60 results about "Matrix permeability" patented technology

The invention relates to a method and a device for predicting the capacity of a fissure-hole type oil deposit. The method includes the steps of acquiring oil deposit bubble point pressure Pb, a volumetric factor B, in-place oil viscosity mu, the shaft radius rw, the oil reservoir thickness h, matrix permeability Km, fissure permeability Kf, oil deposit supply boundary pressure Pe, the boundary radius re, shaft bottom flow pressure Pw, a matrix permeability damage factor alpha m, a double-medium reservoir permeability damage factor alpha A and fissure closing pressure Pf. Fissure-hole type double-medium reservoir permeability KA is obtained according to the matrix permeability Km and the fissure permeability Kf; on the basis of permeation fluid mechanics, the stratum fissure closed radius rf is obtained by the acquired parameters; on the basis of inner and outer boundary conditions and reservoir permeability stress sensitive effects, the relation between the capacity of the fissure-hole type oil deposit and shaft bottom pressure is obtained by the acquired parameters; and the capacity of the fissure-hole type oil deposit is predicted according to the relation between the capacity of the fissure-hole type oil deposit and the shaft bottom pressure.

The invention provides a staged fracturing yield prediction method of a low-permeability gas reservoir horizontal well, and belongs to the fracturing field of the low-permeability gas reservoir horizontal well in development of oil-gas fields. According to the method, horizontal well fracturing design is firstly carried out to obtain original data, then geological modeling is carried out according to the original data to obtain a geological model, finally area network refinement and fracturing crack simulation are carried out on the geological model, and therefore the yield of the horizontal well under different crack parameters is calculated. By combing FracProPT2007 and Eclipse, the staged fracturing yield prediction method of the low-permeability gas reservoir horizontal well can accurately capture the shapes of fracture cracks and flowing parameters of the fracture cracks in each position, can simulate the flowing of multi-layer and multi-phase fluid flowing into the cracks and flowing into a shaft from the cracks, and analyzes the influence of the geometic shapes of the cracks, the flow guide capacity, the crack positions, the interval, the included angle of the cracks, the base material permeability and other parameters on yield, and leakage of fracturing liquid and the flow-back process of the fracturing liquid are taken into account.

A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%. Similar methods using stepwise fracturing fluids and remedial fracturing treatments are provided.

The invention discloses a fracture-matrix permeability differential judgment method for a carbonate reservoir equivalent model. The fracture-matrix permeability differential judgment method comprises equivalent fracture single medium value simulated fracture-matrix permeability differential judgment, equivalent matrix single medium value simulated fracture-matrix permeability differential judgment, and equivalent double-porosity and single-permeability value simulated fracture-matrix permeability differential judgment. By the method, the historical matching and project forecast of various carbonate reservoirs with diversified reservoir stratums, complicated fracture and matrix matching relationships, large change of permeability differential, complicated oil gas and water relationships, large change of pressure distribution, large simulation blocks, complicated production histories and the like can be quickly realized.

The invention relates to a shale gas permeability tester. The shale gas permeability tester comprises a gas cylinder, a pressure regulating valve, a first pneumatic valve, a first pressure sensor, a second pneumatic valve, a second pressure sensor and an emptying valve which are sequentially connected through sealing pipelines, and the shale gas permeability tester further comprises a hand-operated valve, a model cup, a temperature sensor, a specimen cup and a thermostat. The invention further relates to a method for testing shale gas permeability. A shale core is crashed into particles with a certain shape, then the particles are placed in a thermostatic sealed container, pressure of the particles with change of time is recorded in real time after certain pressure is added in the container, and therefore the permeability of a shale base material is calculated. A test for the shale gas permeability is no longer affected by crack permeability, and the permeability of the shale base material can be accurately tested.

Methods, program code, computer readable medium, and apparatus estimating permeability at unsampled (uncored) but logged interval locations in a reservoir based upon a similarity with log signatures from cored intervals, are provided. An example of a method can include performing a core plug-by-core plug blind test, defining an objective function which qualifies the quality of the permeability prediction to minimize discrepancies between measured and predicted permeability, optimizing calculated parameters, and estimating permeability values of uncored logged intervals. The method can also include applying a debiasing / variance restoration to compensate for inherent averaging artifacts

The invention provides an imitation horizontal well waterflooding well pattern adapting method which comprises the steps that the optimal well pattern form is obtained through a numerical reservoir simulation method, and models with different included angles between fissures and a well array are established for simulation and prediction; the array spacing of the optimal well pattern form under different permeability conditions is optimized, and the optimal well array spacing is obtained under different permeability range conditions; the reasonable well pattern density is determined, the economical and reasonable well spacing is calculated, the well spacing is determined accordingly, and the fissures are made to adapt to the well spacing; numerical simulation is conducted, and the optimal fissure construction parameters matched with different matrix permeability, and the optimal injection-production parameters are obtained; and the technology for adaption of the well pattern, the fissures and water injection during waterflooding of the low-permeability reservoir imitation horizontal wells is formed. By adoption of the imitation horizontal well waterflooding well pattern adapting method, the optimal configuration for the imitation horizontal well injection-production well pattern, the artificial fissures and a working system is achieved, a technical guarantee can be provided for effective production and efficient development of low-permeability low-abundance reservoirs, and the imitation horizontal well waterflooding well pattern adapting method has wide popularization prospects.

A method of recovering hydrocarbons from a hydrocarbon-bearing subterranean formation with a matrix permeability of less than 1 mD is disclosed. The method includes injecting a volume of a first fluid having a viscosity lower than the viscosity of water into an injection well present in the formation; separately injecting a volume of a second fluid into the formation before, after, or before and after injecting the first fluid; and producing at least a fraction of the injected volume of the first fluid and hydrocarbons from the formation through a production well present in the formation.

The invention provides a fracture permeability computing method, comprising the steps of obtaining average fracture permeability according to well test permeability, matrix permeability and fracture porosity, wherein the well test permeability is obtained according to open-flow capacity; establishing a first computing model among the average fracture permeability, average fracture porosity and anaverage fluid movement index; calibrating the first computing model according to the well test permeability and establishing a second computing model among the fracture permeability, fracture porosityand the fluid movement index; and obtaining the fracture permeability according to the second computing model. According to the computing method provided by the invention, the fracture permeability and fracture effectiveness can be evaluated relatively accurately, so a fracture permeability computing result achieves well test precision.

The invention discloses a shear seam shale core pulse attenuation permeability testing method. The method comprises the following steps of: S1: establishing a dual-medium physical model of a shear seam shale core based on a multi-scale seepage model of gas in the shear seam shale core; S2: obtaining a finite volume discrete format corresponding to a physical model by using a finite volume method, solving a full-implicit solving format of the physical model by combining the Newton-Raphson iterative algorithm, and programming and solving the model; S3: performing a pulse attenuation experiment on the shear seam shale core by using a pulse attenuation method experiment device, and measuring a pressure and time relation curve of an upstream chamber and a downstream chamber by using the experimental data; and S4: combining the dual-medium physical model of the shear seam shale core, and acquiring the matrix permeability and the fracture permeability of the shear seam shale core by adopting a curve fitting method. The method can be used for testing the permeability of the shale core with the shear seam.

The invention provides a shale gas saturation determination method, device and equipment based on deep learning, and the method comprises the steps of obtaining the fracture permeability and target moment of a target stratum; converting the fracture permeability into equivalent matrix permeability to obtain equivalent permeability data of the target stratum; determining a target equivalent permeability field diagram of the target stratum according to the equivalent permeability data; and according to the target equivalent permeability field diagram and the target moment, determining a saturation field diagram of the target stratum at the target moment by utilizing a target deep convolution decoding network. In the embodiment of the invention, a solving problem of an uncertainty equation can be converted into a graph-graph regression problem by utilizing a target deep convolution solution coding network, and a relationship among a permeability field graph, a target moment and a saturation field graph is established. And the resolution of the image can be reduced through the target deep convolution decoding network, so that the calculation efficiency can be effectively improved, andthe technical effect of efficiently and accurately predicting saturation distribution is achieved.

A method of increasing the fracture complexity in a treatment zone of a subterranean formation is provided. The subterranean formation is characterized by having a matrix permeability less than 1.0 microDarcy. The method includes the step of pumping one or more fracturing fluids into a far-field region of a treatment zone of the subterranean formation at a rate and pressure above the fracture pressure of the treatment zone. A first fracturing fluid of the one or more fracturing fluids includes a first solid particulate, wherein: (a) the first solid particulate includes a particle size distribution for bridging the pore throats of a proppant pack previously formed or to be formed in the treatment zone; and (b) the first solid particulate comprises a degradable material. In an embodiment, the first solid particulate is in an insufficient amount in the first fracturing fluid to increase the packed volume fraction of any region of the proppant pack to greater than 73%. Similar methods using stepwise fracturing fluids and remedial fracturing treatments are provided.

The invention discloses a fracture simulation method for a fractured tight sandstone oil-gas reservoir. The method is characterized by comprising the following steps: step one: pressing a core model and laying gauze elements with different layer numbers at the middle part of the core model to simulate different fracture apertures; step two: determining the relationship between the gauze elements with different layer numbers and the fracture apertures; step three: determining the relationship between different placement directions of the gauze elements in the core model and the fracture strike;step four: determining the relationship between different layer numbers of the gauze elements and the fracture permeability. The method disclosed by the invention can simulate fractures with different fracture apertures, different branch numbers and different strikes in fractured oil and gas reservoirs; the simulated minimum fracture aperture can reach 0.08mm which fully reaches the micro-fracture level, while the maximum fracture aperture can be set according to needs; meanwhile, the matrix permeability can be as low as 0.1*10<-3>mu m<2> which reaches the ultra-low permeability level of a tight oil reservoir matrix, so that indoor simulation requirements of actual production conditions in the oil reservoir are met.

The invention discloses a testing method of a substrate permeation rate of a repeated fracturing plugging agent. The testing method comprises the following steps: (a) preparing the repeated fracturing plugging agent for future use; (b) selecting a plurality of rock core samples for future use; (c) cutting a selected rock core and making an artificial crack; (d) paving one layer of particle substances on a crack surface and simulating a fracturing crack; (e) injecting the repeated fracturing plugging agent into the simulated fracturing crack and standing for a period of time; (f) injecting liquid, determining the permeation rate and calculating the plugging rate; and (g) cleaning sand in the rock core and then firmly sticking the rack to determine the substrate permeation rate. According to the testing method disclosed by the invention, the substrate permeation rate of the repeated fracturing plugging agent can be rapidly detected; and the testing process is simple, the tested result is accurate, and the testing method provides data support to the utilization of the repeated fracturing plugging agent.

He invention discloses a method for calculating the permeability of a matrix after acid fracturing of carbonatite. The method comprises the steps that 1) basic parameters are collected; 2) a viscositydynamic change equation of natural gas in the matrix flowing process is set up; 3) a dynamic change calculation model of the tubular billet aperture and the secondary microfissure width considering stress sensitivity is set up; 4) the starting pressure gradient and a irreducible water film are considered, and flow equations of the natural gas in a tubular billet and a crack are set up; and 5) a fractal theory is introduced, a total flow calculation equation of the tubular billet and the crack is set up, the face, close to the crack, of the carbonatite obtained after acid fracturing is treatedinto a tubular billet-crack dual pore medium seepage model, and a model for calculating the permeability of the matrix after acid fracturing of the carbonatite is set up. The method for calculating the permeability of the matrix after acid fracturing of the carbonatite is provided based on the actual flowing process of the natural gas under the conditions of stress sensitivity, crack width dynamic changes, multiple pore media and the starting pressure gradient.

The invention relates to a method and a device for predicting the capacity of a fissure-hole type oil deposit. The method includes the steps of acquiring oil deposit bubble point pressure Pb, a volumetric factor B, in-place oil viscosity mu, the shaft radius rw, the oil reservoir thickness h, matrix permeability Km, fissure permeability Kf, oil deposit supply boundary pressure Pe, the boundary radius re, shaft bottom flow pressure Pw, a matrix permeability damage factor alpha m, a double-medium reservoir permeability damage factor alpha A and fissure closing pressure Pf. Fissure-hole type double-medium reservoir permeability KA is obtained according to the matrix permeability Km and the fissure permeability Kf; on the basis of permeation fluid mechanics, the stratum fissure closed radius rf is obtained by the acquired parameters; on the basis of inner and outer boundary conditions and reservoir permeability stress sensitive effects, the relation between the capacity of the fissure-hole type oil deposit and shaft bottom pressure is obtained by the acquired parameters; and the capacity of the fissure-hole type oil deposit is predicted according to the relation between the capacity of the fissure-hole type oil deposit and the shaft bottom pressure.

The invention discloses a soilless cultivation substrate for red ginger flower cultivation, which is composed of the following raw materials in parts by weight: 8-10 parts of Artemisia annua, 3-5 parts of honeysuckle, 4-6 parts of dandelion, 30-35 parts of bagasse, 5-8 parts of okara, 5-8 parts of urea, 1-3 parts of jasmonic acid, 1-3 parts of salicylic acid, 0.5-1 part of xanthan gum, 3-5 parts of orange peel and 50 parts of rice washing water. The preparation method of the red ginger flower cultivation substrate of the present invention mainly includes the steps of pulverizing traditional Chinese medicine, preparing nutrient solution, fermenting and mixing. According to the growth characteristics of the red ginger flower, the present invention enhances the effects of repelling and killing insects by adding Artemisia annua, honeysuckle and dandelion; adopts orange peel and various biological regulators to configure the nutrient solution, enriches the growth conditions of the red ginger flower. The required nutrients can promote plant growth; by adding bagasse and urea, the nutritional needs of red ginger flowers are met, the permeability and permeability of the substrate are enhanced, and the cultivation effect is good.

The invention provides a shale matrix permeability determination device and method. The device comprises a gas cylinder, a booster pump which is connected with the gas cylinder, an automatic gas supplementing and pressurizing system which is connected with the booster pump through a pressure regulating valve, and is used for supplementing and pressurizing a reference chamber and a sample chamber through gas in a gas storage tank of the booster pump under the condition that the pressure in the reference chamber and the sample chamber is identified to be smaller than a target pressure preset value in the experiment process, a temperature control device which is used for placing the reference chamber and the sample chamber used for placing a shale rock sample to be measured, and a pressure sensor which is used for measuring pressure data of the reference chamber and the sample chamber. By utilizing the scheme provided by the invention, the problem that the pressure of the whole system issharply reduced after particle gaps are filled with gas is avoided, the influence of the filling degree on permeability determination can be eliminated, the measurement error is reduced, and the accuracy of permeability determination is improved.

Methods, program code, computer readable medium, and apparatus estimating permeability at unsampled (uncored) but logged interval locations in a reservoir based upon a similarity with log signatures from cored intervals, are provided. An example of a method can include performing a core plug-by-core plug blind test, defining an objective function which qualifies the quality of the permeability prediction to minimize discrepancies between measured and predicted permeability, optimizing calculated parameters, and estimating permeability values of uncored logged intervals. The method can also include applying a debiasing / variance restoration to compensate for inherent averaging artifacts.

The invention discloses efficient cross-linking and low damage fracturing fluid. The efficient cross-linking and low damage fracturing fluid is prepared from the components in percentage by mass: 25%-65% of a thickening agent, 15%-45% of a cross-linking agent, 0.06%-1% of a PH regulator, 0.1%-0.3% of a clay stabilizer, 0.8%-2% of a discharge aiding agent, 0.5%-2% of a waterproof locking agent, 0.01%-0.06% of a bactericide, 0.01%-0.05% of a gel breaker and 40%-60% of water. The fracturing fluid uses fast dissolving guar gum (super HPG), the swelling time is smaller than 3 min, continuous blending is met, material consumption is reduced, the gel state is good, the delayed cross-linking time can be regulated, friction resistance is effectively lowered, a powdery plugging agent is adopted to realize multilayer steering in seams and between the seams, a complex seam net is formed, the compact oil and gas transformation effect is improved, by setting one or more of montmorillonite, kaolin, illite or chlorite as the clay stabilizer and starting with dissecting of different clay mineral damage mechanisms, targeted technological means are adopted, clay mineral damage caused by extraneous fluids is controlled to the utmost extent, and thus the matrix permeability is ensured.

The invention discloses a bacterial strain medium and a preparation method thereof. The bacterial strain medium solves the problems of soft and loose states of the traditional bacterial strain medium, improves base hardness and is convenient for transport and storage. Because of matrix change, physical vibration and temperature difference adaptability are improved. The traditional medium tissue structure is changed so that matrix permeability is improved and mycelia growth oxygen demands are greatly satisfied. The matrix components are changed so that a bacterial strain quality guarantee period is prolonged. The bacterial strain medium changes nutrition components of the traditional medium, has comprehensive and reasonable nutrition, improves medium base number and effectively inhibits infectious microbes. Through use of needlebush particles and sawdust, a raw material source and an application scope are widened. Inoculation efficiency is improved and a bacterial strain cost is about 1 / 5 that of the traditional PDA medium.

The invention discloses a method for testing matrix damage rate applied to a plugging agent. The method comprises the steps of: (a) preparing a repeated fracturing blocking agent and selecting a plurality of cores for later use; (b) respectively splitting the selected cores, and manufacturing an artificial fracture; (c) paving a layer of particulate matter inside a fracture, and simulating a fracturing fracture; (d) injecting the repeated fracturing blocking agent into an analogue fracturing fracture to stew for a period of time; (e) cleaning sand in each core after injecting the liquid, firmly bonding the fracture and determining the matrix permeability, and (f) obtaining the matrix damage rate through the measured matrix permeability. The matrix damage rate of the repeated fracturing blocking agent can be rapidly tested by the method; the method is simple in test process and accurate in test result, and the data support is provided for use of the repeated fracturing blocking agent.

A waveform energy generation system, the system including at least one joint of production casing, and one or more energy generators residing along the joint of production casing. The energy generators are configured to be in substantial mechanical contact with a subsurface formation within a wellbore. The energy generators may include either explosive devices or a piezo-electric material. The system also includes a signal transmission system. The signal transmission system is used to send control signals from the surface down to the energy generators for activation at the formation's resonant frequency. Methods of enhancing the permeability of a rock matrix within a subsurface formation using the wellbore as an energy generator are also provided.

The invention relates to a cross-linking reinforcing agent used for boron cross-linking modified guar gum fracturing fluid, a preparation method of the cross-linking reinforcing agent and the boron cross-linking modified guar gum fracturing fluid prepared from the cross-linking reinforcing agent, and belongs to the technical field of modified guar gum fracturing fluids. Specifically, in the embodiments of the invention, a cross-linking reinforcing agent is prepared by adopting glycerin, sodium thiosulfate and water, when the prepared cross-linking reinforcing agent is added into the boron cross-linking modified guar gum fracturing fluid, the temperature resistance and shear resistance of the fracturing liquid can be improved, a use concentration of the modified guar gum at the same temperature can be greatly reduced, a residue content after gel breaking can be reduced, damage to reservoir matrix permeability can be avoided, and the fracturing effect is improved.

The invention discloses a dual-porosity dual-permeability model and dynamic prediction method for a shale gas reservoir considering gas-water two-phase flow. Aiming at the flow of gas in a formation from an entire matrix system to natural fractures, gas-water two-phase flow exists in the matrix system and the fracture system, and the condition that the matrix permeability is corrected by the influence of an adsorbed water layer in inorganic nano-scale pores is considered, the proportion of organic matter and clay minerals and the respective adsorption and desorption constants thereof are introduced to derive a shale gas reservoir gas-water two-phase flow dual-porosity dual-permeability model; and an IMPES method and Matlab mathematical software are adopted to program and solve the two-phase, three-dimensional, dual-porosity and dual-permeability model of multistage fractured horizontal wells in the shale gas reservoir, and the dynamic changes of production pressure are accurately predicted. The invention aims to solve the technical problem that shale gas reservoir gas-water two-phase dual-medium models in the prior art cannot accurately and dynamically predict the production pressure.

The invention discloses a vegetable seedling raising matrix, which belongs to the technical field of soilless cultivation. The vegetable seedling raising matrix is mainly prepared from the following raw materials in parts by weight: 60 to 70 parts of decomposed pine needles, 29 to 39 parts of coco coir, 0.3 to 0.35 part of calcium magnesium phosphate fertilizer, 0.3 to 0.35 part of potassium sulfate, and 0.3 to 0.35 part of ammonium sulfate; the water content of the matrix is 28 to 34 percent, the total porosity is 75 to 80 percent, the particle size is 0.3 to 0.5 mm, an air-water ratio is 1:(3.5 to 4), and a pH value is 6.5 to 7.3. The vegetable seedling raising matrix of the invention is scientific and reasonable in raw material proportioning; by adopting the decomposed pine needles andcoco coir as main raw materials, the vegetable seedling raising matrix is long in fertilizer effective time, balanced in nutrition, good in matrix permeability, high in water absorption, resistant tobacteria, pollution-free, capable of promoting the growth of vegetable seedlings with good growth, and capable of increasing the seed sprouting rate, and the cultivated vegetable seedlings are high in yield, good in quality and good in economic benefit.

The invention discloses a matrix permeability calculation method and system. The method comprises the following steps of establishing natural gamma neutron logging cross plots of sandstones with different granularities, and determining constraint boundaries of the sandstones with different granularities; obtaining a rock granularity profile according to the natural gamma neutron logging cross plot; determining granularity median ranges corresponding to different granularities according to the rock granularity profile; establishing a cross plot according to the known particle size median, the constraint boundary and the natural gamma, and calculating the initial particle size median of the unknown sandstone; determining the particle size median of the unknown sandstone according to the particle size median range corresponding to the unknown sandstone and the initial particle size median; and calculating permeability of the matrix according to the particle size median. According to the method, evaluation of the matrix permeability is realized by establishing the granularity profile calculation chart and calculating the granularity median, the influence of granularity on the matrix permeability is reflected, and permeability of the double-hole medium reservoir can be accurately determined by combining the fracture permeability.

The feasibility of performing hydraulic fracturing can be assessed by analyzing the effect of skin on the overall deliverability of a reservoir. Aspects of the disclosure provide a method to determine equivalent skin in hydraulic fractured system through a semi analytical correlation obtained by numerical modeling. Two 3D models are considered: a base case without fracture and a complex case with fractures. The base case is simulated by varying matrix permeabilities while the fractured model is run with different sets of varying fracture's lengths, widths, and permeability as well as matrix permeabilities. The two cases are comparatively analyzed and skin is determined. A generalized correlation for determination of skin is derived through application of multivariate regression technique on obtained skins and their corresponding variables.