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
The tight sandstone reservoirs in the first sub-member of Chang 7 member(Chang 71)of Triassic Yanchang Formation in the Jiyuan area,Ordos Basin,show significant variations in microscopic pore-throat structure(PTS)and ...The tight sandstone reservoirs in the first sub-member of Chang 7 member(Chang 71)of Triassic Yanchang Formation in the Jiyuan area,Ordos Basin,show significant variations in microscopic pore-throat structure(PTS)and fluid mobility due to the influences of the northeast and northwest dual provenance systems.This study performed multiple experimental analyses on nine samples from the area to determine the petrological and petrophysical properties,as well as the PTS characteristics of reservoirs in different provenance-controlled regions.On this basis,the pore-throat size distribution(PSD)obtained from high-pressure mercury injection(HPMI)was utilized to convert the NMR movable fluid T2spectrum,allowing for quantitative characterization of the full PSD and the occurrence characteristics of movable fluids.A systematic analysis was conducted on the primary controlling factors affecting fluid mobility in the reservoir.The results indicated that the lithology in the eastern and western regions is lithic arkose.The eastern sandstones,being farther from the provenance,exhibit higher contents of feldspar and lithic fragments,along with the development of more dissolution pores.The reservoir possesses good petrophysical properties,low displacement pressure,and high pore-throat connectivity and homogeneity,indicating strong fluid mobility.In contrast,the western sandstones,being nearer to the provenance,exhibit poor grain sorting,high contents of lithic fragments,strong compaction and cementation effects,resulting in poor petrophysical properties,and strong pore-throat heterogeneity,revealing weak fluid mobility.The range of full PSD in the eastern reservoir is wider than that in the western reservoir,with relatively well-developed macropores.The macropores are the primary space for occurrence of movable fluids,and controls the fluid mobility of the reservoir.The effective porosity of movable fluids(EPMF)quantitatively represents the pore space occupied by movable fluids within the reservoir and correlates well with porosity,permeability,and PTS parameters,making it a valuable parameter for evaluating fluid mobility.Under the multi-provenance system,the eastern and western reservoirs underwent different sedimentation and diagenesis processes,resulting in differential distribution of reservoir mineral components and pore types,which in turn affects the PTS heterogeneity and reservoir quality.The composition and content of reservoir minerals are intrinsic factors influencing fluid mobility,while the microscopic PTS is the primary factor controlling it.Low clay mineral content,welldeveloped macropores,and weak pore-throat heterogeneity all contribute to the storage and seepage of reservoir fluids.展开更多
Due to the complex conditions and strong heterogeneity of tight sandstone reservoirs,the reservoirs should be classified and the controlling factors of physical properties should be studied.Cast thin section observati...Due to the complex conditions and strong heterogeneity of tight sandstone reservoirs,the reservoirs should be classified and the controlling factors of physical properties should be studied.Cast thin section observations,cathodoluminescence,scanning electron microscopy(SEM),X-ray diffraction(XRD),and high-pressure mercury injection(HPMI)were used to classify and optimize the reservoir.The Brooks-Corey model and stepwise regression were used to study the fractal dimension and main controlling factors of the physical properties of the high-quality reservoir.The results show that the reservoirs in the study area can be divided into four types,and the high-quality reservoir has the best physical properties and pore-throat characteristics.In the high-quality reservoir,the homogeneity of transitional pores was the best,followed by that of micropores,and the worst was mesopores.The porosity was controlled by depth and kaolinite.The model with standardized coefficients is y=12.454−0.778×(Depth)+0.395×(Kaolinite).The permeability was controlled by depth,illite/montmorillonite,and siliceous cement,and the model with standardized coefficients is y=1.689−0.683×(Depth)−0.395×(Illite/Montmorillonite)−0.337×(Siliceous Cement).The pore-throat evolutionary model shows that the early-middle diagenetic period was when the reservoir physical properties were at their best,and the kaolinite intercrystalline pores and residual intergranular pores were the most important.展开更多
Tight sandstone gas reservoirs have poorer porosityepermeability relationships,so conventional reservoir classification schemes can hardly satisfy the classification and evaluation demand of this type of reservoirs.To...Tight sandstone gas reservoirs have poorer porosityepermeability relationships,so conventional reservoir classification schemes can hardly satisfy the classification and evaluation demand of this type of reservoirs.To solve this problem,this paper took the Permian tight sandstone gas reservoir in the Linxing Block along the eastern margin of the Ordos Basin as an example to describe the micro-structures of the tight sandstone reservoirs by means of high-pressure mercury injection,nuclear magnetic resonance(NMR),scanning electron mi-croscope(SEM)and so on.Then,the control effect of micro-structure parameters on the macrophysical properties was studied.Finally,classification and evaluation of tight sandstone reservoirs were carried out on this basis.And the following research results were obtained.First,NMR can identify the distribution of pores of different sizes,and high-pressure mercury injection can reflect the poreethroat configuration and percolation capacity of a reservoir.Second,both methods are better coincident in the description results.With an in-crease of the right peak of T2 spectra,the mercury intrusion curve presents a concave shape and the pore throat radius increases while the pore type gradually changes from intragranular dissolution pores and intercrystalline pores to intergranular pores and intergranular disso-lution pores and the reservoir quality gets better.Third,micro-pore structure controls reservoir physical properties andfluid mobility.And the porosity of large pores is best correlated with the effective porosity,so it can be used to evaluate the reservoir capacity of tight sandstone.Fourth,the throat radius R15 obtained by high pressure mercury injection is in the best correlation with porosity and permeability,so it can be used to evaluate the percolation capacity of tight sandstone.Fifth,by combining the porosity of large pores with the R15,the tight sandstone reservoirs in the Linxing Block are classified into 4 categories,and the classification results are in a good agreement with the on-site well test data.It is concluded that the combination of high-pressure mercury injection and NMR can effectively identify the key parameters which reflect the reservoir capacity and percolation capacity of tight sandstone,and improve the reliability and integrity of reservoir classification.And by selecting the key parameters that reflect reservoir capacity and percolation capacity,it can provide guidance for the classification and evaluation of tight sandstone reservoirs.展开更多
By using core,logging curves,and experiment data,favorable lithofacies types in the 2 nd Member of Triassic Xujiahe Formation in the Xinchang area,Sichuan Basin were classified,standard of the favorable lithofacies wa...By using core,logging curves,and experiment data,favorable lithofacies types in the 2 nd Member of Triassic Xujiahe Formation in the Xinchang area,Sichuan Basin were classified,standard of the favorable lithofacies was established,planar distribution regularities of the favorable lithofacies were identified,and forming mechanisms of the favorable lithofacies and their control effect on production were examined.(1)The 2 nd Member of Xujiahe Formation has twelve types of lithofacies,among which multiple layer medium-coarse grain sandstone lithofacies,parallel bedding medium-coarse grain sandstone lithofacies,massive bedding medium-coarse grain sandstone lithofacies,inclined bedding medium-coarse grain sandstone lithofacies,and charcoal-bearing medium-coarse grain sandstone lithofacies with better physical properties and higher gas content are favorable lithofacies;they feature low gamma,low neutron porosity,low resistivity,and high acoustic travel time on logging curves.(2)The sedimentary process controls spatial distribution of sand bodies which are the material basis of the favorable lithofacies;post diagenetic fluids would differentially reconstruct the favorable lithofacies;tectonic activities and abnormal formation pressure made strata slide along the weakness plane,giving rise to fractures in different types of rocks,which can enhance the reservoir permeability significantly.(3)The development degree of favorable lithofacies is a major factor affecting stable production of gas well.展开更多
Accurate prediction of reservoir parameters is essential for reservoir evaluation.Recent machine learning methods have spurred significant advancements in reservoir prediction;however,limited well logging data and str...Accurate prediction of reservoir parameters is essential for reservoir evaluation.Recent machine learning methods have spurred significant advancements in reservoir prediction;however,limited well logging data and strong reservoir heterogeneity still hinder the accuracy and reliability of such predictions.Addressing these challenges requires methods capable of effectively predicting reservoir parameters under data scarcity and complex reservoir structures.In this study,we propose CAF2,a feature-fusion cross-modal alignment framework guided by large language models(LLMs).CAF2 integrates data augmentation,knowledge distillation,cross-modal alignment,and feature fusion.The data augmentation module employs the RealTabFormer model to generate synthetic datasets that mirror the distribution of real logging data,addressing the challenge of data scarcity.Knowledge distillation extracts essential domain knowledge from LLMs,guiding cross-modal alignment between well logging data and textual knowledge.This alignment mitigates modality gaps via token and sequence alignment,enhancing depth-domain feature representation.Finally,a cross-variable and cross-depth feature fusion strategy exploits both variable information and depth correlations,overcoming the difficulties in accurate reservoir parameter prediction posed by reservoir heterogeneity.Experimental results demonstrate that CAF2 significantly outperforms existing models in predicting tight sandstone reservoir parameters,serving as an effective tool for oil and gas exploration and development.展开更多
Tight reservoirs are widely distributed, especially in coal measure strata. Identification of the densification mechanism of the tight sandstone reservoirs is critical in effectively exploring and exploiting tight gas...Tight reservoirs are widely distributed, especially in coal measure strata. Identification of the densification mechanism of the tight sandstone reservoirs is critical in effectively exploring and exploiting tight gasoil resources. In this study, the gas for mation from type III organic matter in coal was kinetically modeled for the whole diagenetic stage, from the shallow buried biogas generation stage to the deep buried thermal gas generation stage. The results demonstrated that during hydrocarbon formation, quantities of nonhydrocarbon gases, such as CO2, were generated. The proportion of CO2 is about 50%70% of that of the C15, which far exceeds the CO2 content （05%） in the natural gas in the sedimentary basins. Geological case study analysis showed that a considerable part of the ＂lost＂ gaseous CO2 was converted into carbonate cement under favorable envi ronments. Under the ideal conditions, the volume of the carbonate cement transformed from total CO2 generated by 1 m3 coal （Junggar Basin Jurassic, TOC 67%） can amount to 0.32 m3. Obviously, this process plays a very important role in the for mation of tight sandstone reservoirs in the coal measures. Our results also show that the kinetic generation processes of Ci5 and CO2 are asynchronous. There are two main stages of CO2 generation, one at the weak diagenetic stage and the other at the overmature stage, which are different from largescale multistage hydrocarbon gas generation. Therefore, we can understand the mechanism of tight gas charging by determining the filling time for a tight gas reservoir and the key period of CO2 genera tion. Further analysis and correlation studies of a specific region are of great significance for determining the mechanism and modeling gas charging in tight reservoirs. It should be noted that the formation of tight sandstone reservoirs is the combined result of complex organicinorganic and waterrockhydrocarbon interactions. The details of spatial and temporal distributions of the carbonate cement derived from the organic C02, which combines with metal ions （Ca/Mg/Fe） in the formation water, should be further investigated.展开更多
The spatial-temporal relationship between high-quality source rocks and reservoirs is a key factor when evaluating the formation,occurrence,and prospectivity of tight oil and gas reservoirs.In this study,we analyze th...The spatial-temporal relationship between high-quality source rocks and reservoirs is a key factor when evaluating the formation,occurrence,and prospectivity of tight oil and gas reservoirs.In this study,we analyze the fundamental oil and gas accumulation processes occurring in the Songliao Basin,contrasting tight oil sand reservoirs in the south with tight gas sand reservoirs in the north.This is done using geochemical data,constant-rate and conventional mercury injection experiments,and fluid inclusion analyses.Our results demonstrate that as far as fluid mobility is concerned,the expulsion center coincides with the overpressure zone,and its boundary limits the occurrence of tight oil and gas accumulations.In addition,the lower permeability limit of high-quality reservoirs,controlled by pore-throat structures,is 0.1×10^-3μm^2 in the fourth member of the Lower Cretaceous Quantou Formation(K1q^4)in the southern Songliao Basin,and 0.05×10^-3μm^2 in the Lower Cretaceous Shahezi Formation(K1sh)in the northern Songliao Basin.Furthermore,the results indicate that the formation of tight oil and gas reservoirs requires the densification of reservoirs prior to the main phase of hydrocarbon expulsion from the source rocks.Reservoir“sweet spots”develop at the intersection of high-quality source rocks(with high pore pressure)and reservoirs(with high permeability).展开更多
Taking the second member of the Xujiahe Formation of the Upper Triassic in the Xinchang structural belt as an example,based on data such as logging,production,seismic interpretation and test,a systematic analysis was ...Taking the second member of the Xujiahe Formation of the Upper Triassic in the Xinchang structural belt as an example,based on data such as logging,production,seismic interpretation and test,a systematic analysis was conducted on the structural characteristics and evolution,reservoir diagenesis and densification processes,and types and stages of faults/fractures,and revealing the multi-stage and multi-factor dynamic coupled enrichment mechanisms of tight gas reservoirs.(1)In the early Yanshan period,the paleo-structural traps were formed with low-medium maturity hydrocarbons accumulating in structural highs driven by buoyancy since reservoirs were not fully densified in this stage,demonstrating paleo-structure control on traps and early hydrocarbon accumulation.(2)In the middle-late Yanshan period,the source rocks became mature to generate and expel a large quantity of hydrocarbons.Grain size and type of sandstone controlled the time of reservoir densification,which restricted the scale of hydrocarbon charging,allowing for only a small-scale migration through sand bodies near the fault/fracture or less-densified matrix reservoirs.(3)During the Himalayan period,the source rocks reached overmaturity,and the residual oil cracking gas was efficiently transported along the late-stage faults/fractures.Wells with high production capacity were mainly located in Type I and II fault/fracture zones comprising the late-stage north-south trending fourth-order faults and the late-stage fractures.The productivity of the wells was controlled by the transformation of the late-stage faults/fractures.(4)The Xinchang structural belt underwent three stages of tectonic evolution,two stages of reservoir formation,and three stages of fault/fractures development.Hydrocarbons mainly accumulated in the paleo-structure highs.After reservoir densification and late fault/fracture adjustment,a complex gas-water distribution pattern was formed.Thus,it is summarized as the model of“near-source and low-abundance hydrocarbon charging in the early stage,and differential enrichment of natural gas under the joint control of fault-fold-fracture complex,high-quality reservoirs and structural highs in the late stage”.Faults/fractures with well-coupled fault-fold-fracture-pore are favorable exploration targets with high exploration effectiveness.展开更多
Seismic characterizing of tight gas sandstone (TGS) reservoirs is essential for identifying promising gas-bearing regions. However, exploring the petrophysical significance of seismic-inverted elastic properties is ch...Seismic characterizing of tight gas sandstone (TGS) reservoirs is essential for identifying promising gas-bearing regions. However, exploring the petrophysical significance of seismic-inverted elastic properties is challenging due to the complex microstructures in TGSs. Meanwhile, interbedded structures of sandstone and mudstone intensify the difficulty in accurately extracting the crucial tight sandstone properties. An integrated rock-physics-based framework is proposed to estimate the reservoir quality of TGSs from seismic data. TGSs with complex pore structures are modeled using the double-porosity model, providing a practical tool to compute rock physics templates for reservoir parameter estimation. The VP/VS ratio is utilized to predict the cumulative thickness of the TGS reservoirs within the target range via the threshold value evaluated from wireline logs for lithology discrimination. This approach also facilitates better capturing the elastic properties of the TGSs for quantitative seismic interpretation. Total porosity is estimated from P-wave impedance using the correlation obtained based on wireline log analysis. After that, the three-dimensional rock-physics templates integrated with the estimated total porosity are constructed to interpret microfracture porosity and gas saturation from velocity ratio and bulk modulus. The integrated framework can optimally estimate the parameters dominating the reservoir quality. The results of the indicator proposed based on the obtained parameters are in good agreement with the gas productions and can be utilized to predict promising TGS reservoirs. Moreover, the results suggest that considering microfracture porosity allows a more accurate prediction of high-quality reservoirs, further validating the applicability of the proposed method in the studied region.展开更多
Through comprehensively applying geological and geophysical data,as well as core and thin section observation,the characteristics of reservoirs and fractures in the second member of the Xujiahe Formation(hereinafter r...Through comprehensively applying geological and geophysical data,as well as core and thin section observation,the characteristics of reservoirs and fractures in the second member of the Xujiahe Formation(hereinafter referred to as Xu2 Member)in the Yuanba area,northern Sichuan Basin,were studied.Combined with the analysis of the main controlling factors of production capacity,the types and characteristics of the sweet spots in the tight sandstone gas reservoir were determined.The evaluation standards and geological models of the sweet spots were established.The results are as follows:(1)There are bedding-parallel fracture-,fault-induced fracture-,and pore-dominated sweet spots in the tight sandstone gas reservoirs of the Xu2 Member.(2)The bedding parallel fracture-dominated sweet spots have developed in quartz sandstones with well-developed horizontal fractures and micro-fractures.They are characterized by high permeability and high gas output during production tests.This kind of sweet spots is thin and shows a limited distribution.Their logging responses show extremely low gamma-ray(GR)values and medium-high AC values.Moreover,the bedding parallel fracture-dominated sweet spots can be mapped using seismic methods.(3)The fault-induced fracture-dominated sweet spots have welldeveloped medium-and high-angle shear fractures.Their logging responses show an increase in peaks of AC values and total hydrocarbon content and a decrease in resistivity.Seismically,the areas with welldeveloped fault-induced fracture-dominated sweet spots can be effectively mapped using the properties such as seismic entropy and maximum likelihood.(4)The pore-dominated sweet spots are developed in medium-grained feldspathic litharenites with good reservoir properties.They are thick and widely distributed.(5)These three types of sweet spots are mainly determined by sedimentation,diagenesis,and tectonism.The bedding parallel fracture-dominated sweet spots are distributed in beachbar quartz sandstones on the top of the 1st sand layer group in the Xu2 Member,which develops in a shore-shallow lake environment.The fault-induced fracture-dominated sweet spots mainly occur near faults.They are increasingly developed in areas closer to faults.The pore-dominated sweet spots are primarily distributed in the 2nd and 3rd sand layer groups,which lie in the development areas of distributary channels near provenances at western Yuanba area.Based on the geological and seismic data,a comprehensive evaluation standard for these three types of sweet spots of the tight sandstone reservoirs in the Xu2 Member has been established,which,on the one hand,lays the foundation for the development and evaluation of the gas reservoir,and on the other hand,deepens the understanding of sweet spot in the tight sandstone gas reservoirs.展开更多
At present,evaluation on reservoir damage induced by fracturing fluid mainly refers to The Evaluation Measurement for Properties of Water-based Fracturing Fluid:SY/T5107-2016(referred to as the industry standard below...At present,evaluation on reservoir damage induced by fracturing fluid mainly refers to The Evaluation Measurement for Properties of Water-based Fracturing Fluid:SY/T5107-2016(referred to as the industry standard below).However,the fracturing fluid displacing core process stipulated in the industry standard is not consistent with the fast invading process of fracturing fluid into the reservoir under high pressure during the actual fracturing construction.Besides,the influences of fracturing fluid residues,gel breaking mode,original water saturation and other factors are not taken into consideration in the experiments to evaluate the damage of fracturing fluids.Thus,the accuracy of evaluation results is influenced.In this paper,tight sandstone cores of the Lower Jurassic Ahe Formation(J1a)in Dibei area of Kuqa Depression of the Tarim Basin were selected as samples.The invading process of fracturing fluid into a tight sandstone reservoir was simulated by modifying experimental process and method.Then,the damage degree of fracturing fluid to gas reservoir was evaluated and the damage mechanisms of fracturing fluid were analyzed systematically.And the following research results were obtained.First,themodified evaluationmethod takes into account the influences of several factors,such as the originalwater saturation of gas reservoir,the instantaneous“breakdown”effect of high-pressure during fracturing and the fracturing fluid residues,so it can evaluate the damage degree of fracturing fluid to tight sandstone gas reservoirsmore objectively.Second,the evaluation results based on the industry standard showthat the damage degree of fracturing fluid to the permeability of tight sandstone gas reservoirs ismedium to strong,whereas the damage degree evaluated by themodifiedmethod is medium to weak.Third,the retention of fracturing fluid residues in fractures is the main cause of permeability damage.The residues can easily block fractures and fracture surface pores.Most of them retain in the pores in the surface layer of matrix cores(invasion depth less than 3 cm),so residues are filtered by matrix pores.Fourth,when fracturing fluid migrates inwards from the core surface,high molecular polymers retain in the form of thin-film lamellar,local flaky nodular and crystal inclusion in turn in the reservoir pores.Fifth,under the experimental conditions,salting-out crystals appear and are unevenly distributed in the cores.In fractures,salting-out crystals and high molecules are polymerized to form composite inclusions.In matrix pores,salting-out crystals and a small number of fragments(e.g.illite)are enclosed to form a complex.Sixth,migratory particles caused by speed sensitivity are usually combined with residues and high molecular polymers to form composite inclusions,thus blocking pores and fractures.展开更多
In order to explore the damage mechanisms and improve the method to evaluate and optimize the performance of formation damage control of oil-based drill-in fluids, this paper took an ultra-deep fractured tight gas res...In order to explore the damage mechanisms and improve the method to evaluate and optimize the performance of formation damage control of oil-based drill-in fluids, this paper took an ultra-deep fractured tight gas reservoir in piedmont configuration, located in the Cretaceous Bashijiqike Fm of the Tarim Basin, as an example. First, evaluation experiments were conducted on the filtrate invasion, the dynamic damage of oil-based drill-in fluids and the loading capacity of filter cakes. Meanwhile, the evaluating methods were optimized for the formation damage control effect of oil-based drill-in fluids in laboratory: pre-processing drill-in fluids before grading analysis;using the dynamic damage method to simulate the damage process for evaluating the percentage of regained permeability;and evaluating the loading capacity of filter cakes. The experimental results show that (1) oil phase trapping damage and solid phase invasion are the main formation damage types;(2) the damage degree of filtrate is the strongest on the matrix;and (3) the dynamic damage degree of oil-based drill-in fluids reaches medium strong to strong on fractures and filter cakes show a good sealing capacity for the fractures less than 100 μm. In conclusion, the filter cakes' loading capacity should be first guaranteed, and both percentage of regained permeability and liquid trapping damage degree should be both considered in the oil-based drill-in fluids prepared for those ultra-deep fractured tight sandstone gas reservoirs.展开更多
In order to solve the difficulties in the volume fracturing stimulation of Middle Jurassic Shaximiao Formation tight sandstone reservoirs in the Qiulin Block of Central Sichuan Basin and explore the adaptability of hi...In order to solve the difficulties in the volume fracturing stimulation of Middle Jurassic Shaximiao Formation tight sandstone reservoirs in the Qiulin Block of Central Sichuan Basin and explore the adaptability of high-intensity volumefracturing technology,we selected the outcrop samples of Shaximiao Formation tight sandstone in the Qiulin Block to carry out the physical simulation experiment of true triaxial hydraulic fracturing.On this basis,horizontal well cluster perforation was optimally designed by using the production predictionmodel of staged multi-cluster fracturing horizontal wells.Then,based on the liquid control and proppant increase mode,three rounds of pilot tests were carried out on the tight sandstone reservoirs in this area.Andthe following research resultswere obtained.First,natural fractures in the ShaximiaoFormation tight sandstone reservoir of theQiulin Block are undeveloped,and hydraulic fractures are morphologically dominated by symmetric double-wing fractures,so complex fracture networks can be hardly formed.In addition,the reservoir is of medium to strong water sensitivity,so conventional volume fracturing is not adaptive to the reservoir stimulation in this block.Second,the connotation of high-intensity volume fracturing technology is to carry out multi-cluster perforation in each section to form multiple independent double-wing fractures and to implement the proppant injection mode of liquid control and proppant increase to reduce the inflowfluid while ensuring the high-intensity proppant injection,so as to reduce the damage of inflowfluid to the formation.Third,there are 10 fracturing sections inWell Qiulin 207-5-H2,with 7-12 clusters in each section,and the displacement is in the range of 16-18m^(3)/min.According to the fluid control and proppant increase mode,12146 m^(3) slick water and 4170 t proppant are injected in total.The tested production rate and absolute open flow of natural gas after the fracturing are up to 83.88×10^(4)m^(3)/d and 214.05×10^(4)m^(3)/d,respectively.Fourth,with the decrease of cluster spacing,the cumulative gas production increases gradually,but when the cluster spacing is less than 15 m,the increase amplitude of cumulative gas production decreases.Fifth,when the proppant injection intensity is lower than 6 t/m,the tested gas production per kilometer of stimulated section ina horizontal well overall presents an increasing trend with the increase of proppant injection intensity.When the proppant injection intensity is higher than 6 t/m,however,the tested gas production per kilometer of stimulated section does not increase significantly with the increase of proppant injection intensity.Sixth,as the included angle between the borehole trajectory and the direction ofmaximumhorizontal principal stress increases,the tested gas production per kilometer of stimulated section overall presents an increasing trend.When the hydraulic fracture is nearly perpendicular to the borehole,the effective drainage area is the largest and the tested gas production per kilometer of stimulated section is also the highest.In conclusion,the fracturing mode of high production well has a borehole trajectory of large included angle,perforation cluster spacing of 10 m or so,proppant injection intensity of 5 t/m and large-displacement slick water+continuous injection of combined particle size proppant.展开更多
Tight sandstone gas reservoirs commonly contain water,so liquid loading often appears near wellbores,leading to production decline and even shutdown of gas wells.Therefore,the study on the change of water saturation n...Tight sandstone gas reservoirs commonly contain water,so liquid loading often appears near wellbores,leading to production decline and even shutdown of gas wells.Therefore,the study on the change of water saturation near wellbores is of great significance to understanding the water production mechanisms of gas wells.In this paper,a set of physical simulation experiment procedures of identifying the change of water saturation near wellbores was designed according to the principle of radial well seepage of gas wells,and the production performance after vertical well fracturing in gas reservoirs was simulated by connecting tight cores with a diameter of 10.5 cm,3.8 cm and 2.5 cm in series in a descending order of distance.According to the depressurizing production mode of gas wells,tubes with small diameters of 20,30,40 and 50 mm were used to simulate gas well tubing to control the gas production rate.And the change of water saturation near wellbore in the process of depletion production and its influencing factors were investigated.Finally,combined with actual data of production wells,the water saturation and water production of gas wells near wellbores and in different zones were calculated at the above four different small diameters of tubes and the changes thereof were also analyzed.The following results were obtained.First,each gas production rate corresponds to a critical water saturation.When the initial water saturation is lower than the critical value,the formation water flowing near the wellbore and in the middle zone can be carried out along with the production of gas and no liquid loading is formed.Second,when the initial water saturation is higher than the critical value,a large amount of formation water migrating from the far-wellbore zones accumulates near the wellbore,and thus liquid loading occurs at the bottom hole.Third,when the initial water saturation is equal to the critical value,the higher the gas production rate is,the more easily liquid loading tends to form near the wellbore.Fourth,for the same water saturation,water production increases and recovery factor decreases with the increase of gas production rate.In conclusion,the cumulative water production chart of a gas well generated by the physical simulation experiment method proposed in this paper agrees well with the water production behavior of the corresponding gas well.The research results are conducive to the effective prediction of gas well water production and can be used as guidance for the reasonable gas well water control.展开更多
Injecting CO_(2)when the gas reservoir of tight sandstone is depleted can achieve the dual purposes of greenhouse gas storage and enhanced gas recovery(CS-EGR).To evaluate the feasibility of CO_(2)injection to enhance...Injecting CO_(2)when the gas reservoir of tight sandstone is depleted can achieve the dual purposes of greenhouse gas storage and enhanced gas recovery(CS-EGR).To evaluate the feasibility of CO_(2)injection to enhance gas recovery and understand the production mechanism,a numerical simulation model of CS-EGR in multi-stage fracturing horizontal wells is established.The behavior of gas production and CO_(2)sequestration is then analyzed through numerical simulation,and the impact of fracture parameters on production performance is examined.Simulation results show that the production rate increases significantly and a large amount of CO_(2)is stored in the reservoir,proving the technical potential.However,hydraulic fractures accelerate CO_(2)breakthrough,resulting in lower gas recovery and lower CO_(2)storage than in gas reservoirs without fracturing.Increasing the length of hydraulic fractures can significantly increase CH4production,but CO_(2)breakthrough will advance.Staggered and spaced perforation of hydraulic fractures in injection wells and production wells changes the fluid flow path,which can delay CO_(2)breakthrough and benefit production efficiency.The fracture network of massive hydraulic fracturing has a positive effect on the CS-EGR.As a result,CH4production,gas recovery,and CO_(2)storage increase with the increase in stimulated reservoir volume.展开更多
Exploration and development practices have proved that staged volumetric fracturing stimulation in horizontal wells is a key technology for tight sandstone gas development,and reservoir sweet spot is an important basi...Exploration and development practices have proved that staged volumetric fracturing stimulation in horizontal wells is a key technology for tight sandstone gas development,and reservoir sweet spot is an important basis for the perforation position selection and staged fracturing in the process of well location deployment and reservoir stimulation.Tight sandstone reservoirs are usually characterized by sandstone and mudstone interlayers with different thicknesses,and complex natural fracture distribution and geostress state.It is hard to predict“geological-engineering”dual sweet spots,and these two kinds of sweet spots are usually in different zones.As a result,there lacks a basis for the optimization of fracturing parameters to stimulate tight sandstone reservoirs.This paper establishes a geological sweet spot prediction model which takes into account total hydrocarbon content,reservoir porosity and other factors,then puts forward a 3D multi-scale engineering sweet spot evaluation method which takes into account lithology,fracture morphology,fracture mechanical behavior,and dilatation and shear dilation effect,andfinally a“geological-engineering”dual sweet spot evaluation model for tight sandstone reservoirs.Two wells in the tight sandstone gasfield in the Linxing Block of the Ordos Basin were selected as a case,and the dual sweet spot profiles,fracturing pressure and SRV were compared and analyzed.The results show that:1)shear dilation angle influences the distribution of engineering sweet spots at the most in the study area,followed by dissipated energy,elastic modulus and fracture energy;2)the geological sweet spot zone with a high coefficient is not necessarily the pay zone with high shale gas production;3)the engineering sweet spot zone with a high coefficient needs lower fracture pressure and can be stimulated relatively sufficiently;4)high-quality geological sweet spots and high-quality engineering sweet spots are poorly consistent in spatial location.In conclusion,the stimulation of tight sandstone gas reservoirs shall take geological sweet spot as the basis and engineering sweet spot as the guarantee,and the distribution of dual sweep spots should be considered comprehensively.The multi-scale“geological-engineering”dual sweet spot evaluation method proposed in this paper provides important technical support for the prediction of sweet spots of the tight sandstone gas and the optimization of development schemes in the study area.展开更多
The reservoir permeability of tight sandstone gas reservoirs is low,which makes it difficult to carry out displacement flow experiments on real cores underground conditions,so the microscopic flow mechanism can be har...The reservoir permeability of tight sandstone gas reservoirs is low,which makes it difficult to carry out displacement flow experiments on real cores underground conditions,so the microscopic flow mechanism can be hardly studied.Based on the lattice Boltzmann method(LBM),this paper simulated the flow process of formation water displaced by tight gas under the simulated reservoir conditions of high temperature and high pressure to clarify the distribution of bound water in the reservoir.Then,reservoir drying was experimentally studied using the laser etching model,and numerical simulation of reservoir drying was simplified by referring to the visualization results of the experiment.Finally,the influence of reservoir drying on the seepage capacity of tight gas was studied by means of numerical simulation.And the following research results were obtained.First,when the lattice Boltzmann model is used for high temperature and high pressure reservoirs,it satisfies the Laplace law and its numerical solution of two-phase Poiseuille flow rate is basically consistent with the analytical solution,which indicates that this model can be used to simulate gasewater immiscible displacement under reservoir conditions.Second,tight gas preferentially breaks through in large porous media connected channels,and after the breakthrough,the displacement rate of formation water decreases significantly.Third,the contact angle between formation water and rock wall has a significant influence on gasewater two-phase flow.The stronger the water wettability of the rock is,the lower the displacement rate is.Fourth,the bound water in tight sandstone gas reservoirs can be classified into four types,including adsorbed water film,blind end pore water,dead pore water and trapped water.In porous media,a large number of connected microchannels are occupied by trapped water and adsorbed water film and the phenomenon of“water lock”is obvious,which seriously influences the seepage capacity of tight gas in the porous media of reservoir.Fifth,drying agent can react with bound water to produce a large number of bubbles,which will consume adsorbed water film,trapped water and blind end pore water,so as to improve the gas seepage capacity.Sixth,in the“water lock”regions formed by trapped water,the gas seepage capacity can be effectively improved by increasing the drying strength.On the whole,the tight gas permeability increases with the increase of drying strength,but its increase amplitude decreases gradually when the drying strength exceeds a certain degree.展开更多
The Yan'an Gas Field is located in the southeastern part of the Ordos Basin,and its low-permeability tight sandstone gas reservoirs are characterized by thin reservoirs,poor physical properties and complex overlap...The Yan'an Gas Field is located in the southeastern part of the Ordos Basin,and its low-permeability tight sandstone gas reservoirs are characterized by thin reservoirs,poor physical properties and complex overlapping relationships.In addition,its surface is loess tableland,which makes it difficult to predict reservoirs by using seismic data.As a result,existing engineering technologies for gas field development cannot support the efficient development of this field.In order to optimize the development methods and technologies of the Yan'an Gas Field,the Yanchang Petroleum(Group)Co.Ltd.has developed to a set of key technologies suitable for the benefit development of this field concerning reservoir prediction,well pattern optimization,drilling and completion,reservoir protection,fracturing stimulation and ground gathering and transportation after nearly ten years of theoretical and technical researches.First,an effective reservoir prediction technology based on dynamic knowledge base was developed.It improves the drilling ratio of effective sandbody dramatically and achieves the accurate tracking of stable single sandbody in the range of 3-5 m.Second,a three-dimensional exploitation mode of hybrid well pattern based on the irregular diamond-shaped well pattern was established.It includes the multi-layer commingled production of cluster well and the single-layer production of horizontal well.Compared with regular well patterns,the well number is reduced by 6.9%and well pattern control is increased by 8%.Third,high-efficiency drilling technology for vulnerable reservoirs with collapse and leakage in the same well was developed.It improves wellbore wall stability,shortens drilling cycle and protects reservoir.Fourth,the multi-layer long-span fracturing of vertical/directional wells in one operation and the CO_(2)and hydraulic fracturing treatment of horizontal wells were realized to improve single well production significantly.Fifth,the medium-pressure gathering and transportation system in loess tableland with downhole throttling,branch-on-branch inter-well tandem and centralized alcohol injection as the core technologies was established.It reduces workload,shortens construction cycle and improves economic benefit.In conclusion,these development technologies play a crucial role in the development,appraisal and productivity construction of the Yan'an Gas Field.Through the application of these key technologies,the benefit development of this field is realized with an annual natural gas production capacity of 50×10^(8)m^(3).Furthermore,they are conducive to the enrichment and development of the theories and technologies for developing tight sandstone gas reservoirs in China,and they can be used as a reference for the development of similar gas fields.展开更多
The sandstone layers of the Upper Paleozoic tight clastic gas reservoirs in the Ordos Basin are generally distributed in a pattern of nearly NS strip,and the channel branches and intersects frequently.A single sand bo...The sandstone layers of the Upper Paleozoic tight clastic gas reservoirs in the Ordos Basin are generally distributed in a pattern of nearly NS strip,and the channel branches and intersects frequently.A single sand body is in a multilayered contact mode resulted from lateral accretion,and the sand bodies at the river intersections present a feature of lying in the nearly EW direction,which brings great difficulties to the geosteering of horizontal wells.In order to improve the reservoir drilling rate of horizontal wells,this paper systematically analyzed the geosteering status of horizontal wells and the sedimentary characteristics of reservoirs.Then,the spatial distribution of reservoirs was predicted using 3D geological modeling and 3D seismic.In addition,based on the cognitions on the space distribution of sand bodies from the drilled horizontal wells,the horizontal well geo-steering technology and method were constantly improved and enriched.Thus,an integrated steering technology of“fine sublayer correlation for target entering,geology in small scale,and seismic in large scale”based on in-depth integration of multidisciplinary thinking was newly formed,and it was also applied on site.And the following research results were obtained.First,under the guidance of the sedimentation model,the target entering process is controlled precisely and the success rate of one-trip target entering is improved,so it is one important method for the target steering of deviated hole sections.Second,geological modeling can guide the drilling of horizontal wells,but to some extent,it is deviated from the real underground geologic bodies,so it can be used as an auxiliary horizontal-well steering method.Third,3D seismic steering can tell the boundary of complex river channel and discriminate the spatial relative location of predominant sand bodies,so it is the primary method for horizontal-well steering to provide excellent judgment and guidance on the steering of horizontal hole sections.Fourth,owing to the application of this new method in 62 horizontal wells drilled in the tight gas demonstration area,the average horizontal section length reaches 1430 m,the average sandstone drilling rate is 86.2%,the average gas layer drilling rate is 70.2%,and the gas layer drilling rate of horizontal wells is increased by more than 10%.展开更多
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.
文摘The tight sandstone reservoirs in the first sub-member of Chang 7 member(Chang 71)of Triassic Yanchang Formation in the Jiyuan area,Ordos Basin,show significant variations in microscopic pore-throat structure(PTS)and fluid mobility due to the influences of the northeast and northwest dual provenance systems.This study performed multiple experimental analyses on nine samples from the area to determine the petrological and petrophysical properties,as well as the PTS characteristics of reservoirs in different provenance-controlled regions.On this basis,the pore-throat size distribution(PSD)obtained from high-pressure mercury injection(HPMI)was utilized to convert the NMR movable fluid T2spectrum,allowing for quantitative characterization of the full PSD and the occurrence characteristics of movable fluids.A systematic analysis was conducted on the primary controlling factors affecting fluid mobility in the reservoir.The results indicated that the lithology in the eastern and western regions is lithic arkose.The eastern sandstones,being farther from the provenance,exhibit higher contents of feldspar and lithic fragments,along with the development of more dissolution pores.The reservoir possesses good petrophysical properties,low displacement pressure,and high pore-throat connectivity and homogeneity,indicating strong fluid mobility.In contrast,the western sandstones,being nearer to the provenance,exhibit poor grain sorting,high contents of lithic fragments,strong compaction and cementation effects,resulting in poor petrophysical properties,and strong pore-throat heterogeneity,revealing weak fluid mobility.The range of full PSD in the eastern reservoir is wider than that in the western reservoir,with relatively well-developed macropores.The macropores are the primary space for occurrence of movable fluids,and controls the fluid mobility of the reservoir.The effective porosity of movable fluids(EPMF)quantitatively represents the pore space occupied by movable fluids within the reservoir and correlates well with porosity,permeability,and PTS parameters,making it a valuable parameter for evaluating fluid mobility.Under the multi-provenance system,the eastern and western reservoirs underwent different sedimentation and diagenesis processes,resulting in differential distribution of reservoir mineral components and pore types,which in turn affects the PTS heterogeneity and reservoir quality.The composition and content of reservoir minerals are intrinsic factors influencing fluid mobility,while the microscopic PTS is the primary factor controlling it.Low clay mineral content,welldeveloped macropores,and weak pore-throat heterogeneity all contribute to the storage and seepage of reservoir fluids.
基金financially supported by the National Natural Science Foundation of China(Nos.41972172 and U1910205).
文摘Due to the complex conditions and strong heterogeneity of tight sandstone reservoirs,the reservoirs should be classified and the controlling factors of physical properties should be studied.Cast thin section observations,cathodoluminescence,scanning electron microscopy(SEM),X-ray diffraction(XRD),and high-pressure mercury injection(HPMI)were used to classify and optimize the reservoir.The Brooks-Corey model and stepwise regression were used to study the fractal dimension and main controlling factors of the physical properties of the high-quality reservoir.The results show that the reservoirs in the study area can be divided into four types,and the high-quality reservoir has the best physical properties and pore-throat characteristics.In the high-quality reservoir,the homogeneity of transitional pores was the best,followed by that of micropores,and the worst was mesopores.The porosity was controlled by depth and kaolinite.The model with standardized coefficients is y=12.454−0.778×(Depth)+0.395×(Kaolinite).The permeability was controlled by depth,illite/montmorillonite,and siliceous cement,and the model with standardized coefficients is y=1.689−0.683×(Depth)−0.395×(Illite/Montmorillonite)−0.337×(Siliceous Cement).The pore-throat evolutionary model shows that the early-middle diagenetic period was when the reservoir physical properties were at their best,and the kaolinite intercrystalline pores and residual intergranular pores were the most important.
基金supported by the National Natural Science Foundation of China"Full-borchole pore throat characterization and modeling of tight sandstone based on the combination of image method and fluid method"(No.41602141)"Mechanism and effects of imbibition and retention of fracturing fluid in in-situ shale gas reservoirs"(No.41972139)the Independent Innovation Foundation of Universities(No.18CX02069A).
文摘Tight sandstone gas reservoirs have poorer porosityepermeability relationships,so conventional reservoir classification schemes can hardly satisfy the classification and evaluation demand of this type of reservoirs.To solve this problem,this paper took the Permian tight sandstone gas reservoir in the Linxing Block along the eastern margin of the Ordos Basin as an example to describe the micro-structures of the tight sandstone reservoirs by means of high-pressure mercury injection,nuclear magnetic resonance(NMR),scanning electron mi-croscope(SEM)and so on.Then,the control effect of micro-structure parameters on the macrophysical properties was studied.Finally,classification and evaluation of tight sandstone reservoirs were carried out on this basis.And the following research results were obtained.First,NMR can identify the distribution of pores of different sizes,and high-pressure mercury injection can reflect the poreethroat configuration and percolation capacity of a reservoir.Second,both methods are better coincident in the description results.With an in-crease of the right peak of T2 spectra,the mercury intrusion curve presents a concave shape and the pore throat radius increases while the pore type gradually changes from intragranular dissolution pores and intercrystalline pores to intergranular pores and intergranular disso-lution pores and the reservoir quality gets better.Third,micro-pore structure controls reservoir physical properties andfluid mobility.And the porosity of large pores is best correlated with the effective porosity,so it can be used to evaluate the reservoir capacity of tight sandstone.Fourth,the throat radius R15 obtained by high pressure mercury injection is in the best correlation with porosity and permeability,so it can be used to evaluate the percolation capacity of tight sandstone.Fifth,by combining the porosity of large pores with the R15,the tight sandstone reservoirs in the Linxing Block are classified into 4 categories,and the classification results are in a good agreement with the on-site well test data.It is concluded that the combination of high-pressure mercury injection and NMR can effectively identify the key parameters which reflect the reservoir capacity and percolation capacity of tight sandstone,and improve the reliability and integrity of reservoir classification.And by selecting the key parameters that reflect reservoir capacity and percolation capacity,it can provide guidance for the classification and evaluation of tight sandstone reservoirs.
基金Supported by the China National Science and Technology Major Project(2016ZX05002-006)Sinopec Science and Technology Department Project(P18089-4)
文摘By using core,logging curves,and experiment data,favorable lithofacies types in the 2 nd Member of Triassic Xujiahe Formation in the Xinchang area,Sichuan Basin were classified,standard of the favorable lithofacies was established,planar distribution regularities of the favorable lithofacies were identified,and forming mechanisms of the favorable lithofacies and their control effect on production were examined.(1)The 2 nd Member of Xujiahe Formation has twelve types of lithofacies,among which multiple layer medium-coarse grain sandstone lithofacies,parallel bedding medium-coarse grain sandstone lithofacies,massive bedding medium-coarse grain sandstone lithofacies,inclined bedding medium-coarse grain sandstone lithofacies,and charcoal-bearing medium-coarse grain sandstone lithofacies with better physical properties and higher gas content are favorable lithofacies;they feature low gamma,low neutron porosity,low resistivity,and high acoustic travel time on logging curves.(2)The sedimentary process controls spatial distribution of sand bodies which are the material basis of the favorable lithofacies;post diagenetic fluids would differentially reconstruct the favorable lithofacies;tectonic activities and abnormal formation pressure made strata slide along the weakness plane,giving rise to fractures in different types of rocks,which can enhance the reservoir permeability significantly.(3)The development degree of favorable lithofacies is a major factor affecting stable production of gas well.
基金supported by the Special Funds for Science and Technology Planning Projects of Sichuan Province(No.2024YFHZ0158)。
文摘Accurate prediction of reservoir parameters is essential for reservoir evaluation.Recent machine learning methods have spurred significant advancements in reservoir prediction;however,limited well logging data and strong reservoir heterogeneity still hinder the accuracy and reliability of such predictions.Addressing these challenges requires methods capable of effectively predicting reservoir parameters under data scarcity and complex reservoir structures.In this study,we propose CAF2,a feature-fusion cross-modal alignment framework guided by large language models(LLMs).CAF2 integrates data augmentation,knowledge distillation,cross-modal alignment,and feature fusion.The data augmentation module employs the RealTabFormer model to generate synthetic datasets that mirror the distribution of real logging data,addressing the challenge of data scarcity.Knowledge distillation extracts essential domain knowledge from LLMs,guiding cross-modal alignment between well logging data and textual knowledge.This alignment mitigates modality gaps via token and sequence alignment,enhancing depth-domain feature representation.Finally,a cross-variable and cross-depth feature fusion strategy exploits both variable information and depth correlations,overcoming the difficulties in accurate reservoir parameter prediction posed by reservoir heterogeneity.Experimental results demonstrate that CAF2 significantly outperforms existing models in predicting tight sandstone reservoir parameters,serving as an effective tool for oil and gas exploration and development.
基金supported by National Natural Science Foundation of China (Grant No. 40873031)China Petroleum Foundation (Grant Nos. 2012Y-011, 2011B-0601)National Oil and Gas Special Foundation (Grant No. 2011ZX05007-001)
文摘Tight reservoirs are widely distributed, especially in coal measure strata. Identification of the densification mechanism of the tight sandstone reservoirs is critical in effectively exploring and exploiting tight gasoil resources. In this study, the gas for mation from type III organic matter in coal was kinetically modeled for the whole diagenetic stage, from the shallow buried biogas generation stage to the deep buried thermal gas generation stage. The results demonstrated that during hydrocarbon formation, quantities of nonhydrocarbon gases, such as CO2, were generated. The proportion of CO2 is about 50%70% of that of the C15, which far exceeds the CO2 content （05%） in the natural gas in the sedimentary basins. Geological case study analysis showed that a considerable part of the ＂lost＂ gaseous CO2 was converted into carbonate cement under favorable envi ronments. Under the ideal conditions, the volume of the carbonate cement transformed from total CO2 generated by 1 m3 coal （Junggar Basin Jurassic, TOC 67%） can amount to 0.32 m3. Obviously, this process plays a very important role in the for mation of tight sandstone reservoirs in the coal measures. Our results also show that the kinetic generation processes of Ci5 and CO2 are asynchronous. There are two main stages of CO2 generation, one at the weak diagenetic stage and the other at the overmature stage, which are different from largescale multistage hydrocarbon gas generation. Therefore, we can understand the mechanism of tight gas charging by determining the filling time for a tight gas reservoir and the key period of CO2 genera tion. Further analysis and correlation studies of a specific region are of great significance for determining the mechanism and modeling gas charging in tight reservoirs. It should be noted that the formation of tight sandstone reservoirs is the combined result of complex organicinorganic and waterrockhydrocarbon interactions. The details of spatial and temporal distributions of the carbonate cement derived from the organic C02, which combines with metal ions （Ca/Mg/Fe） in the formation water, should be further investigated.
基金supported by the National Natural Science Foundation of China(Nos.41210005 and 41776081)the National Oil and Gas Major Project of China(No.2011ZX05007-001)the Applied Basic Research Program of Qingdao(No.2016239)
文摘The spatial-temporal relationship between high-quality source rocks and reservoirs is a key factor when evaluating the formation,occurrence,and prospectivity of tight oil and gas reservoirs.In this study,we analyze the fundamental oil and gas accumulation processes occurring in the Songliao Basin,contrasting tight oil sand reservoirs in the south with tight gas sand reservoirs in the north.This is done using geochemical data,constant-rate and conventional mercury injection experiments,and fluid inclusion analyses.Our results demonstrate that as far as fluid mobility is concerned,the expulsion center coincides with the overpressure zone,and its boundary limits the occurrence of tight oil and gas accumulations.In addition,the lower permeability limit of high-quality reservoirs,controlled by pore-throat structures,is 0.1×10^-3μm^2 in the fourth member of the Lower Cretaceous Quantou Formation(K1q^4)in the southern Songliao Basin,and 0.05×10^-3μm^2 in the Lower Cretaceous Shahezi Formation(K1sh)in the northern Songliao Basin.Furthermore,the results indicate that the formation of tight oil and gas reservoirs requires the densification of reservoirs prior to the main phase of hydrocarbon expulsion from the source rocks.Reservoir“sweet spots”develop at the intersection of high-quality source rocks(with high pore pressure)and reservoirs(with high permeability).
基金Supported by the National Natural Science Foundation of China(42302141).
文摘Taking the second member of the Xujiahe Formation of the Upper Triassic in the Xinchang structural belt as an example,based on data such as logging,production,seismic interpretation and test,a systematic analysis was conducted on the structural characteristics and evolution,reservoir diagenesis and densification processes,and types and stages of faults/fractures,and revealing the multi-stage and multi-factor dynamic coupled enrichment mechanisms of tight gas reservoirs.(1)In the early Yanshan period,the paleo-structural traps were formed with low-medium maturity hydrocarbons accumulating in structural highs driven by buoyancy since reservoirs were not fully densified in this stage,demonstrating paleo-structure control on traps and early hydrocarbon accumulation.(2)In the middle-late Yanshan period,the source rocks became mature to generate and expel a large quantity of hydrocarbons.Grain size and type of sandstone controlled the time of reservoir densification,which restricted the scale of hydrocarbon charging,allowing for only a small-scale migration through sand bodies near the fault/fracture or less-densified matrix reservoirs.(3)During the Himalayan period,the source rocks reached overmaturity,and the residual oil cracking gas was efficiently transported along the late-stage faults/fractures.Wells with high production capacity were mainly located in Type I and II fault/fracture zones comprising the late-stage north-south trending fourth-order faults and the late-stage fractures.The productivity of the wells was controlled by the transformation of the late-stage faults/fractures.(4)The Xinchang structural belt underwent three stages of tectonic evolution,two stages of reservoir formation,and three stages of fault/fractures development.Hydrocarbons mainly accumulated in the paleo-structure highs.After reservoir densification and late fault/fracture adjustment,a complex gas-water distribution pattern was formed.Thus,it is summarized as the model of“near-source and low-abundance hydrocarbon charging in the early stage,and differential enrichment of natural gas under the joint control of fault-fold-fracture complex,high-quality reservoirs and structural highs in the late stage”.Faults/fractures with well-coupled fault-fold-fracture-pore are favorable exploration targets with high exploration effectiveness.
基金supported by the National Natural Science Foundation of China(Grant numbers 42274160 and 42074153).
文摘Seismic characterizing of tight gas sandstone (TGS) reservoirs is essential for identifying promising gas-bearing regions. However, exploring the petrophysical significance of seismic-inverted elastic properties is challenging due to the complex microstructures in TGSs. Meanwhile, interbedded structures of sandstone and mudstone intensify the difficulty in accurately extracting the crucial tight sandstone properties. An integrated rock-physics-based framework is proposed to estimate the reservoir quality of TGSs from seismic data. TGSs with complex pore structures are modeled using the double-porosity model, providing a practical tool to compute rock physics templates for reservoir parameter estimation. The VP/VS ratio is utilized to predict the cumulative thickness of the TGS reservoirs within the target range via the threshold value evaluated from wireline logs for lithology discrimination. This approach also facilitates better capturing the elastic properties of the TGSs for quantitative seismic interpretation. Total porosity is estimated from P-wave impedance using the correlation obtained based on wireline log analysis. After that, the three-dimensional rock-physics templates integrated with the estimated total porosity are constructed to interpret microfracture porosity and gas saturation from velocity ratio and bulk modulus. The integrated framework can optimally estimate the parameters dominating the reservoir quality. The results of the indicator proposed based on the obtained parameters are in good agreement with the gas productions and can be utilized to predict promising TGS reservoirs. Moreover, the results suggest that considering microfracture porosity allows a more accurate prediction of high-quality reservoirs, further validating the applicability of the proposed method in the studied region.
基金the Science&Technology Department of SINOPEC(No.P19012-2).
文摘Through comprehensively applying geological and geophysical data,as well as core and thin section observation,the characteristics of reservoirs and fractures in the second member of the Xujiahe Formation(hereinafter referred to as Xu2 Member)in the Yuanba area,northern Sichuan Basin,were studied.Combined with the analysis of the main controlling factors of production capacity,the types and characteristics of the sweet spots in the tight sandstone gas reservoir were determined.The evaluation standards and geological models of the sweet spots were established.The results are as follows:(1)There are bedding-parallel fracture-,fault-induced fracture-,and pore-dominated sweet spots in the tight sandstone gas reservoirs of the Xu2 Member.(2)The bedding parallel fracture-dominated sweet spots have developed in quartz sandstones with well-developed horizontal fractures and micro-fractures.They are characterized by high permeability and high gas output during production tests.This kind of sweet spots is thin and shows a limited distribution.Their logging responses show extremely low gamma-ray(GR)values and medium-high AC values.Moreover,the bedding parallel fracture-dominated sweet spots can be mapped using seismic methods.(3)The fault-induced fracture-dominated sweet spots have welldeveloped medium-and high-angle shear fractures.Their logging responses show an increase in peaks of AC values and total hydrocarbon content and a decrease in resistivity.Seismically,the areas with welldeveloped fault-induced fracture-dominated sweet spots can be effectively mapped using the properties such as seismic entropy and maximum likelihood.(4)The pore-dominated sweet spots are developed in medium-grained feldspathic litharenites with good reservoir properties.They are thick and widely distributed.(5)These three types of sweet spots are mainly determined by sedimentation,diagenesis,and tectonism.The bedding parallel fracture-dominated sweet spots are distributed in beachbar quartz sandstones on the top of the 1st sand layer group in the Xu2 Member,which develops in a shore-shallow lake environment.The fault-induced fracture-dominated sweet spots mainly occur near faults.They are increasingly developed in areas closer to faults.The pore-dominated sweet spots are primarily distributed in the 2nd and 3rd sand layer groups,which lie in the development areas of distributary channels near provenances at western Yuanba area.Based on the geological and seismic data,a comprehensive evaluation standard for these three types of sweet spots of the tight sandstone reservoirs in the Xu2 Member has been established,which,on the one hand,lays the foundation for the development and evaluation of the gas reservoir,and on the other hand,deepens the understanding of sweet spot in the tight sandstone gas reservoirs.
基金Project supported by National Natural Science Foundation of China“Basic study on drying of tight gas reservoir and enhancing gas seepage capacity”(No.51534006).
文摘At present,evaluation on reservoir damage induced by fracturing fluid mainly refers to The Evaluation Measurement for Properties of Water-based Fracturing Fluid:SY/T5107-2016(referred to as the industry standard below).However,the fracturing fluid displacing core process stipulated in the industry standard is not consistent with the fast invading process of fracturing fluid into the reservoir under high pressure during the actual fracturing construction.Besides,the influences of fracturing fluid residues,gel breaking mode,original water saturation and other factors are not taken into consideration in the experiments to evaluate the damage of fracturing fluids.Thus,the accuracy of evaluation results is influenced.In this paper,tight sandstone cores of the Lower Jurassic Ahe Formation(J1a)in Dibei area of Kuqa Depression of the Tarim Basin were selected as samples.The invading process of fracturing fluid into a tight sandstone reservoir was simulated by modifying experimental process and method.Then,the damage degree of fracturing fluid to gas reservoir was evaluated and the damage mechanisms of fracturing fluid were analyzed systematically.And the following research results were obtained.First,themodified evaluationmethod takes into account the influences of several factors,such as the originalwater saturation of gas reservoir,the instantaneous“breakdown”effect of high-pressure during fracturing and the fracturing fluid residues,so it can evaluate the damage degree of fracturing fluid to tight sandstone gas reservoirsmore objectively.Second,the evaluation results based on the industry standard showthat the damage degree of fracturing fluid to the permeability of tight sandstone gas reservoirs ismedium to strong,whereas the damage degree evaluated by themodifiedmethod is medium to weak.Third,the retention of fracturing fluid residues in fractures is the main cause of permeability damage.The residues can easily block fractures and fracture surface pores.Most of them retain in the pores in the surface layer of matrix cores(invasion depth less than 3 cm),so residues are filtered by matrix pores.Fourth,when fracturing fluid migrates inwards from the core surface,high molecular polymers retain in the form of thin-film lamellar,local flaky nodular and crystal inclusion in turn in the reservoir pores.Fifth,under the experimental conditions,salting-out crystals appear and are unevenly distributed in the cores.In fractures,salting-out crystals and high molecules are polymerized to form composite inclusions.In matrix pores,salting-out crystals and a small number of fragments(e.g.illite)are enclosed to form a complex.Sixth,migratory particles caused by speed sensitivity are usually combined with residues and high molecular polymers to form composite inclusions,thus blocking pores and fractures.
基金Project supported by the National Natural Science Foundation of China “Research on the transmission mechanism of the oxidative fracturing, permeability-increasing and accelerating gas in the organic-rich shale” (No.: 51674209)“Damage prediction and control for the lost circulation of the working fluid in the fractured reservoir based on the percolation and solid–liquid two-phase flow theories” (No.: 51604236).
文摘In order to explore the damage mechanisms and improve the method to evaluate and optimize the performance of formation damage control of oil-based drill-in fluids, this paper took an ultra-deep fractured tight gas reservoir in piedmont configuration, located in the Cretaceous Bashijiqike Fm of the Tarim Basin, as an example. First, evaluation experiments were conducted on the filtrate invasion, the dynamic damage of oil-based drill-in fluids and the loading capacity of filter cakes. Meanwhile, the evaluating methods were optimized for the formation damage control effect of oil-based drill-in fluids in laboratory: pre-processing drill-in fluids before grading analysis;using the dynamic damage method to simulate the damage process for evaluating the percentage of regained permeability;and evaluating the loading capacity of filter cakes. The experimental results show that (1) oil phase trapping damage and solid phase invasion are the main formation damage types;(2) the damage degree of filtrate is the strongest on the matrix;and (3) the dynamic damage degree of oil-based drill-in fluids reaches medium strong to strong on fractures and filter cakes show a good sealing capacity for the fractures less than 100 μm. In conclusion, the filter cakes' loading capacity should be first guaranteed, and both percentage of regained permeability and liquid trapping damage degree should be both considered in the oil-based drill-in fluids prepared for those ultra-deep fractured tight sandstone gas reservoirs.
基金Project supported by the Scientific Research and Technical Development Project of Postdoctoral Workstation of PetroChina Southwest Oil and Gas Field Company“Research on fracture morphology control and reconstruction technology of tight sandstone gas reservoir in Jinhua-Zhongtaishan ShaximiaoFormation”(No:20190302-15).
文摘In order to solve the difficulties in the volume fracturing stimulation of Middle Jurassic Shaximiao Formation tight sandstone reservoirs in the Qiulin Block of Central Sichuan Basin and explore the adaptability of high-intensity volumefracturing technology,we selected the outcrop samples of Shaximiao Formation tight sandstone in the Qiulin Block to carry out the physical simulation experiment of true triaxial hydraulic fracturing.On this basis,horizontal well cluster perforation was optimally designed by using the production predictionmodel of staged multi-cluster fracturing horizontal wells.Then,based on the liquid control and proppant increase mode,three rounds of pilot tests were carried out on the tight sandstone reservoirs in this area.Andthe following research resultswere obtained.First,natural fractures in the ShaximiaoFormation tight sandstone reservoir of theQiulin Block are undeveloped,and hydraulic fractures are morphologically dominated by symmetric double-wing fractures,so complex fracture networks can be hardly formed.In addition,the reservoir is of medium to strong water sensitivity,so conventional volume fracturing is not adaptive to the reservoir stimulation in this block.Second,the connotation of high-intensity volume fracturing technology is to carry out multi-cluster perforation in each section to form multiple independent double-wing fractures and to implement the proppant injection mode of liquid control and proppant increase to reduce the inflowfluid while ensuring the high-intensity proppant injection,so as to reduce the damage of inflowfluid to the formation.Third,there are 10 fracturing sections inWell Qiulin 207-5-H2,with 7-12 clusters in each section,and the displacement is in the range of 16-18m^(3)/min.According to the fluid control and proppant increase mode,12146 m^(3) slick water and 4170 t proppant are injected in total.The tested production rate and absolute open flow of natural gas after the fracturing are up to 83.88×10^(4)m^(3)/d and 214.05×10^(4)m^(3)/d,respectively.Fourth,with the decrease of cluster spacing,the cumulative gas production increases gradually,but when the cluster spacing is less than 15 m,the increase amplitude of cumulative gas production decreases.Fifth,when the proppant injection intensity is lower than 6 t/m,the tested gas production per kilometer of stimulated section ina horizontal well overall presents an increasing trend with the increase of proppant injection intensity.When the proppant injection intensity is higher than 6 t/m,however,the tested gas production per kilometer of stimulated section does not increase significantly with the increase of proppant injection intensity.Sixth,as the included angle between the borehole trajectory and the direction ofmaximumhorizontal principal stress increases,the tested gas production per kilometer of stimulated section overall presents an increasing trend.When the hydraulic fracture is nearly perpendicular to the borehole,the effective drainage area is the largest and the tested gas production per kilometer of stimulated section is also the highest.In conclusion,the fracturing mode of high production well has a borehole trajectory of large included angle,perforation cluster spacing of 10 m or so,proppant injection intensity of 5 t/m and large-displacement slick water+continuous injection of combined particle size proppant.
基金supported by the National Major Science and Technology Project“Experimental Evaluation of Spatial Characteristics and Seepage Law of FracturedPorous Reservoir”(No.:2016ZX05052-002-001)National Major Science and Technology Project“Invasion Mechanism of Fractured-Porous(Cave)and Bottom Water Gas Reservoir and Its Impact on Gas Reservoir Stability and Recovery”(No.:2017ZX05030-003-003-001)China National Petroleum Corporation Scientific Research and Technology Development Project(No.2016B-1501).
文摘Tight sandstone gas reservoirs commonly contain water,so liquid loading often appears near wellbores,leading to production decline and even shutdown of gas wells.Therefore,the study on the change of water saturation near wellbores is of great significance to understanding the water production mechanisms of gas wells.In this paper,a set of physical simulation experiment procedures of identifying the change of water saturation near wellbores was designed according to the principle of radial well seepage of gas wells,and the production performance after vertical well fracturing in gas reservoirs was simulated by connecting tight cores with a diameter of 10.5 cm,3.8 cm and 2.5 cm in series in a descending order of distance.According to the depressurizing production mode of gas wells,tubes with small diameters of 20,30,40 and 50 mm were used to simulate gas well tubing to control the gas production rate.And the change of water saturation near wellbore in the process of depletion production and its influencing factors were investigated.Finally,combined with actual data of production wells,the water saturation and water production of gas wells near wellbores and in different zones were calculated at the above four different small diameters of tubes and the changes thereof were also analyzed.The following results were obtained.First,each gas production rate corresponds to a critical water saturation.When the initial water saturation is lower than the critical value,the formation water flowing near the wellbore and in the middle zone can be carried out along with the production of gas and no liquid loading is formed.Second,when the initial water saturation is higher than the critical value,a large amount of formation water migrating from the far-wellbore zones accumulates near the wellbore,and thus liquid loading occurs at the bottom hole.Third,when the initial water saturation is equal to the critical value,the higher the gas production rate is,the more easily liquid loading tends to form near the wellbore.Fourth,for the same water saturation,water production increases and recovery factor decreases with the increase of gas production rate.In conclusion,the cumulative water production chart of a gas well generated by the physical simulation experiment method proposed in this paper agrees well with the water production behavior of the corresponding gas well.The research results are conducive to the effective prediction of gas well water production and can be used as guidance for the reasonable gas well water control.
基金the financial support of the National Natural Science Foundation of China(Grant No.52304018)China Postdoctoral Science Foundation(Grant No.2023TQ0014,Grant No.2023M730088)。
文摘Injecting CO_(2)when the gas reservoir of tight sandstone is depleted can achieve the dual purposes of greenhouse gas storage and enhanced gas recovery(CS-EGR).To evaluate the feasibility of CO_(2)injection to enhance gas recovery and understand the production mechanism,a numerical simulation model of CS-EGR in multi-stage fracturing horizontal wells is established.The behavior of gas production and CO_(2)sequestration is then analyzed through numerical simulation,and the impact of fracture parameters on production performance is examined.Simulation results show that the production rate increases significantly and a large amount of CO_(2)is stored in the reservoir,proving the technical potential.However,hydraulic fractures accelerate CO_(2)breakthrough,resulting in lower gas recovery and lower CO_(2)storage than in gas reservoirs without fracturing.Increasing the length of hydraulic fractures can significantly increase CH4production,but CO_(2)breakthrough will advance.Staggered and spaced perforation of hydraulic fractures in injection wells and production wells changes the fluid flow path,which can delay CO_(2)breakthrough and benefit production efficiency.The fracture network of massive hydraulic fracturing has a positive effect on the CS-EGR.As a result,CH4production,gas recovery,and CO_(2)storage increase with the increase in stimulated reservoir volume.
文摘Exploration and development practices have proved that staged volumetric fracturing stimulation in horizontal wells is a key technology for tight sandstone gas development,and reservoir sweet spot is an important basis for the perforation position selection and staged fracturing in the process of well location deployment and reservoir stimulation.Tight sandstone reservoirs are usually characterized by sandstone and mudstone interlayers with different thicknesses,and complex natural fracture distribution and geostress state.It is hard to predict“geological-engineering”dual sweet spots,and these two kinds of sweet spots are usually in different zones.As a result,there lacks a basis for the optimization of fracturing parameters to stimulate tight sandstone reservoirs.This paper establishes a geological sweet spot prediction model which takes into account total hydrocarbon content,reservoir porosity and other factors,then puts forward a 3D multi-scale engineering sweet spot evaluation method which takes into account lithology,fracture morphology,fracture mechanical behavior,and dilatation and shear dilation effect,andfinally a“geological-engineering”dual sweet spot evaluation model for tight sandstone reservoirs.Two wells in the tight sandstone gasfield in the Linxing Block of the Ordos Basin were selected as a case,and the dual sweet spot profiles,fracturing pressure and SRV were compared and analyzed.The results show that:1)shear dilation angle influences the distribution of engineering sweet spots at the most in the study area,followed by dissipated energy,elastic modulus and fracture energy;2)the geological sweet spot zone with a high coefficient is not necessarily the pay zone with high shale gas production;3)the engineering sweet spot zone with a high coefficient needs lower fracture pressure and can be stimulated relatively sufficiently;4)high-quality geological sweet spots and high-quality engineering sweet spots are poorly consistent in spatial location.In conclusion,the stimulation of tight sandstone gas reservoirs shall take geological sweet spot as the basis and engineering sweet spot as the guarantee,and the distribution of dual sweep spots should be considered comprehensively.The multi-scale“geological-engineering”dual sweet spot evaluation method proposed in this paper provides important technical support for the prediction of sweet spots of the tight sandstone gas and the optimization of development schemes in the study area.
基金Project supported by the Key Program of the National Natural Science Foundation of China“Basic Research on Drying of Tight Gas Reservoirs and Improvement of Gas Seepage Capacity”(No.51534006).
文摘The reservoir permeability of tight sandstone gas reservoirs is low,which makes it difficult to carry out displacement flow experiments on real cores underground conditions,so the microscopic flow mechanism can be hardly studied.Based on the lattice Boltzmann method(LBM),this paper simulated the flow process of formation water displaced by tight gas under the simulated reservoir conditions of high temperature and high pressure to clarify the distribution of bound water in the reservoir.Then,reservoir drying was experimentally studied using the laser etching model,and numerical simulation of reservoir drying was simplified by referring to the visualization results of the experiment.Finally,the influence of reservoir drying on the seepage capacity of tight gas was studied by means of numerical simulation.And the following research results were obtained.First,when the lattice Boltzmann model is used for high temperature and high pressure reservoirs,it satisfies the Laplace law and its numerical solution of two-phase Poiseuille flow rate is basically consistent with the analytical solution,which indicates that this model can be used to simulate gasewater immiscible displacement under reservoir conditions.Second,tight gas preferentially breaks through in large porous media connected channels,and after the breakthrough,the displacement rate of formation water decreases significantly.Third,the contact angle between formation water and rock wall has a significant influence on gasewater two-phase flow.The stronger the water wettability of the rock is,the lower the displacement rate is.Fourth,the bound water in tight sandstone gas reservoirs can be classified into four types,including adsorbed water film,blind end pore water,dead pore water and trapped water.In porous media,a large number of connected microchannels are occupied by trapped water and adsorbed water film and the phenomenon of“water lock”is obvious,which seriously influences the seepage capacity of tight gas in the porous media of reservoir.Fifth,drying agent can react with bound water to produce a large number of bubbles,which will consume adsorbed water film,trapped water and blind end pore water,so as to improve the gas seepage capacity.Sixth,in the“water lock”regions formed by trapped water,the gas seepage capacity can be effectively improved by increasing the drying strength.On the whole,the tight gas permeability increases with the increase of drying strength,but its increase amplitude decreases gradually when the drying strength exceeds a certain degree.
基金Project supported by the National High-tech Research and Development Plan(863 Program)project“new technology for shale gas exploration and development”(No.:2013AA064501)Shaanxi Science and Technology Research and Development Plan project“Natural gas exploration and development innovation team of Shaanxi Yanchang Petroleum”(No.:2015KCT-17).
文摘The Yan'an Gas Field is located in the southeastern part of the Ordos Basin,and its low-permeability tight sandstone gas reservoirs are characterized by thin reservoirs,poor physical properties and complex overlapping relationships.In addition,its surface is loess tableland,which makes it difficult to predict reservoirs by using seismic data.As a result,existing engineering technologies for gas field development cannot support the efficient development of this field.In order to optimize the development methods and technologies of the Yan'an Gas Field,the Yanchang Petroleum(Group)Co.Ltd.has developed to a set of key technologies suitable for the benefit development of this field concerning reservoir prediction,well pattern optimization,drilling and completion,reservoir protection,fracturing stimulation and ground gathering and transportation after nearly ten years of theoretical and technical researches.First,an effective reservoir prediction technology based on dynamic knowledge base was developed.It improves the drilling ratio of effective sandbody dramatically and achieves the accurate tracking of stable single sandbody in the range of 3-5 m.Second,a three-dimensional exploitation mode of hybrid well pattern based on the irregular diamond-shaped well pattern was established.It includes the multi-layer commingled production of cluster well and the single-layer production of horizontal well.Compared with regular well patterns,the well number is reduced by 6.9%and well pattern control is increased by 8%.Third,high-efficiency drilling technology for vulnerable reservoirs with collapse and leakage in the same well was developed.It improves wellbore wall stability,shortens drilling cycle and protects reservoir.Fourth,the multi-layer long-span fracturing of vertical/directional wells in one operation and the CO_(2)and hydraulic fracturing treatment of horizontal wells were realized to improve single well production significantly.Fifth,the medium-pressure gathering and transportation system in loess tableland with downhole throttling,branch-on-branch inter-well tandem and centralized alcohol injection as the core technologies was established.It reduces workload,shortens construction cycle and improves economic benefit.In conclusion,these development technologies play a crucial role in the development,appraisal and productivity construction of the Yan'an Gas Field.Through the application of these key technologies,the benefit development of this field is realized with an annual natural gas production capacity of 50×10^(8)m^(3).Furthermore,they are conducive to the enrichment and development of the theories and technologies for developing tight sandstone gas reservoirs in China,and they can be used as a reference for the development of similar gas fields.
基金supported by National Major Science and Technology Project“Demonstration Project of Large Low-Permeability Lithologic Reservoir Development in Ordos Basin”(No.:2016ZX05050)CNPC Science Research and Technology Development Project,China“Research and Application of Key Technology for Sustainable,Efficient and Stable Production of Changqing Oilfield at 50 Million Tons”(No.:2016E-0509).
文摘The sandstone layers of the Upper Paleozoic tight clastic gas reservoirs in the Ordos Basin are generally distributed in a pattern of nearly NS strip,and the channel branches and intersects frequently.A single sand body is in a multilayered contact mode resulted from lateral accretion,and the sand bodies at the river intersections present a feature of lying in the nearly EW direction,which brings great difficulties to the geosteering of horizontal wells.In order to improve the reservoir drilling rate of horizontal wells,this paper systematically analyzed the geosteering status of horizontal wells and the sedimentary characteristics of reservoirs.Then,the spatial distribution of reservoirs was predicted using 3D geological modeling and 3D seismic.In addition,based on the cognitions on the space distribution of sand bodies from the drilled horizontal wells,the horizontal well geo-steering technology and method were constantly improved and enriched.Thus,an integrated steering technology of“fine sublayer correlation for target entering,geology in small scale,and seismic in large scale”based on in-depth integration of multidisciplinary thinking was newly formed,and it was also applied on site.And the following research results were obtained.First,under the guidance of the sedimentation model,the target entering process is controlled precisely and the success rate of one-trip target entering is improved,so it is one important method for the target steering of deviated hole sections.Second,geological modeling can guide the drilling of horizontal wells,but to some extent,it is deviated from the real underground geologic bodies,so it can be used as an auxiliary horizontal-well steering method.Third,3D seismic steering can tell the boundary of complex river channel and discriminate the spatial relative location of predominant sand bodies,so it is the primary method for horizontal-well steering to provide excellent judgment and guidance on the steering of horizontal hole sections.Fourth,owing to the application of this new method in 62 horizontal wells drilled in the tight gas demonstration area,the average horizontal section length reaches 1430 m,the average sandstone drilling rate is 86.2%,the average gas layer drilling rate is 70.2%,and the gas layer drilling rate of horizontal wells is increased by more than 10%.
