32 results about "Conglomerate" patented technology

The invention relates to the technical field of oil-gas exploration logging interpretation and evaluation, in particular to a compact glutenite reservoir quality determination method based on pore structure factors. The method comprises the following steps: calculating the porosity POR through the density; the method comprises the following steps: performing correlation fitting analysis on permeability and pore structure parameters by using mercury injection data of a compact glutenite reservoir, screening out parameters with high correlation, and constructing a pore structure factor KX; performing rendezvous analysis on the pore structure factor KX and conventional logging data, screening out logging data with high correlation, and constructing a reservoir pore structure factor KX comprehensive classification evaluation model; calculating the shale content Vsh through a neutron-density intersection method; and establishing a reservoir classification evaluation standard by using the pore structure factor KX, the shale content Vsh, the porosity POR and the lithologic factor H, and determining the quality of the compact glutenite reservoir. The method has the advantage of high accuracy.

The invention relates to a low-permeability reservoir CO2 drive gas channeling channel identification method which comprises the following steps: S1, collecting geological data and production dynamic data of a target block well group, and calculating a gas channeling channel discrimination index; s2, calculating the weight of each gas channeling channel discrimination index; s3, calculating an onrush coefficient and correcting a boundary; s4, calculating a membership degree, and standardizing each gas channeling channel discrimination index according to the membership degree to meet the condition that the numerical value is between 0 and 1; s5, static and dynamic index comprehensive discrimination coefficients of the injection wells and the production wells are calculated; s6, calculating comprehensive weights of static and dynamic indexes of each injection well and each production well; s7, calculating a total discrimination coefficient; and S8, determining a three-level classification standard of the gas channeling channel, and judging the development direction of the gas channeling channel. The method solves the problem that an existing gas channeling channel identification method is low in accuracy of gas channeling channel identification due to the fact that the existing gas channeling channel identification method lacks research on a low-permeability conglomerate oil reservoir and does not fully utilize dynamic and static data.

The invention belongs to the field of gravel curtain layer reconstruction, and provides a gravel curtain layer reconstruction method which comprises the steps of stripping, screening, storage, improvement, reconstruction, watering and maintenance, and further provides a soil-stone separation device used in the gravel curtain layer reconstruction method, the soil-stone separation device comprises a separation tank, the top of the separation tank is open, a gravel flow guide bin covers the separation tank, and a sieve plate is rotationally arranged in the separation tank; the sieve plate is arranged in the separation tank and vibrates during rotation, the interior of the separation pipe is divided into a screening bin and a soil receiving bin in an up-down corresponding mode through the sieve plate, and the sieve plate can move upwards through a jacking mechanism so that the sieve plate can be moved out of the separation tank and separated objects can be thrown out all around through centrifugal force. The damaged gravel curtain layer is reconstructed, a crust layer is formed below the gravel layer, the wind erosion resistance can be greatly enhanced, it is guaranteed that strong wind erosion can be effectively resisted for a long time, and meanwhile gravel and original gravel curtain layer soil can be rapidly separated and stacked in a high-quality mode in the gravel curtain layer reconstruction period.

The invention belongs to the technical field of unconventional oil and gas development, and particularly relates to a gas-water-rock reaction and particle dissolution-migration in-situ visual quantitative determination method and device based on a micro-fluidic chip. The quantitative determination method comprises the following steps: firstly, designing a chip model containing a real rock core, wherein factors such as a strong heterogeneous structure of the compact conglomerate oil reservoir and strong difference of a pore throat structure are considered at the same time; then, the gas-water-rock reaction and the particle dissolution-migration process are recorded through an optical camera; and finally, analyzing contribution degrees of different minerals to a gas-water-rock reaction and judging different corrosion modes of the conglomerate by combining image processing software and a mathematical model. The method can be used for carrying out in-situ visual quantitative determination on gas-water-rock three-phase reaction, particle corrosion and a secondary migration process in the conglomerate reservoir under the conditions of oil reservoir temperature pressure and fluid chemistry.

The application relates to a method for evaluating a remaining gas sweet spot area of a compact sandstone conglomerate gas reservoir, and belongs to the technical field of oilfield development. The method comprises the following steps: using structures, sedimentary facies and a reservoir model to preferably select a static remaining gas potential area; using a numerical model current pressure and remaining gas abundance to determine a current remaining gas potential area; combining the dynamic and static conditions to preferably select a current remaining gas sweet spot area; carrying out numerical model scheme prediction, using cumulative production, daily production, pressure and remaining gas abundance to determine an optimal scheme; determining a future remaining gas potential area on a pressure and remaining gas abundance diagram predicted by the scheme; combining the dynamic and static conditions to preferably select a future remaining gas sweet spot area; taking the intersection of the current and future remaining gas sweet spot areas to determine a final remaining gas sweet spot area; and deploying a virtual well in the sweet spot area to verify the final remaining gas sweet spot area. The application defines a remaining gas sweet spot area selection method, determines a final remaining gas sweet spot area, and realizes systematic, accurate and rapid selection of a remaining gas sweet spot area of a compact sandstone conglomerate gas reservoir.

The present application relates to a kind of experimental device for studying the influencing factor of water transport rate of sandstone surrounding rock, the experimental device includes base, multifunctional container, three microwave moisture sensors, three micro-pressure transmitters, high-density electrical instrument and data collector.Multifunctional container is equipped with cover and base fence;The front end of base fence is equipped with sample support vertical plate, and the front of sample support vertical plate is equipped with sensor fixed column;Multifunctional container is square hole, and square hole is equipped with sealing buckle;Sealing buckle is inserted with rock sample in contact with square hole;Rock sample is equipped with three sensor layout ports, and is sleeved with three electrode fixed frame, and electrode fixed frame is equipped with copper screw with electrode line;Electrode line is connected with high-density electrical instrument;Three micro-pressure transmitters are in contact with rock sample;Rock sample is uniformly distributed with a plurality of platinum resistance on one side.At the same time, the present application also discloses test method.The present application can realize the influence degree of water transport rate in rock sample under the action of different factors.

The invention provides an electric imaging logging-based dense glutenite micro-crack automatic identification method, which comprises the steps of 1, preprocessing electric imaging logging original data, 2, carrying out interpolation restoration on blank stripes between polar plates in an electric imaging image, 3, carrying out sliding processing on a whole-well-periphery dynamic imaging image, and 4, carrying out sliding processing on the whole-well-periphery dynamic imaging image. The method comprises the following steps of 1, setting a feature extraction algorithm and corresponding different radiuses, 2, marking a training set, 3, setting a classifier, 4, training the classifier, 8, calculating parameters of the microcracks, and 9, generating a result map. The method provides powerful technical support for reservoir evaluation, exploration and development of compact glutenite.

The application discloses a kind of special low permeability sandy conglomerate reservoir well bottom flow pressure level keeping prediction method, including the statistical special low permeability sandy conglomerate body oil reservoir core sample's permeability and pressure sensitivity relationship data;Calculate the ratio of the permeability of rock sample under each level net confining pressure condition and the permeability tested under initial net confining pressure condition;Draw the relationship curve of net confining pressure value and permeability change rate;Predict the permeability loss ratio of reservoir near the bottom of production well with the increase of production pressure difference;Calculate production pressure difference, compare permeability classification data, calculate the permeability reduction ratio in the range of salt well bottom and the influence on fluid production rate.The application is mainly aimed at the production characteristics of the production well of special low permeability sandy conglomerate reservoir, explains the internal cause of its change, and provides development theoretical basis;It has guiding significance for the initial development mode, method and production pressure control of special low permeability sandy conglomerate reservoir.

The present application discloses a construction method for large-section rectangular pipe jacking in a cemented conglomerate stratum, comprising the following construction steps: arranging a pipe shed (1) on the outer contour of the top of an excavation cross-section to achieve support of the top of the excavation cross-section; dividing the excavation cross-section into a rock stratum region (2) and a soft soil region (3), arranging positioning drilling holes (4) in the rock stratum region, and arranging positioning grouting reinforcement holes (5) in the soft soil region; performing horizontal drilling in the rock stratum region on the basis of positioning points of the drilling holes, and after drilling of the drilling holes is completed, injecting a bentonite-slaked lime mixed slurry into the drilling holes to fill the drilling holes; performing horizontal high-pressure jet grouting pile construction at the grouting reinforcement holes in the soft soil region to achieve reinforcement of the soft soil stratum; and after treatment of the soft soil region and the rock stratum region is completed, using a pipe jacking machine to perform jacking along a jacking route. The present application enables smooth jacking construction in complex strata having abrupt stratum changes.

The invention discloses a glutenite physical property evaluation method based on XRF element logging. The glutenite physical property evaluation method comprises the steps of rock debris sampling, cleaning, drying and grinding; measuring rock debris element types and rock debris element contents by XRF (X-Ray Fluorescence) elements; establishing a quartz gravel content index based on the quartz gravel characteristic element Si, and calculating the quartz gravel content index; establishing a granite gravel content index based on the granite gravel characteristic elements Na + K, and calculating the granite gravel content index; establishing an interstitial filler content index based on the interstitial filler characteristic elements Ca + Mg and Al + Fe + Ti, and calculating the interstitial filler content index; establishing a glutenite physical property evaluation standard based on the relationship between the quartz gravel content index, the granite gravel content index and the interstitial substance content index of the drilled well and the glutenite physical property; and performing reservoir evaluation by using the established glutenite physical property evaluation standard, and the like. According to the invention, glutenite stratum physical property evaluation can be carried out in real time while drilling.

The invention discloses a compact glutenite lithology identification method and system, electronic equipment and a storage medium, and relates to the technical field of logging, and the method comprises the following steps: according to logging curve measurement data of an uncored well section of a target research area, a model formula of a quasi-skeleton difference factor and a model formula of an argillaceous characteristic factor, obtaining a lithology identification result of the uncored well section of the target research area; calculating to obtain the value of the quasi-skeleton difference factor of each logging sampling point of the uncored well section and the value of the shale characteristic factor of each logging sampling point; and determining the lithology of each logging sampling point of the non-cored well section according to the value of the quasi-skeleton difference factor of each logging sampling point of the non-cored well section, the value of the shale characteristic factor of each logging sampling point and a lithology identification standard. According to the method, the lithology of the non-cored well section can be judged and identified, and the problems of high application cost and low identification precision in the lithology identification process of the deep compact glutenite reservoir in the prior art are solved.

The application provides a conglomerate reservoir reservoir classification method, and belongs to the technical field of oil and gas development exploration, and solves the problem that the existing oil layer classification method cannot accurately predict the oil production and development potential of different wells. A conglomerate reservoir reservoir classification method comprises the following steps: calculating the static Young's modulus of all wells according to the measured longitudinal wave data of all wells, the measured transverse wave data of part of the wells and the measured static Young's modulus of part of the wells; obtaining the fitting relationship between the static Young's modulus and the rock brittleness index according to the measured mineral content data of part of the wells and the measured static Young's modulus of part of the wells; calculating the rock brittleness index of all wells based on the fitting relationship between the static Young's modulus and the rock brittleness index according to the static Young's modulus of all wells; and establishing the four-quadrant classification standard of the reservoir reservoir according to the rating parameters and the rock brittleness index of all wells, so as to determine the reservoir reservoir category.

The invention discloses a method for predicting a glutenite high-quality reservoir stratum, and the method specifically comprises the following steps: S1, seismic data interpretation processing: carrying out the frequency extension of seismic data based on a self-adaptive amplitude-preserving frequency extension technology, and obtaining amplitude-preserved high-resolution seismic data; s2, establishing a lithology identification plate: performing pairwise intersection on conventional logging curves by using a cross plot, performing sensitive factor intersection analysis, establishing the lithology identification plate, searching a sensitive curve capable of identifying a high-quality reservoir stratum, and in order to ensure high correlation between the curve and an earthquake, performing curve reconstruction to obtain a reconstructed characteristic curve; s3, model solving: establishing a low-frequency impedance model and a high-frequency reconstruction characteristic curve model D by using a model difference method; s4, initial reservoir stratum inversion: carrying out glutenite reservoir stratum prediction based on the high-resolution seismic data and the low-frequency impedance model to obtain an initial reservoir stratum prediction result; and S5, iterative inversion: based on the initial reservoir stratum prediction result and the high-frequency reconstruction characteristic curve model, carrying out nonlinear data combination on the initial reservoir stratum prediction result and the high-frequency reconstruction characteristic curve model, and finally obtaining an iterative inversion result. On the basis of the self-adaptive amplitude-preserving frequency-expanding technology, the self-adaptive molecular decomposition time-frequency analysis algorithm is introduced, the resolution of seismic data is improved, meanwhile, the predication method of the glutenite reservoir stratum is optimized, and the predication precision of the glutenite high-quality reservoir stratum is improved. The method is suitable for predicting the glutenite high-quality reservoir stratum.

The invention provides an experimental device and method for liquid injection energization after oil reservoir fracturing failure. The invention relates to a liquid injection energizing experimental device after oil reservoir fracturing failure. The liquid injection energizing experimental device comprises a core holder, a displacement device, a confining pressure device, a back pressure device, a bypass device and a nuclear magnetic resonance spectrometer, the rock core holder is provided with an accommodating cavity which is used for accommodating a rock core sample; the displacement device can inject fluid into the rock core sample, the confining pressure device is used for applying peripheral pressure to the rock core sample, the back pressure device is used for establishing reverse pressure at the second end of the accommodating cavity, and the bypass device is used for releasing the fluid in the accommodating cavity; the nuclear magnetic resonance spectrometer is used for measuring the relaxation time of the rock core sample. The real development process of the ultra-low permeability conglomerate oil reservoir is completely simulated, the reliability of experimental data is guaranteed, the liquid injection energy increasing oil displacement efficiency can be quantified, meanwhile, the utilization rule of crude oil in pores with different pore diameters is determined, and a comprehensive experimental basis is provided for parameter optimization of the liquid injection energy increasing process and screening of injected media.

This invention provides a method for efficient proppant delivery and placement in tight sandstone and conglomerate reservoirs, belonging to the field of unconventional oil and gas exploration and development technology. The invention includes the following steps: determining the surface roughness of the hydraulic fracture in the sandstone and conglomerate reservoir; determining the effective width of the hydraulic fracture based on the surface roughness; determining the sand transport index of the hydraulic fracture based on the effective fracture width; determining the hydraulic fracturing sand transport capacity index; and optimizing the sand transport parameters using dimensionless sand transport capacity. This invention can rapidly optimize proppant delivery and placement by utilizing hydraulic fracture parameters and hydraulic fracturing construction parameters, combining the sand transport capacity of the fracture itself with the sand transport capacity of the construction conditions. This provides a basis for optimizing fracturing schemes in tight sandstone and conglomerate oil and gas reservoirs, and is beneficial for improving the fracturing effect in tight sandstone and conglomerate oil and gas reservoirs.

The present application provides a kind of conglomerate reservoir fracture morphology prediction method and chart generation method, belong to the fracturing technical field of oil development.The present application constructs fracture propagation morphology model, establishes conglomerate reservoir fracture morphology prediction chart;According to conglomerate reservoir fracture morphology chart, determine whether the development form of hydraulic fracture is pressure post fracture development vertical fracture or horizontal fracture;For the area of vertical fracture development, collect the geological and mechanical parameters of the fracture that affects the vertical fracture development area and penetrates the layer;Fracture penetration expansion model considering reservoir and interlayer is constructed, and vertical fracture penetration chart is established;According to the collected geological and mechanical parameters of reservoir and interlayer, combined with vertical fracture penetration chart, determine whether hydraulic fracturing can penetrate interlayer.The fracture propagation morphology model constructed by the present application is more accurate, the fracture morphology prediction is more accurate, the selected fracturing operation mode is well matched with the geological characteristics of reservoir, the reservoir modification cost can be reduced, and the development benefit of oil field can be improved.

The present application belongs to the technical field of unconventional oil and gas development, and particularly relates to a gas-water-rock reaction and micro-particle dissolution-migration in-situ visualized quantitative determination method and device based on a micro-fluidic chip. The quantitative determination method designs a chip model containing a real core by simultaneously considering factors such as strong heterogeneity of a dense conglomerate reservoir, strong difference of pore throat structure and the like; then records the gas-water-rock reaction and micro-particle dissolution-migration process through an optical camera; finally, combines image processing software and a mathematical model to analyze the contribution degree of different minerals to the gas-water-rock reaction and to distinguish different dissolution modes of conglomerate. The method can quantitatively determine the gas-water-rock three-phase reaction, micro-particle dissolution and secondary migration process in a conglomerate reservoir under the conditions of reservoir temperature, pressure and fluid chemistry.

The invention discloses a glutenite oil-water layering identification method based on automatic machine learning, and relates to the technical field of oil-gas exploration oil-water layering algorithm identification. Comprising the following steps: acquiring geological logging characteristic data related to glutenite exploration and a corresponding oil-water layering interpretation conclusion; integrating the derivative features and geological logging feature data into a model training input feature set; determining a weight ratio of the feature to the model by adopting a weighting algorithm combining a feature weight and a model weight, selecting a machine learning model according to a data type, and training to generate a candidate model; meanwhile, weighting recall rate related indexes of an oil layer, a poor oil layer and the same oil-water layer are adopted as model evaluation standards, and an optimal model is obtained through screening; and performing oil-water layering identification on the reservoir of the target glutenite oil well by using the optimal model to realize division of an oil layer, a poor oil layer, an oil-water same layer and an oil-free layer. The automatic machine learning module is adopted to select the optimal hyper-parameters of the model, so that the generation efficiency and accuracy of the model are greatly improved.

The invention provides a gravel content-based glutenite effective porosity calculation method, and belongs to the technical field of oil and gas field development engineering.The method comprises the following steps of obtaining glutenite slice identification data, rock core data and formation testing result data of a target interval, determining the reservoir pore space type and development condition through rock core and slice observation, and calculating the effective porosity of glutenite according to the reservoir pore space type and development condition; acquiring porosity and permeability intersection results corresponding to different gravel contents of the target interval; reservoir parameters of the target interval are analyzed, and factors influencing conglomerate reservoir development are subjected to influence evaluation; sorting the factors influencing the development of the conglomerate reservoir according to the influence, and selecting the factors in preset sorting as the calculation basis of the porosity; and establishing an effective porosity calculation equation. The correlation between the effective porosity calculated according to the method and the permeability is good, and the effective porosity of the glutenite reservoir can be accurately identified, so that the physical property characteristics of the effective reservoir are accurately identified, and the method can be used for new well reservoir evaluation.

The present application provides a kind of based on Markov chain's sandstone and conglomerate source supply capacity quantitative prediction method, comprising: step 1, understand the basic geological profile of study area, carry out Cenozoic standard layer structural diagram interpretation;Step 2, determine the prediction object and initial state probability vector and time series vector, establish Markov prediction model;Step 3, apply statistical estimation method, establish one-step transition probability matrix;Step 4, realize multiple state probability prediction by one-step transition probability matrix;Step 5, based on source supply intensity factor K, establish the functional relationship between source supply intensity factor K and fan body advancing (retreating) distance.The sandstone and conglomerate source supply capacity quantitative prediction method based on Markov chain has high practical value, strong operability, high prediction result accuracy, and has significant progress compared with the traditional gentle slope zone sandstone and conglomerate source area source supply capacity quantitative prediction.

This invention relates to the field of oil and gas exploration, and particularly to a comprehensive source analysis method for near-source sedimentary systems based on geology and geophysics, comprising: S1, analyzing the anterior surface reflection structure and seismic facies characteristics of geophysical profiles to obtain the source distribution area; S2, collecting samples in the source distribution area, including field outcrop samples and well samples; S3, performing conglomerate distribution characteristic analysis and gravel composition analysis on the samples, and performing sandstone fragment type analysis on the sandstone in the samples; S4, based on the conglomerate distribution characteristic analysis, gravel composition and sandstone fragment type analysis, combined with geophysical root mean square amplitude attributes and wave impedance attributes, characterizing the sedimentary microfacies distribution map of channel sand bodies; S5, based on the sedimentary microfacies distribution map, performing paleocurrent analysis to further clarify the source direction of each well.

The application provides a sandstone and conglomerate OVT domain partitioned gather optimization stacking offset optimization method, which comprises the following steps: step 1, determining the fan body burial depth H and the fan body plan distribution map of the target layer in a research area; step 2, reasonably optimizing a real drilling well reconstruction time-depth relationship function formula A in the research area; step 3, calculating a fan body dip angle alpha; step 4, determining the maximum effective offset l2 of the reflection flat section of the target layer in the research area; step 5, calculating the minimum effective offset l1 of the target layer fan body in the research area; and step 6, obtaining the optimal gather stacking offset range l of the target layer fan body in the research area by comprehensively combining the step 4 and the step 5. The sandstone and conglomerate OVT domain partitioned gather optimization stacking offset optimization method can calculate the optimal offset range of the OVT domain partitioned gather optimization stacking of the target layer, and the obtained seismic data volume can better reflect the sandstone and conglomerate fan body distribution range and the effective reservoir development area.

This invention relates to the field of oil and gas extraction and discloses a method for determining target intervals suitable for hydraulic fracturing from tight conglomerate reservoirs. The method includes: acquiring stratigraphic and rock information of the tight conglomerate reservoir in the target area; classifying the tight conglomerate reservoir into multiple conglomerate types based on the stratigraphic and rock information; generating geological feature results corresponding to each conglomerate type based on the stratigraphic and rock information; and selecting the optimal conglomerate type from the multiple conglomerate types based on the geological feature results. The method provided by this invention can screen out the most suitable conglomerate type for hydraulic fracturing from multiple conglomerate types, achieving accurate prediction and screening of the most suitable conglomerate type for hydraulic fracturing.

The present application belongs to the technical field of oil exploration, and particularly relates to a method for well-seismic comprehensive fine delineation of sandy conglomerate. The method comprises the following steps: combining with a reservoir configuration division method, fine delineating a vertical sedimentary structure level of the sandy conglomerate; using a seismic sedimentology analysis method, well-seismic comprehensive delineating a spatial distribution of the sandy conglomerate, and clearly defining a spatial feature of a reservoir configuration unit in a target area; establishing a parameter knowledge base of an internal structure unit of the sandy conglomerate, and predicting a favorable reservoir development position in the target area. The method combines geological, logging and seismic fine delineation methods, finds an effective combination point, and applies the combined system method to a sandy conglomerate reservoir for verification, thereby establishing an effective well-seismic comprehensive fine delineation method of the sandy conglomerate. The method effectively overcomes the problems of complex internal structure of the sandy conglomerate and unclear marks.

This invention discloses a method, system, and terminal equipment for obtaining the grain size of sandstone and conglomerate. The method includes acquiring grain size experimental data from sandstone and conglomerate cores of different grain sizes; establishing sensitive logging curves for sandstone and conglomerate cores of different grain sizes based on the grain size experimental data; establishing a formula for calculating the sandstone and conglomerate content index based on the sensitive logging curves; establishing a formula for calculating the porosity index based on the sensitive logging curves; establishing a grain size index formula based on the sandstone and conglomerate content index formula and the porosity index formula; and establishing a grain size calculation formula based on the grain size index formula and the grain size experimental data. The grain size of sandstone and conglomerate of different grain sizes is obtained through the grain size calculation formula. This invention introduces the sandstone and conglomerate content index and the porosity index to establish a highly universal quantitative calculation model for sandstone and conglomerate grain size. Theoretically, this model better conforms to actual stratigraphic and petrophysical characteristics, has higher calculation accuracy and reliable theoretical basis, and is convenient, simple, versatile, and widely applicable.

The invention discloses a horizontal well reversed-sequence refracturing method and application, and belongs to the technical field of compact conglomerate oil reservoir transformation of petroleum engineering. According to the method, the communication condition of the old joint and the stratum is judged through trial extrusion, and sand plugging treatment is conducted on the old joint of the communicated stratum; the well is washed until the fracturing operation requirement is met, hydraulic sand blasting perforation operation is conducted, and oil sleeve annulus sand fracturing is conducted to form a new fracturing crack; and the oil sleeve annulus is cleaned, the relation between the sand discharging amount and the liquid amount is calculated, and a basis is provided for follow-up construction till fracturing operation of all workshop sections is completed. According to the method, the plugging effect is judged through peak-type lifting of construction curve pressure after trial extrusion, plugging is conducted in combination with an artificial sand plugging technology of fine sand and liquid amount control and multiple times of plugging, the plugging rate of the old seam of the horizontal well is increased, a new seam is manufactured through a hydraulic sand blasting perforation reversed-sequence staged fracturing technology, real-time and accurate transformation is achieved, an untransformed section of a remaining oil enrichment area is activated, and the plugging efficiency of the old seam of the horizontal well is improved. And the mining period is prolonged, and the single well EUR is remarkably improved.

The invention discloses a high-strength conglomerate carbonic acid saturation softening chiseling system and a construction method. The system comprises an inflation unit, a water injection unit, a sealing device and a monitoring control unit. The carbonation reaction is creatively introduced into conglomerate rock drilling pretreatment, CO2 reacts with water to form a carbonic acid saturation environment and reacts with carbonate minerals in conglomerate to reduce the rock stratum strength, self-adaptive regulation and control are achieved by integrating a multi-parameter sensor and a controller, and the softening effect is accurately controlled; a combined sealing device of a rubber expansion air bag and a mechanical sealing ring is adopted and matched with a pipeline switching valve set to achieve multi-hole linkage operation, and the construction efficiency is greatly improved. Besides, the ground exploration hole is directly used as an operation channel, blasting-free wetting operation is combined, the problems of construction limitation and dust and noise pollution in a complex environment are solved, and the method has the outstanding advantages of being environmentally friendly, efficient, accurate in control and safe in construction.

This invention discloses a method for predicting the productivity of igneous conglomerate tight sandstone and conglomerate reservoirs. The method involves classifying the reservoir into lithofacies, determining the lithofacies identification index for each lithofacies, performing grain size analysis, constructing a grain size identification index calculation model for the igneous conglomerate tight sandstone and conglomerate, obtaining the grain size identification index for perforated and fractured sections, calculating the porosity and permeability of the perforated and fractured sections, and performing depth-weighted processing on the logging parameters of the perforated and fractured sections to determine the fracturing engineering index, perforation section index, and fractured section index values. This establishes a productivity prediction model for igneous conglomerate tight sandstone and conglomerate reservoirs, and calculates the comprehensive productivity index to predict the productivity of a single well. This invention integrates the influence of lithofacies, grain size, reservoir properties, construction design, perforation, and fracturing on single-well productivity, achieving accurate prediction of the productivity of igneous conglomerate tight sandstone and conglomerate reservoirs.

This invention belongs to the field of oil and gas development technology and provides a method for determining the particle size of bridging particles for temporary plugging in conglomerate fractures based on lithofacies classification. The method includes: obtaining the characteristic parameter VG of gravel content through analysis of the gravel composition of full-diameter core samples from the target layer of the well or the same layer in adjacent wells; obtaining the strength comparison parameter RC by obtaining the strength of gravel and cement in the conglomerate reservoir samples through micron-level indentation tests; classifying the conglomerate into four categories based on RC and VG as the main controlling factors; cutting the full-diameter core into standard rock plates using a wire cutting device, splitting the rock plates using a Brazilian fracturing test device to prepare realistic fracture models, and obtaining the fracture morphology through laser scanning; obtaining fracture models of samples from different lithofacies through 3D printing; and conducting temporary plugging tests within fractures using the fracture models to obtain the most suitable bridging particle size for fractures under different lithofacies. This invention can achieve targeted temporary plugging within fractures of different lithofacies, improving the effectiveness of temporary plugging.

The present application relates to the technical field of complex oil and gas reservoir logging evaluation in oil exploration, and is a method for identifying fluid categories based on a storage index and apparent formation water resistivity variance, comprising: calculating gravel, sandy and argillaceous lithological component factors by using the results of conglomerate core analysis; calculating n formation rock porosities and n apparent formation water resistivities; obtaining the variance of the n apparent formation water resistivities; calculating a sorting coefficient and a heterogeneity factor; calculating a fracture porosity and a fracture factor; constructing a storage index and apparent formation water resistivity variance and storage index fluid identification chart, and determining an oil layer standard. The present application is a method for identifying conglomerate reservoir fluid categories based on an electrical imaging storage index and apparent formation water resistivity variance, overcomes the limitations of the porosity and oil saturation crossplot method based on the Archie formula and the difference spectrum method based on nuclear magnetic resonance, provides a new method for identifying conglomerate reservoir fluid categories, and the chart application coincidence rate is 100%.