48 results about "Conglomerate" patented technology

The invention discloses a construction method of cast-in-situ piles constructed by electric drill and rotary drilling relay drill, which includes two stages of construction preparation and construction operation; the construction preparation stage includes: 1) construction technology preparation stage; 2) site preparation stage; 3), mud preparation and circulation stage; 4), construction machinery, raw material preparation. Using this construction method mainly improves the utilization rate of machinery, speeds up the speed of hole formation, and shortens the time of hole formation. Electric drill construction in soft soil layer is more economical than rotary excavation pile machine, and the speed is faster than rotary excavation. The depth of rock penetration is difficult to judge and other problems. According to the construction records of the pile test stage, the electric drill has a footage of about 30cm/hour in the 5-1 weakly cemented conglomerate layer, and the 5-2 medium cemented conglomerate layer has a footage of about 10cm/hour, and the speed of the rotary pile machine in the 5-1 weakly cemented conglomerate layer is about 100cm / hour, the speed of 5‑2 medium cemented conglomerate layer is about 50cm/hour, and the speed is greatly improved.

The invention discloses a conglomerate full-diameter rock core radial flow oil-water relative permeability measuring device and method. According to a conglomerate full-diameter rock core radial flowoil-water relative permeability measuring experimental device, an experimental process and an experimental data processing method, the radial seepage process of the oil and water near a wellbore underthe formation temperature and pressure can be accurately simulated, and the radial seepage oil and water relative permeability of the conglomerate full-diameter rock core is measured. The experimental device comprises a vacuumizing system, a pressure supply system, a simulated reservoir module and a produced liquid metering system. The experimental process comprises the following steps of full-diameter rock core pretreatment, rock core absolute permeability determination, rock core vacuumizing and water saturation, an oil displacement water method rock core saturated oil experiment and the water displacement oil unsteady state method oil-water relative permeability measurement experiment. The data processing method is a full-diameter rock core radial flow oil-water relative permeability curve calculation method derived on the basis of a Darcy formula, a B-L radial seepage equation, a flow function G and the like.

The invention provides a horizontal well refracturing simulation method for a compact conglomerate oil reservoir. The method comprises the following steps: establishing a geologic model according to oil reservoir data; obtaining an initial fracture network model through UFM fracture propagation simulation, and obtaining a final fracture simulation fracture network form through correction; establishing an unstructured grid numerical simulation model and performing correction through production dynamic simulation; optimizing a water injection scheme through water injection energy increasing simulation, and optimizing soaking time through four-dimensional geological modeling based on the optimized water injection scheme; establishing a fracture network model after refracturing; and establishing a numerical simulation model after refracturing and carrying out refracturing production dynamic simulation. According to the method, the existence of multiple groups of micro-scale natural fracture equivalent gravels is adopted, so that fracture expansion better conforms to the conglomerate oil reservoir; through four-dimensional crustal stress modeling, crustal stress models at different time points are established, and a basis is provided for determining a conglomerate oil reservoir water injection scheme and soaking time after water injection, namely, when to carry out refracturing work according to crustal stress recovery conditions.

The invention discloses a conglomerate granularity evaluation method based on CT three-dimensional model reconstruction, and the method comprises the following steps: S1, selecting a conglomerate sample with the diameter of 10-100 mm, and carrying out the CT three-dimensional scanning of the selected conglomerate, and obtaining a two-dimensional gray image and a three-dimensional digital core data body of the conglomerate sample; S2, performing image processing on the two-dimensional grayscale image, eliminating image noise and enhancing the contrast ratio of conglomerate and a matrix in the image; S3, gravel in the image is extracted and segmented; S4, calculating the diameter of each gravel and constructing a three-dimensional model of the gravel; and S5, carrying out particle size analysis on gravels and interstitial substances in the conglomerate. Under the condition that a rock sample is not damaged, the size and the distribution of the gravel in the glutenite are conveniently and reliably analyzed, the three-dimensional space distribution characteristics of the gravel structure are visualized, a new method is provided for quantitative analysis of the size and the distribution of the gravel diameter, and meanwhile the application of the digital core technology in particle size analysis is expanded.

The invention provides a conglomerate reservoir evaluation method based on gravel component analysis. On the basis of conglomerate gravel component analysis, microscopic characteristics (gravel components and surface porosity) and macroscopic characteristics (reservoir pore permeability and oil and gas productivity) of a conglomerate reservoir are combined, and the control effect of the conglomerate gravel components on an oil and gas reservoir is discussed, so that a correlation between the gravel components and reservoir physical properties and oil and gas productivity is established. The conglomerate reservoir evaluation method based on the gravel component analysis is a direct reservoir geological evaluation method and can accurately and conveniently evaluate the conglomerate reservoir without depending on geophysical logging information, so that the exploration and development of the conglomerate oil and gas reservoir are accurately and quickly guided.

The invention belongs to the technical field of well logging in the petroleum exploration and development industry, and particularly relates to a well logging sandy conglomerate lithology fine evaluation method based on electric imaging. The evaluation method is more reliable in evaluation mode and more accurate in calculation result. The evaluation method comprises the following steps of carryingout blank strip filling preprocessing on a two-dimensional static micro-resistivity scanning image; carrying out edge detection on conglomerate particles in the image subjected to the filling preprocessing, and segmenting out the conglomerate particles from a background; according to geological deposition constraint conditions, carrying out region merging and splitting on the segmented conglomerate particles; and calculating a particle size spectrum and a lithology curve based on a sliding window and the particle size.

The invention discloses an experimental device and method for simulating a casing damage process, and relates to the field of petroleum engineering rock mechanics. The experimental method comprises the steps: a rock test piece for simulating a stratum is manufactured, the rock test piece sequentially comprises a shale layer, a conglomerate layer and a mudstone layer; a fault is prefabricated in the manufacturing process of the rock test piece; a shaft is drilled in the rock test piece, the shaft penetrates through the fault, and a casing is mounted in the shaft; in the process of applying thetriaxial pressure, data of a displacement deformation sensor and data of the triaxial pressure applied to the rock test piece are recorded; and the rock test piece is taken out, the casing is taken out to observe and record the damage conditions of the casing and a cement sheath, and the influence of the rock stratum stress difference on casing damage is analyzed according to the damage conditionsof the casing and the cement sheath, the data of the displacement deformation sensor and the data of the triaxial pressure applied to the rock test piece. The casing damage process can be simulated,factors causing casing damage are analyzed, and finally prevention and treatment of the casing damage problem of the oil-gas well of the oil field are achieved.

The invention discloses a high-fidelity heterogeneous conglomerate artificial core and a manufacturing method thereof.The manufacturing method includes the steps that S1, local air setting sand, local riverbed sand and quartz powder of different particle fractions are mixed to form mixed sand, formation water of a corresponding stratum is added into the mixed sand and stirred to be uniform, and the mass of the formation water accounts for 2-15% of that of the mixed sand; s2, uniformly mixing a diluent, epoxy resin, a plasticizer and a curing agent to prepare a cementing agent; the mass of the epoxy resin is 4-12% of the mass of the mixed sand, the mass of the plasticizer is 6-17% of the mass of the epoxy resin, the mass of the curing agent is 5-15% of the mass of the epoxy resin, and the mass of the diluent is 15-65% of the mass of the epoxy resin; and S3, adding the cementing agent into the mixed sand, uniformly stirring, pressing in a mold, and molding to obtain the artificial rock core. The manufactured artificial rock core is closer to a natural rock core, so that the accuracy of an indoor simulation experiment is improved.

The invention provides an oil reservoir development mode optimization method based on starting pressure under a flow coefficient. The method comprises the steps of calculating the flow coefficient, testing starting pressure gradients of different fluids injected into rock cores with different permeability rates, establishing a flow coefficient-starting pressure gradient curve, and selecting reasonable development modes for different types of oil reservoirs according to test results. According to the method, the physical properties of a reservoir and the properties of the fluids are consideredat the same time, and the application range is wider (including various development methods such as water flooding, gas flooding and chemical flooding). The method can be used for evaluating the starting pressure gradients of different flow coefficients under the conditions of different low-permeability reservoir rock cores and different types of injected fluids. Meanwhile, the method is not onlysuitable for sandstone oil reservoirs, but also suitable for lithologic oil reservoirs such as low-permeability carbonate rock, conglomerate and shale, the application range is wide, and a quantitative basis is provided for optimization of different types of oil reservoir development modes, selection of the technical direction of improving the recovery efficiency and judgment of the permeability limit of the low-permeability oil reservoirs suitable for different injected fluids.

The invention discloses a method for identifying a conglomerate oil layer through resistance reduction rate based on a clay type, and belongs to the field of oil and gas reservoir logging evaluation.The method for identifying the conglomerate oil layer through the resistance reduction rate based on the clay type is characterized in that based on the fact that clay in a reservoir is the same as clay in an adjacent mudstone layer in type, the influence on resistivity of the reservoir and resistivity of the mudstone layer is in the same direction, the resistance reduction rate obtained by dividing the resistivity of the reservoir and the resistivity of the mudstone layer removes the influence of the clay, and based on a resistance increase rate theory of an Archie formula, the porosity is evaluated by combining density logging so that the conglomerate oil layer can be accurately identified. According to the method for identifying the conglomerate oil layer through the resistance reduction rate, the limitation of identifying the conglomerate oil layer by using the resistance increase rate is overcome, the influence of the clay on the reservoir resistivity is effectively eliminated, the conglomerate oil layer can be accurately identified by using the resistance reduction rate in combination with density logging, and the chart application coincidence rate is 100%.

The invention relates to an oil sand interlayer quantitative recognition method and system based on electric imaging logging. The method comprises the steps that electric imaging logging data are preprocessed; two parameters of longitudinal and transverse difference variance of the 192 curves are calculated based on 192 curves of electric imaging logging; logging response characteristic analysis is carried out on the seven lithology, and lithology sensitive parameters are selected; respectively reading natural gamma, lithology density, photoelectric section indexes, longitudinal difference variance and transverse difference variance values corresponding to the seven lithology on the basis of rock core lithology, and establishing a lithology identification model by utilizing a support vector machine in a classified manner; taking natural gamma, lithologic density, a photoelectric section index, a longitudinal difference method and a transverse difference variance value as input curves;and calling a lithology identification model, utilizing a support vector machine to classify and identify lithology, dividing the types of the mud conglomerate through the mud content, and taking themud conglomerate with the mud content of more than 30% as an interlayer to realize quantitative identification of the oil sand interlayer based on electric imaging logging.

The invention discloses a conglomerate reservoir hydrofracture complex fracture extension trajectory prediction method, which comprises the following steps: generating a square servo boundary, and randomly generating a matrix particle model in the servo boundary; generating a gravel profile in the matrix particle model; defining the matrix in the gravel contour as a gravel particle cluster, and respectively assigning the mesomechanics parameters of matrix particles and gravel particles; gravel edge contact on the gravel contour is obtained by writing a traversal function; establishing a pipe domain seepage model, carrying out fluid-solid coupling, giving an injection rate, and establishing a crack extension criterion; gravels with different cementation strengths and crack extension tracks under the gravel edges with different cementation strengths are simulated by changing microscopic mechanical parameters of gravel particles and gravel edges. The method has the following beneficial effects that complex geometrical shapes and irregular outlines of gravels and different cementing strengths of gravel edges are fully considered, and the process of generating complex cracks when hydrofracture cracks meet the gravels can be further known.

The invention discloses a fluid identification method and device. The method comprises the steps: determining a classification critical value of the content of acid minerals used for classifying conglomerate reservoirs, classifying the conglomerate reservoir according to the classification critical value and the content of acidic minerals in the conglomerate reservoir to obtain a conglomerate reservoir classification result, establishing an acid mineral content and resistivity cross plot corresponding to the conglomerate reservoir classification result, and identifying the fluid type in the conglomerate reservoir according to the acid mineral content and resistivity cross plot. According to the method and device, the technical problem that the fluid containing the acid mineral conglomeratecannot be accurately judged in the prior art is solved.

The invention discloses a method and a device for determining a rock modality. The method comprises the steps of: acquiring preset modal parameters of a conglomerate reservoir micro-pore structure and rock pore structure parameters of a typical core rock sample, wherein the preset modal parameters are obtained according to different types of rock modal assumptions in advance; according to a preset correlation, determining target pore structure parameters related to the preset modal parameters, wherein the preset correlation is used for reflecting correlation between the preset modal parameters and the rock pore structure parameters; performing multiple linear regression calculation on the target pore structure parameters and the preset modal parameters to obtain a multiple linear regression equation; and on the basis of the regression result of the multiple linear regression equation, determining the rock modality of the conglomerate reservoir microcosmic pore structure, wherein the rock modality comprises one of a single modality, a double modality and a complex modality. The technical problem that the conglomerate reservoir pore structure modality identification method in the prior art cannot effectively identify the conglomerate reservoir pore structure modality is solved.

The invention relates to an ultra-low permeability tight reservoir fracture-pore type core preparation and saturated oil experiment method which sequentially comprises the following steps: (1) selecting a proper ultra-low permeability tight reservoir core, and performing axial and circumferential treatment; (2) cleaning and drying the rock core; (3) placing the rock core in a middle holder for vacuumizing and saturation; (4) wrapping the saturated rock core by using tetrafluoroethylene heated by a high-temperature drying gun, and forming a crack by using crack forming equipment; (5) the finally obtained rock core is saturated again through the rock core holder, and the liquid phase permeability of the rock core is obtained; and (6) obtaining the matrix saturation and the oil saturation according to the provided calculation formula. According to the method, the difficulty that the core matrix part of the fractured ultra-low permeability tight reservoir core cannot obtain sufficient saturated oil after fracture forming is solved, and a more accurate oil saturation mode and an oil saturation calculation formula of the method are provided for oil field development of fractured glutenite.

The invention provides an impact instability judgment method for an asymmetric island working face. The impact instability judgment method comprises the following steps of (S1) obtaining the spatial distribution characteristics of overlying strata of the working face, and revealing the control influence of conglomerate on the movement of the overlying strata on the working face through a micro-seismic monitoring result; (S2) dividing the earth surface into three types of areas, analyzing stress transfer rules of overlying strata in different areas to the island working face, and establishing an average bearing pressure estimation model; and (S3) establishing a relation among the equivalent mining depth, the damage degree of the working face and the average bearing pressure of the working face, and judging the possibility of impact instability of the working face according to the relation. The invention further provides an anti-impact mining method for the asymmetric island working face. According to the method, the asymmetric island working face in the condition of the huge thick conglomerate is used as a research object, and the relation among the equivalent mining depth, the damage degree of the working face and the average bearing pressure is put forward and is used as the basis for judging the danger degree of the working face, so that safe mining of the working face is effectively guaranteed.

The invention relates to the technical field of petroleum and natural gas exploration and development, and discloses a method for evaluating a conglomerate reservoir in a tectonic extrusion area. The method for evaluating the conglomerate reservoir in the tectonic extrusion area comprises the following steps: selecting a coring well with complete conglomerate drilling data at different tectonic extrusion positions in a research area, and collecting geological data related to the scheme as much as possible, including core logging data, core samples, casting body slices and actually measured pore permeability data; the number and name of wells with drilling coring are determined. An evaluation standard of the conglomerate reservoir in the tectonic extrusion area is established according to the relationship between the content of corroded gravel and the content of broken gravel which are microcosmically counted in the conglomerate reservoir, and a basis is provided for prediction and evaluation of the quality of the conglomerate reservoir in a similar area, so that a logging information evaluation result is always very small in difference from actually measured pore permeability data of a rock core; the method has a great effect in the aspect of predicting a high-quality conglomerate reservoir in a tectonic extrusion area, does not damage a precious rock core, and is relatively low in testing cost, so that the method can be popularized in a large area.

The invention relates to an evaluation method and a correction method of a conglomerate stratum rock abrasiveness parameter. The evaluation method and a correction method comprises the following steps: calculating abrasiveness parameters of a rock sample according to logging data of the rock sample, wherein the logging data comprises density logging data, resistivity logging data, neutron porosity logging data, natural gamma logging data and acoustic logging data. According to the method, density logging information, resistivity logging information, neutron porosity logging information, acoustic logging information and natural gamma logging information are used for directly evaluating the rock abrasiveness parameters of the conglomerate stratum, calculation is easy and convenient, cost is low, and the method has important significance on conglomerate stratum drill bit type selection, efficient rock breaking drilling and cost reduction and efficiency improvement of drilling engineering.

The invention provides concrete with high anti-seismic property and a preparation method thereof, and relates to the technical field of concrete materials. The concrete with the high anti-seismic property is prepared from the following raw materials in parts by weight: 400 to 450 parts of volcanic ash cement, 1180 to 1225 parts of coarse aggregate, 80 to 100 parts of coarse sand, 300 to 320 parts of medium sand, 130 to 160 parts of fine sand, 50 to 70 parts of nano calcium carbonate, 60 to 80 parts of zeolite powder, 20 to 25 parts of water reducing agent, 0.1 to 0.15 part of air entraining agent, 180 to 200 parts of purified water, 0.25 to 0.3 part of sodium polyacrylate, 0.09 to 0.1 part of repairing liquid and 0.1 to 0.12 part of waterproof coating. The impact crusher is used for crushing conglomerate, the content of needle-sheet-shaped aggregate is reduced, the toughness of the aggregate is guaranteed, the effectiveness of waterproof performance is guaranteed, the waterproof paint has good waterproof performance and elasticity and good anti-cracking effect, and if cracks occur in concrete, calcium carbonate is deposited at the cracks through calcium carbonate producing actinomycetes, so that the cracking resistance of the concrete is improved. The waterproof performance of the concrete can be kept for a long time.