tarim Basin,China.Seismics,cores,and image logs were integrated to quantitatively analyze the intensity and dip angle of natural fractures and findings were verified using published sandbox simulations.The carbonate reservoir contains three main types of natural fractures:tectonic fractures,abnormal high-pressure-related fractures,and stylolites.Strike-slip faults control the distribution and characteristics of tectonic fractures across various scales.Generally,both fracture intensity and porosity exhibit a decreasing trend as the distance from the main fault surface increases.Compared with those in non-stepover zones along a strike-slip fault,natural fractures and faults in stepover zones are more developed along the fault strike,with significantly greater development intensity in central stepover regions than that at its two ends.Furthermore,strike-slip faults influence the dip angles of both natural fractures and secondary faults.The proportion of medium-to-low-dip angle fractures and faults in the stepover zone is greater than that in the non-stepover zone.Additionally,the proportion of medium-to low-dip angle fractures and faults in the middle of the stepover is greater than that at both ends.Therefore,strike-slip fault structures control the dip angle of natural fracture and the heterogeneity of secondary fault and fracture intensity.The linking damage zone in the stepover contains a larger volume of fractured rocks,making it a promising petroleum exploration target.The development of stepovers and the orientation of present-day in-situ stress substantially influence the productivity of fractured reservoirs controlled by strike-slip faults.The analysis in this study reveals that reservoir productivity increases as the angle between the strike-slip fault segment and the maximum horizontal principal stress decreases.This study provides valuable insights for quantitatively evaluating fracture heterogeneity in fractured reservoirs and establishing optimized selection criteria for favorable targets in fault-related fractured reservoirs.展开更多
Strong tectonic activities and diagenetic evolution encourage the development of natural fractures as typical features in deep tight sandstone reservoirs of foreland thrust belts.This study focused on the Jurassic in ...Strong tectonic activities and diagenetic evolution encourage the development of natural fractures as typical features in deep tight sandstone reservoirs of foreland thrust belts.This study focused on the Jurassic in the southern Junggar Basin to comprehensively analyze the fracture characteristics and differential distribution and,ultimately,addressed the controlling mechanisms of tectonism and diagenesis on fracture effectiveness.Results revealed that the intensity of tectonic activities determines the complexity of tectonic fracture systems to create various fracture orientations when they have been stronger.The intense tectonic deformation would impact the stratum occurrence,which results in a wide range of fracture dip angles.Moreover,as the intensity of tectonic activities and deformations weakens,the scale and degree of tectonic fractures would decrease continuously.The control of tectonism on fracture effectiveness is reflected in the notable variations in the filling of multiple group fractures developed during different tectonic activity periods.Fractures formed in the early stages are more likely to be filled with minerals,causing their effectiveness to deteriorate significantly.Additionally,the strong cementation in the diagenetic evolution can cause more fractures to be filled with minerals and become barriers to fluid flow,which is detrimental to fracture effectiveness.However,dissolution is beneficial in improving their effectiveness by increasing fracture aperture and their connectivity to the pores.These insights can refine the development pattern of natural fractures and contribute to revealing the evolutionary mechanisms of fracture effectiveness in deep tight sandstone reservoirs of foreland thrust belts.展开更多
During the CO_(2)injection and geological storage process,the integrity of the cap rock significantly influences the long-term safety of CO_(2)storage.Natural fractures within the cap rock serve as potential pathways ...During the CO_(2)injection and geological storage process,the integrity of the cap rock significantly influences the long-term safety of CO_(2)storage.Natural fractures within the cap rock serve as potential pathways for CO_(2)migration,thereby increasing the risk of CO_(2)leakage.In this study,we determined the types,developmental characteristics,permeability changes,and CO_(2)-H_(2)O-Rock reactions of natural fractures in the mudstone cap rocks of the Sanduo Formation(E_(3)s)and Dainan Formation(E_(2)d)in the Gaoyou Sag of the Subei Basin using core observations,thin-section analysis,rock mechanics experiments,and paleomagnetic directional analysis.We identified four tectonic fracture sets(NNW,NWW,EW,and NE);high-angle shear fractures,ranging from 60°to 90°(average 82°)and typically measuring4-12 cm(average 7.5 cm),dominate the assemblage,while slip fractures,ranging from 32°to 50°(average 36°)and measuring 3-6 cm(average 3.9 cm),are also present.At the microscale,shear fractures average 160μm,and bedding fractures average 82μm.Notably,85.78%of shear fractures are unfilled,with calcite filling observed in 14.22%,while other fracture types show no filling.Permeability tests on samples without fractures reveal that permeability declines rapidly below 9 MPa,especially in shallower samples,followed by a slower reduction between 9 and 13 MPa,and ultimately stabilizes at approximately 0.00003 mD.In contrast,samples with fractures exhibit permeability that is 3-4 orders of magnitude higher;their fracture permeability decays according to a power law with pressure yet remains above 10 mD even at 46 MPa.Fractures with larger dip angles and those aligned with the maximum principal stress demonstrate the highest permeability.While silicate-filled fractures exhibit negligible changes in permeability,carbonate-filled fractu res experience a temporary enhancement due to dissolution;however,subsequent permeability remains controlled by factors such as effective stress and fracture orientation.展开更多
Natural fractures,as the main flow channels and important storage spaces,have significant effects on the migration,distribution,and accumulation of tight oil.According to outcrop,core,formation micro image(FMI),cast-t...Natural fractures,as the main flow channels and important storage spaces,have significant effects on the migration,distribution,and accumulation of tight oil.According to outcrop,core,formation micro image(FMI),cast-thin-section,and scanning electron microscopy data from the tight reservoir within the Permian Lucaogou Formation of the Junggar Basin,tectonic fractures are prevalent in this formation mainly on micro to large scale.There are two types of fractures worth noticing:diagenetic fractures and overpressure-related fractures,primarily at micro to medium scale.The diagenetic fractures consist of bedding fractures,stylolites,intragranular fractures,grain-boundary fractures,and diagenetic shrinkage fractures.Through FMI interpretation and Monte Carlo method evaluation,the macro-fractures could be considered as migration channels,and the micro-fractures as larger pore throats that function as storage spaces.The bedding fractures formed earlier than all tectonic fractures,while the overpressure-related fractures formed in the Middle and Late Jurassic.The bedding fractures and stylolites function as the primary channels for horizontal migration of tight oil.The tectonic fractures can provide vertical migration channels and reservoir spaces for tight oil,and readjust the tight oil distribution.The overpressure-related fractures are fully filled with calcite,and hence,have little effect on hydrocarbon migration and storage capacity.The data on tight oil production shows that the density and aperture of fractures jointly determine the productivity of a tight reservoir.展开更多
A review of the pressure transient analysis of flow in reservoirs having natural fractures,vugs and/or caves is presented to provide an insight into how much knowledge has been acquired about this phenomenon and to hi...A review of the pressure transient analysis of flow in reservoirs having natural fractures,vugs and/or caves is presented to provide an insight into how much knowledge has been acquired about this phenomenon and to highlight the gaps still open for further research.A comparison-based approach is adopted which involved the review of works by several authors and identifying the limiting assumptions,model restrictions and applicability.Pressure transient analysis provides information to aid the identification of important features of reservoirs.It also provides an explanation to complex reservoir pressuredependent variations which have led to improved understanding and optimization of the reservoir dynamics.Pressure transient analysis techniques,however,have limitations as not all its models find application in naturally fractured and vuggy reservoirs as the flow dynamics differ considerably.Pollard’s model presented in 1953 provided the foundation for existing pressure transient analysis in these types of reservoirs,and since then,several authors have modified this basic model and come up with more accurate models to characterize the dynamic pressure behavior in reservoirs with natural fractures,vugs and/or caves,with most having inherent limitations.This paper summarizes what has been done,what knowledge is considered established and the gaps left to be researched on.展开更多
Microseismic data shows that some unconventional reservoirs comprise well-developed natural fractures and complex hydraulic fracture networks.It is neither practical nor advantageous to simulate a huge number of natur...Microseismic data shows that some unconventional reservoirs comprise well-developed natural fractures and complex hydraulic fracture networks.It is neither practical nor advantageous to simulate a huge number of natural and hydraulic fractures with numerical models.Given that the conventional dual-porosity models are not applicable to the highly discrete natural fractures,the paper develops a semianalytical well testing model for horizontal wells with hydraulic fracture networks and randomly-distributed discretely natural fractures.The proposed model has the capability to analyze the pressure behaviors by considering complex fracture networks and isolated natural fractures rapidly and efficiently.The model includes diffusivity equations in three domains:(1)matrix,(2)discretely natural fractures,and(3)hydraulic fracture networks.The pressure transient solution of these diffusivity equations is obtained by using Laplace transforms and super-position principle.We verify the presented model by performing a case study with a numerical simulator for complex natural fractures.It is found that there are some interestingflow behaviors for fracture-network horizontal well with discretely natural fractures like bilinearflow,“V-shape”caused byfluid supply,pseudo boundary-dominatedflow,impact of natural fractures,etc.The pseudo boundary-dominatedflow provides us the information about how large the area covered by hydraulic fracture networks.The impact of natural fracture shows the pa-rameters of natural fractures.This work provides a good understanding of transient pressure behaviors in unconventional reservoirs and guidelines for the producer optimizefield development and well economics.展开更多
Natural fracture data from one of the Carboniferous shale masses in the eastern Qaidam Basin were used to establish a stochastic model of a discrete fracture network and to perform discrete element simulation research...Natural fracture data from one of the Carboniferous shale masses in the eastern Qaidam Basin were used to establish a stochastic model of a discrete fracture network and to perform discrete element simulation research on the size efect and mechanical parameters of shale.Analytical solutions of fctitious joints in transversely isotropic media were derived,which made it possible for the proposed numerical model to simulate the bedding and natural fractures in shale masses.The results indicate that there are two main factors infuencing the representative elementary volume(REV)size of a shale mass.The frst and most decisive factor is the presence of natural fractures in the block itself.The second is the anisotropy ratio:the greater the anisotropy is,the larger the REV.The bedding angle has little infuence on the REV size,whereas it has a certain infuence on the mechanical parameters of the rock mass.When the bedding angle approaches the average orientation of the natural fractures,the mechanical parameters of the shale blocks decrease greatly.The REV representing the mechanical properties of the Carboniferous shale masses in the eastern Qaidam Basin were comprehensively identifed by considering the infuence of bedding and natural fractures.When the numerical model size is larger than the REV,the fractured rock mass discontinuities can be transformed into equivalent continuities,which provides a method for simulating shale with natural fractures and bedding to analyze the stability of a borehole wall in shale.展开更多
HoekeBrown failure criterion is one of the widely used rock strength criteria in rock mechanics and mining engineering.Based on the theoretical expression of HoekeBrown parameter m of an intact rock,the parameter m ha...HoekeBrown failure criterion is one of the widely used rock strength criteria in rock mechanics and mining engineering.Based on the theoretical expression of HoekeBrown parameter m of an intact rock,the parameter m has been modified by crack parameters for fractured rocks.In this paper,the theoretical value range and theoretical expression form of the parameter m in HoekeBrown failure criterion were discussed.A critical crack parameter B was defined to describe the influence of the critical crack when the stress was at the peak,while a parameter b was introduced to represent the distribution of the average initial fractures.The parameter m of a fractured rock contained the influences of critical crack(B),confining pressure(s3)and initial fractures(b).Then the triaxial test on naturally fractured limestones was conducted to verify the modification of the parameter m.From the ultrasonic test and loading test results of limestones,the parameter m can be obtained,which indicated that the confining pressure at a high level reduced the differences of m among all the specimens.The confining pressure s3 had an exponential impact on m,while the critical crack parameter B had a negative correlation with m.Then the expression of m for a naturally fractured limestone was also proposed.展开更多
Hot dry rock(HDR)geothermal energy is a kind of widely distributed clean energy with huge reserves.However,its commercial development has been constrained by reservoir stimulation.In the early stage of HDR geothermal ...Hot dry rock(HDR)geothermal energy is a kind of widely distributed clean energy with huge reserves.However,its commercial development has been constrained by reservoir stimulation.In the early stage of HDR geothermal energy development,properly determining spatial distribution patterns of natural fractures in HDR reservoirs can effectively guide reservoir stimulation.This study analyzes the spatial distribution of natural fractures by using FracMan software based on the actual geological data and log data of well M-2 in the Matouying Uplift area,Hebei Province.The fracture parameters are counted and Monte Carlo simulation technique is introduced to optimize the parameters,which makes the natural fracture model more accurate and reliable.Furthermore,this study simulates hydraulic fracturing using the model combined with the actual in-situ stress parameters and the construction scheme.As verified by fitting the changes in simulated wellhead pressure during hydraulic fracturing with the actual wellhead pressure data detected during construction,the methods for natural fracture modeling used in this study are scientific and reasonable.The preliminary prediction results show that the displacement design scheme with a pump displacement of 2.0-3.0 m^(3)/min,4.0-5.5 m^(3)/min and 6-7 m^(3)/min in the early,middle and late stages,respectively,has good fracturing effect.The results of this study can be utilized as a reference for preparing development schemes for HDR reservoirs.展开更多
In order to provide technical support for the shale gas exploration and development in the Lower Silurian Longmaxi Formation of the Sichuan Basin,this paper takes the Longmaxi Formation in the Changning and Fuling Sha...In order to provide technical support for the shale gas exploration and development in the Lower Silurian Longmaxi Formation of the Sichuan Basin,this paper takes the Longmaxi Formation in the Changning and Fuling Shale Gas Fields as the research object to quantitatively characterize the development characteristics of natural fractures in the Longmaxi Formation shale by means of helium pycnometry,X-ray diffraction(XRD),true density testing and other methods,with the aid of the modified petrophysical model.Then,the development types and genetic mechanisms of natural fractures and their influences on shale gas development are discussed.The following research results are obtained.First,the modified petrophysical model can accurately describe the pore system in the Changning shale with a fitting rate of 0.74.Second,the development of natural fractures in shale is different in various regions.The natural fractures in the Changning Shale Gas Field,controlled by basement thrust faults,decollement layers and internal folds,are locally developed and filled with calcareous,and the average fracture porosity is 0.15%.In the Fuling Shale Gas Field,however,natural fractures,mainly controlled by reverse faults and slippage effect,are commonly more developed and unfilled or semi-filled with siliceous,and the average fracture porosity is 1.30%.Third,under the formation conditions,the opening of natural fractures is different.The natural fractures in the Changning Shale Gas Field are basically closed with weaker flowing ability,while those in the Fuling Shale Gas Field are relatively open with stronger flowing ability.Fourth,the occurrence mode of shale gas is influenced by natural fractures,and it is internally dominated by free gas.The initial gas production of shale gas wells is higher.In conclusion,(1)the regression coefficient is introduced to calculate the actual total organic matter content,which promotes the modified petrophysical model to describe matrix pores and fracture pores more accurately;(2)the development of natural fractures in the shale producing pay of the Sichuan Basin is relatively beneficial to shale gas enrichment and exploitation,but the flowing ability of the natural fractures will be weakened under the original formation conditions.展开更多
In this study,we use the extended finite element method(XFEM)with a consideration of junction enrichment functions to investigate the mechanics of hydraulic fractures related to naturally cemented fractures.In the pro...In this study,we use the extended finite element method(XFEM)with a consideration of junction enrichment functions to investigate the mechanics of hydraulic fractures related to naturally cemented fractures.In the proposed numerical model,the lubrication equation is adopted to describe the fluid flow within fractures.The fluid-solid coupling systems of the hydraulic fracturing problem are solved using the Newton-Raphson method.The energy release rate criterion is used to determine the cross/arrest behavior between a hydraulic fracture(HF)and a cemented natural fracture(NF).The failure patterns and mechanisms of crack propagation at the intersection of natural fractures are discussed.Simulation results show that after crossing an NF,the failure mode along the cemented NF path may change from the tensile regime to the shear or mixed-mode regime.When an advancing HF kinks back toward the matrix,the failure mode may gradually switch back to the tensile-dominated regime.Key factors,including the length of the upper/lower portion of the cemented NF,horizontal stress anisotropy,and the intersection angle of the crack propagation are investigated in detail.An uncemented or partially cemented NF will form a more complex fracture network than a cemented NF.This study provides insight into the formation mechanism of fracture networks in formations that contain cemented NF.展开更多
Unconventional reservoirs are generally characterized by low matrix porosity and permeability,in which natural fractures are important factors for gas production.In this study,we analyzed characteristics of natural fr...Unconventional reservoirs are generally characterized by low matrix porosity and permeability,in which natural fractures are important factors for gas production.In this study,we analyzed characteristics of natural fractures,and their influencing factors based on observations from outcrops,cores and image logs.The orientations of natural fractures were mainly in the∼N-S,WNW-ESE and NE-SW directions with relatively high fracture dip angles.Fracture densities were calculated based on fracture measurements within cores,indicating that natural fractures were not well-developed in the Benxi-Upper Shihezi Formations of Linxing Block.The majority of natural fractures were open fractures and unfilled.According to the characteristics of fracture sets and tectonic evolution of the study area,natural fractures in the Linxing Block were mainly formed in the Yanshanian and Himalayan periods.The lithology and layer thickness influenced the development of natural fractures,and more natural fractures were generated in carbonate rocks and thin layers in the study area.In addition,in the Linxing Block,natural fractures with∼N-S-trending strikes contributed little to the overall subsurface fluid flow under the present-day stress state.These study results provide a geological basis for gas exploration and development in the Linxing unconventional reservoirs of Ordos Basin.展开更多
Natural fractures are of crucial importance for oil and gas reservoirs,especially for those with ultralow permeability and porosity.The deep-marine shale gas reservoirs of the Wufeng and Longmaxi Formations are typica...Natural fractures are of crucial importance for oil and gas reservoirs,especially for those with ultralow permeability and porosity.The deep-marine shale gas reservoirs of the Wufeng and Longmaxi Formations are typical targets for the study of natural fracture characteristics.Detailed descriptions of full-diameter shale drill core,together with 3D Computed Tomography scans and Formation MicroScanner Image data acquisition,were carried out to characterize microfracture morphology in order to obtain the key parameters of natural fractures in such system.The fracture type,orientation,and their macroscopic and microscopic distribution features are evaluated.The results show that the natural fracture density appears to remarkably decrease in the Wufeng and Longmaxi Formations with increasing the burial depth.Similar trends have been observed for fracture length and aperture.Moreover,the natural fracture density diminishes as the formation thickness increases.There are three main types of natural fractures,which we interpret as(I)mineral-filled fractures(by pyrite and calcite),i.e.,veins,(II)those induced by tectonic stress,and(III)those formed by other processes(including diagenetic shrinkage and fluid overpressure).Natural fracture orientations estimated from the studied natural fractures in the Luzhou block are not consistent with the present-day stress field.The difference in tortuosity between horizontally and vertically oriented fractures reveals their morphological complexity.In addition,natural fracture density,host rock formation thickness,average total organic carbon and effective porosity are found to be important factors for evaluating shale gas reservoirs.The study also reveals that the high density of natural fractures is decisive to evaluate the shale gas potential.The results may have significant implications for evaluating favorable exploration areas of shale gas reservoirs and can be applied to optimize hydraulic fracturing for permeability enhancement.展开更多
Pre-existing natural fractures and other structurally weak planes are usually well-developed in unconventional reservoirs.When such fractures intersect with hydraulic induced fractures,they will redirect and propagate...Pre-existing natural fractures and other structurally weak planes are usually well-developed in unconventional reservoirs.When such fractures intersect with hydraulic induced fractures,they will redirect and propagate as an important mechanical principle of volume fracturing by the formation of complex fracture networks.Under the shadow effect of natural fractures and other structurally weak planes with hydraulic supported fracture stress,hydraulic fractures do not fully propagate in the direction of the maximum horizontal-principal-stress.This paper computed the stress intensity factors of hydraulic fracture types I and II by integrating the various interactions,established universally-applicable mechanical principles for the propagation behavior when a hydraulic fracture propagating in an arbitrary direction intersects with a natural fracture at an arbitrary angle,and demonstrated the mechanical principles of the intersection between hydraulic induced fractures and pre-existing natural fractures.This study proved the following conclusions:as the intersection angle between the hydraulic fracture and the maximum horizontal-principal-stress increased,the possibility of the hydraulic fracture being captured by the natural fracture with an identical approaching angle first increased and then decreased;as the net stress increased,the intersection behavior between the hydraulic fracture and the natural fracture transitioned from penetration to capture.展开更多
Fracking is one of the kernel technologies in the remarkable shale gas revolution. The extended finite element method is used in this paper to numerically investigate the interaction between hydraulic and natural frac...Fracking is one of the kernel technologies in the remarkable shale gas revolution. The extended finite element method is used in this paper to numerically investigate the interaction between hydraulic and natural fractures, which is an important issue of the enigmatic fracture network formation in fracking. The criteria which control the opening of natural fracture and crossing of hydraulic fracture are tentatively presented. Influence factors on the interaction process are systematically analyzed, which include the approach angle, anisotropy of in-situ stress and fluid pressure profile.展开更多
In the context of complex tectonic evolution,due to the control of tectonic compression stress and faults on tectonic fractures,the formation and development of tectonic fractures in the T_3x~2 tight reservoirs presen...In the context of complex tectonic evolution,due to the control of tectonic compression stress and faults on tectonic fractures,the formation and development of tectonic fractures in the T_3x~2 tight reservoirs present significant variations across different tectonic segments in the Western Sichuan Foreland Basin.We clarified the control of differential tectonic evolution on the formation and development of tectonic fractures in different tectonic segments through field-based observations,core samples,image logging,as well as fluid inclusion petrography and temperature determinations of fracture-filling materials,combined with 2D balanced cross-section restoration.The study area primarily manifests two types of tectonic fractures in the tight reservoirs:orogen-related fractures(regional fractures)and fault-related fractures.The orientations of these fractures are predominantly E-W,nearly N-S,NE,and NW.Specifically,the northern segment area only shows the development of regional fractures,while the southern and middle segments exhibit the development of both regional and tectonic fractures.There are three phases of tectonic fractures in different tectonic segments,and their formation times are relatively consistent.The Mesozoic tectonic events had a significant impact on the northern and central segments,with the amount of tectonic shortening and the rate of stratigraphic shortening gradually decreasing from the northeast to the southwest.The compressional stress resulting from tectonic compression also decreases from the northeast to the southwest.As a result,the development of first-phase and second-phase tectonic shear fractures is more pronounced in the northern and middle segments compared to the southern segment.Under the significant control of faults,the development of N-S-and NE-oriented fault-related fractures is more pronounced in the southern segment,while the development of NE-oriented fault-related fractures is relatively higher in the middle segment.Overall,there is an increased density of fractures and an increasing trend in fracture scale from the northern to the middle and then to the southern segment.展开更多
The presence of sealed or semi-sealed,multiscale natural fracture systems appears to be crucial for the successful stimulation of deep reservoirs.To explore the reaction of such systems to reservoir stimulation,a new ...The presence of sealed or semi-sealed,multiscale natural fracture systems appears to be crucial for the successful stimulation of deep reservoirs.To explore the reaction of such systems to reservoir stimulation,a new numerical simulation approach for hydraulic stimulation has been developed,trying to establish a realistic model of the physics involved.Our new model successfully reproduces dynamic fracture activation,network generation,and overall reservoir permeability enhancement.Its outputs indicate that natural fractures facilitate stimulation far beyond the near-wellbore area,and can significantly improve the hydraulic conductivity of unconventional geo-energy reservoirs.According to our model,the fracture activation patterns are jointly determined by the occurrence of natural fractures and the in situ stress.High-density natural fractures,high-fluid pressure,and low effective stress environments promote the formation of complex fracture networks during stimulation.Multistage or multicluster fracturing treatments with an appropriate spacing also increase the stimulated reservoir area(SRA).The simulation scheme demonstrated in this work offers the possibility to elucidate the complex multiphysical couplings seen in the field through detailed site-specific modeling.展开更多
Fracture network connectivity and aperture （or conductivity） distribution are two crucial features controlling flow behavior of naturally fractured reservoirs. The effect of connectivity on flow properties is well d...Fracture network connectivity and aperture （or conductivity） distribution are two crucial features controlling flow behavior of naturally fractured reservoirs. The effect of connectivity on flow properties is well documented. In this paper, however, we focus here on the influence of fracture aperture distribution. We model a two dimensional fractured reservoir in which the matrix is impermeable and the fractures are well connected. The fractures obey a power-law length distribution, as observed in natural fracture networks. For the aperture distribution, since the information from subsurface fracture networks is limited, we test a number of cases： log-normal distributions （from narrow to broad）, power-law distributions （from narrow to broad）, and one case where the aperture is pro- portional to the fracture length. We find that even a well- connected fracture network can behave like a much sparser network when the aperture distribution is broad enough （c~ 〈 2 for power-law aperture distributions and σ ≥ 0.4 for log-normal aperture distributions）. Specifically, most fractures can be eliminated leaving the remaining dominant sub-network with 90% of the permeability of the original fracture network. We determine how broad the aperture distribution must be to approach this behavior and the dependence of the dominant sub-network on the parameters of the aperture distribution. We also explore whether one can identify the dominant sub-network without doing flow calculations.展开更多
基金This study was supported by the Foundation of National Engineering Laboratory for Exploration and Development of Low-Permeability Oil and Gas Fields(2023-015).
文摘Hydraulic fracturing is a crucial technique for efficient development of coal reservoirs.Coal rocks typically contain a high density of natural fractures,which serve as conduits for fracturing fluid.Upon injection,the fluid infiltrates these natural fractures and leaks out,resulting in complex fracture morphology.The prediction of hydraulic fracture network propagation for coal reservoirs has important practical significance for evaluating hydraulic fracturing.This study proposes a novel inversion method for predicting fracture networks in coal reservoirs,explicitly considering the distribution of natural fractures.The method incorporates three distinct natural fracture opening modes and employs a fractal probability function to constrain fracture propagationmorphology.Based on thismethod,the study compares hydraulic fracture networkmorphologies in coal reservoirs with andwithout the presence of natural fractures.Theresults showthatwhile both reservoir types exhibitmulti-branch fracture networks,reservoirs containing natural fractures demonstrate greater branching and a larger stimulated reservoir volume(SRV).Additionally,the study employs a fractal dimension calculation method to quantitatively describe the geometric distribution characteristics of fractures.The analysis reveals that the geometry and distribution of natural fractures,as well as reservoir geological parameters,significantly influence the fracture networkmorphology and fractal dimension.The contact angle between natural and hydraulic fractures affects propagation direction;specifically,when the contact angle isπ/2,the fractal dimension of the hydraulic fracture network is maximized.Moreover,smaller lengths and spacings of natural fracture led to higher fractal dimensions,which can significantly increase the SRV.The proposed method offers an effective tool for evaluating the hydraulic fracturing of coal reservoirs.
基金supported by the National Natural Science Foundation of China(42090025,42302148)State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Effective Development(33550000-22-ZC0613-0336)CNPC Innovation Found(2023DQ02-0103)。
文摘Lacustrine shale oil reservoirs of the Upper Triassic Chang 7 Member in the Ordos Basin have demonstrated significant potential for hydrocarbon resources.Natural fractures play a crucial role in hydrocarbon enrichment and production.Outcrops,cores,borehole image logs,thin sections,and FE-SEM images were used to investigate the types and characteristics of natural fractures in the Chang 7 Member.The factors controlling fracture development and the mechanisms of bedding-parallel fracture formation were revealed by integrating TOC analysis,XRD analysis,and rock pyrolysis.Results show that natural fractures in the study area include high-angle tectonic fractures and nearly horizontal bedding-parallel fractures.Brittle minerals and bed thickness control the occurrence and attributes of tectonic fractures.High TOC content and thermal maturity positively affect the development of bedding-parallel fractures,formed through the conversion of organic matter to hydrocarbons or the smectite-to-illite transformation.Additionally,the dominant orientations of tectonic fractures intersect the present-day maximum horizontal principal stress at a small angle,resulting in large apertures and good effectiveness.Bedding-parallel fractures contribute to enhance porosity and provide favorable pathways for lateral hydrocarbon migration.Collectively,this study could provide valuable insights for finding promising exploration areas in lacustrine shale oil reservoirs in the Ordos Basin and worldwide.
基金supported by the National Natural Science Foundation of China(No.U21B2062)funding from the Chinese Scholarship Council(CSC)and the American Association of Petroleum Geologists Foundation Grantsin-Aid Program.
文摘Natural fractures controlled by faults in ultradeep carbonate strata play substantial roles as both fluid migration channels and storage spaces.However,characterizing the heterogeneous distribution of underground fractures within the complex three-dimensional geometry of strike-slip fault zones remains challenging.This study investigates the characteristics of natural fractures controlled by strike-slip faults in the fractured Middle and Lower Ordovician reservoirs of the central and northern Tarim Basin,China.Seismics,cores,and image logs were integrated to quantitatively analyze the intensity and dip angle of natural fractures and findings were verified using published sandbox simulations.The carbonate reservoir contains three main types of natural fractures:tectonic fractures,abnormal high-pressure-related fractures,and stylolites.Strike-slip faults control the distribution and characteristics of tectonic fractures across various scales.Generally,both fracture intensity and porosity exhibit a decreasing trend as the distance from the main fault surface increases.Compared with those in non-stepover zones along a strike-slip fault,natural fractures and faults in stepover zones are more developed along the fault strike,with significantly greater development intensity in central stepover regions than that at its two ends.Furthermore,strike-slip faults influence the dip angles of both natural fractures and secondary faults.The proportion of medium-to-low-dip angle fractures and faults in the stepover zone is greater than that in the non-stepover zone.Additionally,the proportion of medium-to low-dip angle fractures and faults in the middle of the stepover is greater than that at both ends.Therefore,strike-slip fault structures control the dip angle of natural fracture and the heterogeneity of secondary fault and fracture intensity.The linking damage zone in the stepover contains a larger volume of fractured rocks,making it a promising petroleum exploration target.The development of stepovers and the orientation of present-day in-situ stress substantially influence the productivity of fractured reservoirs controlled by strike-slip faults.The analysis in this study reveals that reservoir productivity increases as the angle between the strike-slip fault segment and the maximum horizontal principal stress decreases.This study provides valuable insights for quantitatively evaluating fracture heterogeneity in fractured reservoirs and establishing optimized selection criteria for favorable targets in fault-related fractured reservoirs.
基金supported by the CNPC Innovation Found(No.2023DQ02-0103)National Major Science and Technology Projects of China(No.2016ZX05003-001).
文摘Strong tectonic activities and diagenetic evolution encourage the development of natural fractures as typical features in deep tight sandstone reservoirs of foreland thrust belts.This study focused on the Jurassic in the southern Junggar Basin to comprehensively analyze the fracture characteristics and differential distribution and,ultimately,addressed the controlling mechanisms of tectonism and diagenesis on fracture effectiveness.Results revealed that the intensity of tectonic activities determines the complexity of tectonic fracture systems to create various fracture orientations when they have been stronger.The intense tectonic deformation would impact the stratum occurrence,which results in a wide range of fracture dip angles.Moreover,as the intensity of tectonic activities and deformations weakens,the scale and degree of tectonic fractures would decrease continuously.The control of tectonism on fracture effectiveness is reflected in the notable variations in the filling of multiple group fractures developed during different tectonic activity periods.Fractures formed in the early stages are more likely to be filled with minerals,causing their effectiveness to deteriorate significantly.Additionally,the strong cementation in the diagenetic evolution can cause more fractures to be filled with minerals and become barriers to fluid flow,which is detrimental to fracture effectiveness.However,dissolution is beneficial in improving their effectiveness by increasing fracture aperture and their connectivity to the pores.These insights can refine the development pattern of natural fractures and contribute to revealing the evolutionary mechanisms of fracture effectiveness in deep tight sandstone reservoirs of foreland thrust belts.
基金supported by the National Natural Science Foundation of China(Grant No.42402171)the China Postdoctoral Science Foundation(Grant No.2023MD744255)+6 种基金the Natural Science Basic Research Program of Shaanxi(Grant No.2024JC-YBQN-0353)the Scientific Research Program Funded by Shaanxi Provincial Education Department(No.23JK0600)the Shaanxi Postdoctoral Science Foundation(Grant No.2023B SHEDZZ324)the project of Theory of Hydrocarbon Enrichment under Multi-Spheric Interactions of the Earth(Grant No.THEMSIE04010107)the Key Research and Development Program of Shaanxi(Grant No.2021KW-10)the Innovation Capability Support Program of Shaanxi(Grant No.2022PT-08)the SINOPEC CCUS Fund Project(Grant No.33550000-22-ZC0613-0326)。
文摘During the CO_(2)injection and geological storage process,the integrity of the cap rock significantly influences the long-term safety of CO_(2)storage.Natural fractures within the cap rock serve as potential pathways for CO_(2)migration,thereby increasing the risk of CO_(2)leakage.In this study,we determined the types,developmental characteristics,permeability changes,and CO_(2)-H_(2)O-Rock reactions of natural fractures in the mudstone cap rocks of the Sanduo Formation(E_(3)s)and Dainan Formation(E_(2)d)in the Gaoyou Sag of the Subei Basin using core observations,thin-section analysis,rock mechanics experiments,and paleomagnetic directional analysis.We identified four tectonic fracture sets(NNW,NWW,EW,and NE);high-angle shear fractures,ranging from 60°to 90°(average 82°)and typically measuring4-12 cm(average 7.5 cm),dominate the assemblage,while slip fractures,ranging from 32°to 50°(average 36°)and measuring 3-6 cm(average 3.9 cm),are also present.At the microscale,shear fractures average 160μm,and bedding fractures average 82μm.Notably,85.78%of shear fractures are unfilled,with calcite filling observed in 14.22%,while other fracture types show no filling.Permeability tests on samples without fractures reveal that permeability declines rapidly below 9 MPa,especially in shallower samples,followed by a slower reduction between 9 and 13 MPa,and ultimately stabilizes at approximately 0.00003 mD.In contrast,samples with fractures exhibit permeability that is 3-4 orders of magnitude higher;their fracture permeability decays according to a power law with pressure yet remains above 10 mD even at 46 MPa.Fractures with larger dip angles and those aligned with the maximum principal stress demonstrate the highest permeability.While silicate-filled fractures exhibit negligible changes in permeability,carbonate-filled fractu res experience a temporary enhancement due to dissolution;however,subsequent permeability remains controlled by factors such as effective stress and fracture orientation.
基金supported by the National Science&Technology Major Project of China(No.2016ZX05003001).
文摘Natural fractures,as the main flow channels and important storage spaces,have significant effects on the migration,distribution,and accumulation of tight oil.According to outcrop,core,formation micro image(FMI),cast-thin-section,and scanning electron microscopy data from the tight reservoir within the Permian Lucaogou Formation of the Junggar Basin,tectonic fractures are prevalent in this formation mainly on micro to large scale.There are two types of fractures worth noticing:diagenetic fractures and overpressure-related fractures,primarily at micro to medium scale.The diagenetic fractures consist of bedding fractures,stylolites,intragranular fractures,grain-boundary fractures,and diagenetic shrinkage fractures.Through FMI interpretation and Monte Carlo method evaluation,the macro-fractures could be considered as migration channels,and the micro-fractures as larger pore throats that function as storage spaces.The bedding fractures formed earlier than all tectonic fractures,while the overpressure-related fractures formed in the Middle and Late Jurassic.The bedding fractures and stylolites function as the primary channels for horizontal migration of tight oil.The tectonic fractures can provide vertical migration channels and reservoir spaces for tight oil,and readjust the tight oil distribution.The overpressure-related fractures are fully filled with calcite,and hence,have little effect on hydrocarbon migration and storage capacity.The data on tight oil production shows that the density and aperture of fractures jointly determine the productivity of a tight reservoir.
基金the financial support received from the College of Petroleum Engineering and Geosciences at KFUPM through the project SF20006 toward the completion of this work。
文摘A review of the pressure transient analysis of flow in reservoirs having natural fractures,vugs and/or caves is presented to provide an insight into how much knowledge has been acquired about this phenomenon and to highlight the gaps still open for further research.A comparison-based approach is adopted which involved the review of works by several authors and identifying the limiting assumptions,model restrictions and applicability.Pressure transient analysis provides information to aid the identification of important features of reservoirs.It also provides an explanation to complex reservoir pressuredependent variations which have led to improved understanding and optimization of the reservoir dynamics.Pressure transient analysis techniques,however,have limitations as not all its models find application in naturally fractured and vuggy reservoirs as the flow dynamics differ considerably.Pollard’s model presented in 1953 provided the foundation for existing pressure transient analysis in these types of reservoirs,and since then,several authors have modified this basic model and come up with more accurate models to characterize the dynamic pressure behavior in reservoirs with natural fractures,vugs and/or caves,with most having inherent limitations.This paper summarizes what has been done,what knowledge is considered established and the gaps left to be researched on.
基金supported by National Key S&T Special Projects(2016ZX05047-004 and 2016ZX05030)National Natural Science Foundation of China(U1762210)+1 种基金Beijing Natural Science Foundation(3204052)Post-doctoral Program for Innovation Talents(BX20180380).
文摘Microseismic data shows that some unconventional reservoirs comprise well-developed natural fractures and complex hydraulic fracture networks.It is neither practical nor advantageous to simulate a huge number of natural and hydraulic fractures with numerical models.Given that the conventional dual-porosity models are not applicable to the highly discrete natural fractures,the paper develops a semianalytical well testing model for horizontal wells with hydraulic fracture networks and randomly-distributed discretely natural fractures.The proposed model has the capability to analyze the pressure behaviors by considering complex fracture networks and isolated natural fractures rapidly and efficiently.The model includes diffusivity equations in three domains:(1)matrix,(2)discretely natural fractures,and(3)hydraulic fracture networks.The pressure transient solution of these diffusivity equations is obtained by using Laplace transforms and super-position principle.We verify the presented model by performing a case study with a numerical simulator for complex natural fractures.It is found that there are some interestingflow behaviors for fracture-network horizontal well with discretely natural fractures like bilinearflow,“V-shape”caused byfluid supply,pseudo boundary-dominatedflow,impact of natural fractures,etc.The pseudo boundary-dominatedflow provides us the information about how large the area covered by hydraulic fracture networks.The impact of natural fracture shows the pa-rameters of natural fractures.This work provides a good understanding of transient pressure behaviors in unconventional reservoirs and guidelines for the producer optimizefield development and well economics.
基金support of the National Natural Science Foundation of China(51604275)the Key Laboratory of Urban Under Ground Engineering of Ministry of Education(TUE2018-01)+1 种基金Yue Qi Young Scholar Project of China University of Mining&Technology,Beijingthe Fundamental Research Funds for the Central Universities(2016QL02).
文摘Natural fracture data from one of the Carboniferous shale masses in the eastern Qaidam Basin were used to establish a stochastic model of a discrete fracture network and to perform discrete element simulation research on the size efect and mechanical parameters of shale.Analytical solutions of fctitious joints in transversely isotropic media were derived,which made it possible for the proposed numerical model to simulate the bedding and natural fractures in shale masses.The results indicate that there are two main factors infuencing the representative elementary volume(REV)size of a shale mass.The frst and most decisive factor is the presence of natural fractures in the block itself.The second is the anisotropy ratio:the greater the anisotropy is,the larger the REV.The bedding angle has little infuence on the REV size,whereas it has a certain infuence on the mechanical parameters of the rock mass.When the bedding angle approaches the average orientation of the natural fractures,the mechanical parameters of the shale blocks decrease greatly.The REV representing the mechanical properties of the Carboniferous shale masses in the eastern Qaidam Basin were comprehensively identifed by considering the infuence of bedding and natural fractures.When the numerical model size is larger than the REV,the fractured rock mass discontinuities can be transformed into equivalent continuities,which provides a method for simulating shale with natural fractures and bedding to analyze the stability of a borehole wall in shale.
基金financial support from Beijing Outstanding Young Scientist Program,China(Grant No.BJJWZYJH01201911413037)the National Natural Science Foundation of China(Grant No.41877257)Shaanxi Coal Group Key Project,China(Grant No.2018SMHKJ-A-J-03)。
文摘HoekeBrown failure criterion is one of the widely used rock strength criteria in rock mechanics and mining engineering.Based on the theoretical expression of HoekeBrown parameter m of an intact rock,the parameter m has been modified by crack parameters for fractured rocks.In this paper,the theoretical value range and theoretical expression form of the parameter m in HoekeBrown failure criterion were discussed.A critical crack parameter B was defined to describe the influence of the critical crack when the stress was at the peak,while a parameter b was introduced to represent the distribution of the average initial fractures.The parameter m of a fractured rock contained the influences of critical crack(B),confining pressure(s3)and initial fractures(b).Then the triaxial test on naturally fractured limestones was conducted to verify the modification of the parameter m.From the ultrasonic test and loading test results of limestones,the parameter m can be obtained,which indicated that the confining pressure at a high level reduced the differences of m among all the specimens.The confining pressure s3 had an exponential impact on m,while the critical crack parameter B had a negative correlation with m.Then the expression of m for a naturally fractured limestone was also proposed.
文摘Hot dry rock(HDR)geothermal energy is a kind of widely distributed clean energy with huge reserves.However,its commercial development has been constrained by reservoir stimulation.In the early stage of HDR geothermal energy development,properly determining spatial distribution patterns of natural fractures in HDR reservoirs can effectively guide reservoir stimulation.This study analyzes the spatial distribution of natural fractures by using FracMan software based on the actual geological data and log data of well M-2 in the Matouying Uplift area,Hebei Province.The fracture parameters are counted and Monte Carlo simulation technique is introduced to optimize the parameters,which makes the natural fracture model more accurate and reliable.Furthermore,this study simulates hydraulic fracturing using the model combined with the actual in-situ stress parameters and the construction scheme.As verified by fitting the changes in simulated wellhead pressure during hydraulic fracturing with the actual wellhead pressure data detected during construction,the methods for natural fracture modeling used in this study are scientific and reasonable.The preliminary prediction results show that the displacement design scheme with a pump displacement of 2.0-3.0 m^(3)/min,4.0-5.5 m^(3)/min and 6-7 m^(3)/min in the early,middle and late stages,respectively,has good fracturing effect.The results of this study can be utilized as a reference for preparing development schemes for HDR reservoirs.
基金Project supported by the National Major Science and Technology Project“Formation and Enrichment Conditions of Shale Gas in the Sichuan Basin and Its Surrounding Areas,Technologies for Selecting Regions,Evaluation and Applications”(No.:2017ZX05035)。
文摘In order to provide technical support for the shale gas exploration and development in the Lower Silurian Longmaxi Formation of the Sichuan Basin,this paper takes the Longmaxi Formation in the Changning and Fuling Shale Gas Fields as the research object to quantitatively characterize the development characteristics of natural fractures in the Longmaxi Formation shale by means of helium pycnometry,X-ray diffraction(XRD),true density testing and other methods,with the aid of the modified petrophysical model.Then,the development types and genetic mechanisms of natural fractures and their influences on shale gas development are discussed.The following research results are obtained.First,the modified petrophysical model can accurately describe the pore system in the Changning shale with a fitting rate of 0.74.Second,the development of natural fractures in shale is different in various regions.The natural fractures in the Changning Shale Gas Field,controlled by basement thrust faults,decollement layers and internal folds,are locally developed and filled with calcareous,and the average fracture porosity is 0.15%.In the Fuling Shale Gas Field,however,natural fractures,mainly controlled by reverse faults and slippage effect,are commonly more developed and unfilled or semi-filled with siliceous,and the average fracture porosity is 1.30%.Third,under the formation conditions,the opening of natural fractures is different.The natural fractures in the Changning Shale Gas Field are basically closed with weaker flowing ability,while those in the Fuling Shale Gas Field are relatively open with stronger flowing ability.Fourth,the occurrence mode of shale gas is influenced by natural fractures,and it is internally dominated by free gas.The initial gas production of shale gas wells is higher.In conclusion,(1)the regression coefficient is introduced to calculate the actual total organic matter content,which promotes the modified petrophysical model to describe matrix pores and fracture pores more accurately;(2)the development of natural fractures in the shale producing pay of the Sichuan Basin is relatively beneficial to shale gas enrichment and exploitation,but the flowing ability of the natural fractures will be weakened under the original formation conditions.
基金financially supported by the National Science Foundation of China(Grant Nos.51804033 and 51936001)Natural Science Foundation of Jiangsu Province(Grant No.BK20170457)+3 种基金Program of Great Wall Scholar(Grant No.CIT&TCD20180313)Jointly Projects of Beijing Natural Science FoundationBeijing Municipal Education Commission(Grant No.KZ201810017023)Beijing Youth Talent Support Program(CIT&TCD201804037).
文摘In this study,we use the extended finite element method(XFEM)with a consideration of junction enrichment functions to investigate the mechanics of hydraulic fractures related to naturally cemented fractures.In the proposed numerical model,the lubrication equation is adopted to describe the fluid flow within fractures.The fluid-solid coupling systems of the hydraulic fracturing problem are solved using the Newton-Raphson method.The energy release rate criterion is used to determine the cross/arrest behavior between a hydraulic fracture(HF)and a cemented natural fracture(NF).The failure patterns and mechanisms of crack propagation at the intersection of natural fractures are discussed.Simulation results show that after crossing an NF,the failure mode along the cemented NF path may change from the tensile regime to the shear or mixed-mode regime.When an advancing HF kinks back toward the matrix,the failure mode may gradually switch back to the tensile-dominated regime.Key factors,including the length of the upper/lower portion of the cemented NF,horizontal stress anisotropy,and the intersection angle of the crack propagation are investigated in detail.An uncemented or partially cemented NF will form a more complex fracture network than a cemented NF.This study provides insight into the formation mechanism of fracture networks in formations that contain cemented NF.
基金Many thanks to the financial support from National Natural Science Foundation of China(Grant Nos.41702130 and 41872171)National Science and Technology Major Project(2016ZX05066)Priority Academic Program Development of Jiangsu Higher Education Institutions(PAPD).
文摘Unconventional reservoirs are generally characterized by low matrix porosity and permeability,in which natural fractures are important factors for gas production.In this study,we analyzed characteristics of natural fractures,and their influencing factors based on observations from outcrops,cores and image logs.The orientations of natural fractures were mainly in the∼N-S,WNW-ESE and NE-SW directions with relatively high fracture dip angles.Fracture densities were calculated based on fracture measurements within cores,indicating that natural fractures were not well-developed in the Benxi-Upper Shihezi Formations of Linxing Block.The majority of natural fractures were open fractures and unfilled.According to the characteristics of fracture sets and tectonic evolution of the study area,natural fractures in the Linxing Block were mainly formed in the Yanshanian and Himalayan periods.The lithology and layer thickness influenced the development of natural fractures,and more natural fractures were generated in carbonate rocks and thin layers in the study area.In addition,in the Linxing Block,natural fractures with∼N-S-trending strikes contributed little to the overall subsurface fluid flow under the present-day stress state.These study results provide a geological basis for gas exploration and development in the Linxing unconventional reservoirs of Ordos Basin.
基金The project is funded by the National Natural Science Foundation of China(Grant No.42202155)China Postdoctoral Science Foundation(No.2021MD703807),Major Special Project of the Ministry of Science and Technology of PetroChina(Nos.2022DJ8004 and 2021DJ1901)+4 种基金Heilongjiang Postdoctoral Foundation(No.LBH-Z20121)Natural Science Foundation of Hubei Province Project(No.2020CFB501)The Scientific Research Project of Department of Natural Resources of Hubei Province(No.ZRZY2020KJ10)The authors gratefully acknowledge financial support from the China Scholarship Council(No.202008230018)EGR acknowledges funding by the Spanish Ministry of Science and Innovation(MCIN)/State Research Agency of Spain(AEI)/European Regional Development Fund(ERDF)/10.13039/501100011033 for the“Ramón y Cajal”fellowship RYC2018-026335-I and research projects PGC2018-093903-B-C22 and PID2020-118999GB-I00.
文摘Natural fractures are of crucial importance for oil and gas reservoirs,especially for those with ultralow permeability and porosity.The deep-marine shale gas reservoirs of the Wufeng and Longmaxi Formations are typical targets for the study of natural fracture characteristics.Detailed descriptions of full-diameter shale drill core,together with 3D Computed Tomography scans and Formation MicroScanner Image data acquisition,were carried out to characterize microfracture morphology in order to obtain the key parameters of natural fractures in such system.The fracture type,orientation,and their macroscopic and microscopic distribution features are evaluated.The results show that the natural fracture density appears to remarkably decrease in the Wufeng and Longmaxi Formations with increasing the burial depth.Similar trends have been observed for fracture length and aperture.Moreover,the natural fracture density diminishes as the formation thickness increases.There are three main types of natural fractures,which we interpret as(I)mineral-filled fractures(by pyrite and calcite),i.e.,veins,(II)those induced by tectonic stress,and(III)those formed by other processes(including diagenetic shrinkage and fluid overpressure).Natural fracture orientations estimated from the studied natural fractures in the Luzhou block are not consistent with the present-day stress field.The difference in tortuosity between horizontally and vertically oriented fractures reveals their morphological complexity.In addition,natural fracture density,host rock formation thickness,average total organic carbon and effective porosity are found to be important factors for evaluating shale gas reservoirs.The study also reveals that the high density of natural fractures is decisive to evaluate the shale gas potential.The results may have significant implications for evaluating favorable exploration areas of shale gas reservoirs and can be applied to optimize hydraulic fracturing for permeability enhancement.
基金Sponsored by National Science and Technology Major Projects(2016ZX05052,2016ZX05014).
文摘Pre-existing natural fractures and other structurally weak planes are usually well-developed in unconventional reservoirs.When such fractures intersect with hydraulic induced fractures,they will redirect and propagate as an important mechanical principle of volume fracturing by the formation of complex fracture networks.Under the shadow effect of natural fractures and other structurally weak planes with hydraulic supported fracture stress,hydraulic fractures do not fully propagate in the direction of the maximum horizontal-principal-stress.This paper computed the stress intensity factors of hydraulic fracture types I and II by integrating the various interactions,established universally-applicable mechanical principles for the propagation behavior when a hydraulic fracture propagating in an arbitrary direction intersects with a natural fracture at an arbitrary angle,and demonstrated the mechanical principles of the intersection between hydraulic induced fractures and pre-existing natural fractures.This study proved the following conclusions:as the intersection angle between the hydraulic fracture and the maximum horizontal-principal-stress increased,the possibility of the hydraulic fracture being captured by the natural fracture with an identical approaching angle first increased and then decreased;as the net stress increased,the intersection behavior between the hydraulic fracture and the natural fracture transitioned from penetration to capture.
基金supported by the National Natural Science Foundation of China (Grant No. 11372157)the Special Research Grant for Doctor Discipline by Ministry of Education of China (Grant No. 20120002110075)the Foundation for the Author of National Excellent Doctoral Dissertation of China (FANEDD) (Grant No. 201326)
文摘Fracking is one of the kernel technologies in the remarkable shale gas revolution. The extended finite element method is used in this paper to numerically investigate the interaction between hydraulic and natural fractures, which is an important issue of the enigmatic fracture network formation in fracking. The criteria which control the opening of natural fracture and crossing of hydraulic fracture are tentatively presented. Influence factors on the interaction process are systematically analyzed, which include the approach angle, anisotropy of in-situ stress and fluid pressure profile.
基金financially supported by the National Natural Science Foundation of China(No.42402171)the China Postdoctoral Science Foundation(No.2023MD744255)+6 种基金the Natural Science Basic Research Program of Shaanxi(No.2024JC-YBQN-0353)the Scientific Research Program Funded by Shaanxi Provincial Education Department(No.23JK0600)the Shaanxi Postdoctoral Science Foundation(No.2023BSHEDZZ324)the project of Theory of Hydrocarbon Enrichment under Multi-Spheric Interactions of the Earth(No.THEMSIE04010107)the Key Research and Development Program of Shaanxi(No.2021KW-10)the Innovation Capability Support Program of Shaanxi(No.2022PT-08)the SINOPEC CCUS Fund Project(No.33550000-22ZC0613-0326)。
文摘In the context of complex tectonic evolution,due to the control of tectonic compression stress and faults on tectonic fractures,the formation and development of tectonic fractures in the T_3x~2 tight reservoirs present significant variations across different tectonic segments in the Western Sichuan Foreland Basin.We clarified the control of differential tectonic evolution on the formation and development of tectonic fractures in different tectonic segments through field-based observations,core samples,image logging,as well as fluid inclusion petrography and temperature determinations of fracture-filling materials,combined with 2D balanced cross-section restoration.The study area primarily manifests two types of tectonic fractures in the tight reservoirs:orogen-related fractures(regional fractures)and fault-related fractures.The orientations of these fractures are predominantly E-W,nearly N-S,NE,and NW.Specifically,the northern segment area only shows the development of regional fractures,while the southern and middle segments exhibit the development of both regional and tectonic fractures.There are three phases of tectonic fractures in different tectonic segments,and their formation times are relatively consistent.The Mesozoic tectonic events had a significant impact on the northern and central segments,with the amount of tectonic shortening and the rate of stratigraphic shortening gradually decreasing from the northeast to the southwest.The compressional stress resulting from tectonic compression also decreases from the northeast to the southwest.As a result,the development of first-phase and second-phase tectonic shear fractures is more pronounced in the northern and middle segments compared to the southern segment.Under the significant control of faults,the development of N-S-and NE-oriented fault-related fractures is more pronounced in the southern segment,while the development of NE-oriented fault-related fractures is relatively higher in the middle segment.Overall,there is an increased density of fractures and an increasing trend in fracture scale from the northern to the middle and then to the southern segment.
基金This work was financially supported by the National Natural Science Foundation of China(Nos.U22A20166,51904190,12172230 and U19A2098)the Department of Science and Technology of Guangdong Province(No.2019ZT08G315)。
文摘The presence of sealed or semi-sealed,multiscale natural fracture systems appears to be crucial for the successful stimulation of deep reservoirs.To explore the reaction of such systems to reservoir stimulation,a new numerical simulation approach for hydraulic stimulation has been developed,trying to establish a realistic model of the physics involved.Our new model successfully reproduces dynamic fracture activation,network generation,and overall reservoir permeability enhancement.Its outputs indicate that natural fractures facilitate stimulation far beyond the near-wellbore area,and can significantly improve the hydraulic conductivity of unconventional geo-energy reservoirs.According to our model,the fracture activation patterns are jointly determined by the occurrence of natural fractures and the in situ stress.High-density natural fractures,high-fluid pressure,and low effective stress environments promote the formation of complex fracture networks during stimulation.Multistage or multicluster fracturing treatments with an appropriate spacing also increase the stimulated reservoir area(SRA).The simulation scheme demonstrated in this work offers the possibility to elucidate the complex multiphysical couplings seen in the field through detailed site-specific modeling.
文摘Fracture network connectivity and aperture （or conductivity） distribution are two crucial features controlling flow behavior of naturally fractured reservoirs. The effect of connectivity on flow properties is well documented. In this paper, however, we focus here on the influence of fracture aperture distribution. We model a two dimensional fractured reservoir in which the matrix is impermeable and the fractures are well connected. The fractures obey a power-law length distribution, as observed in natural fracture networks. For the aperture distribution, since the information from subsurface fracture networks is limited, we test a number of cases： log-normal distributions （from narrow to broad）, power-law distributions （from narrow to broad）, and one case where the aperture is pro- portional to the fracture length. We find that even a well- connected fracture network can behave like a much sparser network when the aperture distribution is broad enough （c~ 〈 2 for power-law aperture distributions and σ ≥ 0.4 for log-normal aperture distributions）. Specifically, most fractures can be eliminated leaving the remaining dominant sub-network with 90% of the permeability of the original fracture network. We determine how broad the aperture distribution must be to approach this behavior and the dependence of the dominant sub-network on the parameters of the aperture distribution. We also explore whether one can identify the dominant sub-network without doing flow calculations.
