184 results about "Reservoir engineering" patented technology

The invention relates to a device and a method for simultaneously testing the permeability of compact rocks under transient state and steady state, and belongs to the fields of rock engineering and unconventional oil and gas reservoir engineering. The testing device for simultaneously testing the permeability of the compact rocks under the transient state and the steady state comprises a three-shaft pressure chamber, a bias pressure control system, a confining pressure control system, an upper end permeating system, a lower end permeating system, a vacuum pumping system, a constant temperature system and a data controlling and collecting system. The method for simultaneously testing the permeability of the compact rocks under the transient state and the steady state comprises the following steps: demarcating the reference volume, providing the confining pressure and bias pressure temperature environment for a sample, and testing the permeability under the transient state and the permeability under the steady state. For the device and the method, the practical bias pressure, back pressure and constant temperature testing environment conforming to the engineering is provided, the fluctuation error of the temperature can be controlled within -0.1 DEG C to +0.1 DEG C, the volume error of the gas can be controlled within 0.3%, and the error of the injected pressure can be controlled within 0.5%. The test of the permeability under the transient state in constant pressure and constant volume ways can be simultaneously realized; when the permeability is tested in the constant volume way, the volume of a reference container can be adjusted according to the volume of a pore.

The invention discloses a productivity prediction system and method based on oil gas content, and belongs to the field of oil development and engineering. The system comprises a static parameter confirming module, an oil reservoir and engineering parameter confirming module, a productivity prediction model establishment module and an evaluation module, wherein the static parameter confirming module is used for collecting logging information of strata through logging equipment, partitioning a plurality of reservoir beds according to the logging information, performing recognition and evaluation on any one of the plurality of reservoir beds through a lithology identification method, and confirming that static parameters of one reservoir bed is obtained; the oil reservoir and engineering parameter confirming module is used for performing reservoir engineering analysis on the region where the logging is located, and obtaining oil reservoir and engineering parameters of the region; the productivity prediction model establishment module is used for establishing a productivity prediction model based on the oil gas content and obtaining a stratum flow of an oil layer through calculation according to the static parameters in the reservoir beds and the oil reservoir and engineering parameters of the region; and the evaluation module is used for classifying the reservoir beds of the logging according to the stratum flow of the oil layer. The productivity prediction system and method based on the oil gas content can solve the problem that oil phase permeability is difficult to confirm, thereby improving the accuracy of the productivity prediction.

The invention provides a CO2 drive technological limit well spacing determination method for a low-permeability oil reservoir. The method comprises the steps that the minimum miscible pressure of CO2 and crude oil is determined through a long-thin pipe displacement test; through a rock core displacement test, with the combination of the minimum miscible pressure of the crude oil, the relational expression of the change of starting pressure gradient along with fluidity under the miscible phase and immiscible phase conditions is determined; a calculation formula of a CO2 drive technological limit oil supply radius is established through an oil reservoir engineering method; through a site test method or an oil reservoir numerical simulation method, stratum pressure distribution conditions are obtained, a miscible phase area and an immiscible phase area are determined, and the proportionality coefficient of the miscible phase area and the immiscible phase area is calculated; and through a calculation formula of CO2 drive technological limit well spacing, stratum technological limit well spacing under the current condition is obtained through calculation. According to the CO2 drive technological limit well spacing determination method for the low-permeability oil reservoir, oil field potential is further exploited, economically recoverable reserves are increased greatly, the resource exploitation basis is enhanced, and the crude oil recovery ratio is further increased.

The invention relates to a method for predicting volcanic rock facies, and relates to the technical field of petroleum exploitation reservoir engineering. The method comprises the following steps: (1) forward modeling, (2) seismic attribute extraction, (3) attribute optimization, (4) volcanic rock facies classification, (5) multi-attribute neural network pattern recognition and (6) rock facies prediction, wherein in the step of forward modeling, profile forward modeling is performed on the basis of seismic geologic horizon calibration; in the step of seismic attribute extraction, horizon-oriented seismic attributes are extracted in allusion to a target horizon, and an attribute time window range is determined; in the step of attribute optimization, seismic attributes reflecting volcanic rock distribution are optimized, and preprocessing is performed; in the step of volcanic rock facies classification, category classification is performed on the volcanic rock facies according to a well drilling result; and in the step of rock facies prediction, a plurality of seismic attributes are fused according to neural network parameters acquired by training, and a distribution variation law of the volcanic rock facies in an unknown area is predicted. The prediction method provided by the invention fuses multiple seismic attributes and well drilling information, overcomes the defect that a single seismic attribute only partially reflects the lithological combination difference, and can effectively predict spatial distribution of the volcanic rock facies.

The invention provides a method for representing an oil-water relative permeability curve under the condition of different driving displacement pressure gradients, and belongs to the technical field of reservoir engineering in oil development. The method comprises the following steps that (1) different driving displacement pressure gradients are exerted on a group of rock cores with identical or similar permeability to obtain the relative permeability experiment data of each rock core, then, a permeability curve corresponding to each rock core is made according to the relative permeability experiment data, and next, the relative permeability curve corresponding to each rock core is subjected to normalization processing to obtain an oil-water relative permeability curve corresponding to each rock core; (2) the statistical laws on the water phase maximum relative permeability, the oil displacement efficiency and the pressure gradient are fit out according to the relative permeability experiment data, and the water phase maximum relative permeability and the residue oil saturation degree under different pressure gradients can be solved; (3) a characteristic curve equation of the relative permeability curve corresponding to each rock core is solved.

The invention relates to a prediction and analysis method for an oil field exploitation index, and the method comprises the steps: 1, data obtaining; 2, data extraction; 3, index calculation; 4, probability statistics and clustering analysis; 5, index application. The invention has the following beneficial effects that 1, the method makes the most of the existing exploitation production data of all wells of the same type of oil fields for the exploitation of a new oil field and a new area, and breaks the limits of a typical oil and gas reservoir analogy method in the selection of a typical oiland gas reservoir; 2, the method is a supplement for the oil reservoir engineering method, and achieves the index prediction for the exploitation of oil fields and areas in a small scale based on allsample data of exploitation production wells of the same type of oil reservoirs at the same exploitation stage through the principle of statistics; 3, the prediction result of oil field exploitationindexes determines the reliability evaluation.

A method for forming a model simulating production, by an underground reservoir subject to depletion, of hydrocarbons comprising notably relatively high-viscosity oils. From laboratory measurements of the respective volumes of oil and gas produced by rock samples from the reservoir subject to depletion, and the relative permeabilities (Kr) of rock samples to hydrocarbons, a model of the formation and flow of the gas fraction is used to determine a volume transfer coefficient (hv) by means of an empirical function representing the distribution of nuclei that can be activated at a pressure P (function N(P)) which is calibrated with reference to the previous measurements. Considering that the nuclei distribution N(P) in the reservoir rocks is the same as the distribution measured in the laboratory, the numerical transfer coefficient corresponding thereto in the reservoir at selected depletion rates is determined using the gas fraction formation and flow model, which allows predicting the relative permeabilities in the reservoir and the production thereof which is useful for reservoir engineering. Method for forming a model allowing to simulate the production, by an underground reservoir subjected to depletion, of hydrocarbons comprising notably relatively high-viscosity oils. From laboratory measurements of the respective volumes of oil and gas produced by rock samples from the reservoir and subjected to depletion, and the relative permeabilities (Kr) of rock samples to hydrocarbons, a model of the formation and flow of the gas fraction is used to determine a volume transfer coefficient (hv) by means of an empirical function representing the distribution of nuclei that can be activated at a pressure P (function N(P)) which is calibrated with reference to the previous measurements. Considering that the nuclei distribution N(P) in the reservoir rocks is the same as the distribution measured in the laboratory, the numerical transfer coefficient corresponding thereto in the reservoir at selected depletion rates is determined using the gas fraction formation and flow model, which allows to predict the relative permeabilities in the reservoir and the production thereof. Applications notably reservoir engineering.

A method having an application to production problems in reservoir engineering for quickly forming a stochastic model representative of the distribution of a physical quantity in a porous heterogeneous medium, which is calibrated in relation to dynamic data, by suitable selection of geostatistical realizations to be combined linearly. An iterative gradual deformation process is used, wherein an initial geostatistical realization (y) of the medium and a number (N−1)(N>1) of other realizations (z_i)i=1, . . . ,(N−1), which are independent of initial realization (y), are linearly combined at each iteration, by applying constraints to the linear combination coefficients of realizations (y) and (z_i)i=1, . . . ,(N−1), and an objective function (J) measuring the difference between a set of simulated data deduced from said combination by means of a simulator and said dynamic data is minimized. To quickly minimize the objective function, the Lagrange multiplier (λ), λε R^N−1 associated with the constraint relating to the specified values of the coefficients of realizations (z_i)i=1, . . . ,(N−1) is calculated. The absolute value λ_i of the i^th component of multiplier λ indicates the sensitivity of the objective function in relation to the i^th geostatistical realization (z_i).

The invention discloses a volume fracturing directional well arranging method for an ultra-low permeability dense reservoir. By adoption of the well arranging method, the large-scale volume fracturing capability can be achieved, the initial per-well production is greatly increased, and the proportion of oil-water wells is high. The modes of reservoir engineering, numerical simulation, downhole microseismic monitoring, mine field statistics and the like are comprehensively utilized during well pattern optimization, characteristics and transform technologies of different reservoir stratums are fully considered, and fractured flooding is avoided; and meanwhile, the requirement for energy replenishing for long-term stable production and water injection is met, and accordingly the purposes of increasing the per-well production and exploitation benefits of the ultra-low permeability dense reservoir are achieved. The volume fracturing directional well arranging method is suitable for complex geological conditions such as longitudinal reservoir stratum superimposed development and large planar structure variation amplitude of the ultra-low permeability dense reservoir, reasonable, and capable of improving the exploiting effect to the maximum extent.

The invention belongs to the technical field of oil-gas field development, and particularly relates to a determination method for the injection allocation volume of separated layer water injection layer sections. The injection allocation volume of the separated layer water injection layer sections is determined according to the relation among the recovery percentage, the water storage rate and the water content rate by applying a traditional oil reservoir engineering method. The determination method comprises the following steps that liquid physical property data, the separated layer water injection layer section dividing combination and dividing layer section number and water injection production history data of an oil reservoir are collected and counted; the total water injection volume needed when the water content rate of all the separated layer water injection layer sections reaches 98% is calculated; the accumulated insufficient water injection volume of all the separated layer water injection layer sections is obtained through calculation by subtracting the accumulated water injection volume from the total water injection volume needed when the water content rate of all the separated layer water injection layer sections reaches 98%; the injection allocation volume of all the separated layer water injection layer sections is determined. According to the determination method, a reasonable layer section injection allocation volume scheme can be quickly determined to determine the injection allocation volume of the separated layer water injection layer sections, and the problems that a small amount of oil-water well layered testing data exists, and the injection allocation volume of the separated layer water injection layer sections is difficult to determine can be solved.

The invention provides a horizontal well refracturing method. The effects of sealing and cementing an oil pit shaft of a horizontal well, temporarily building a fire-new pit shaft, building a refracturing passage and freely selecting a repeated transformation layer section according to the oil reservoir engineering requirements can be realized; the process goal of precisely controlling the repeated transformation of artificial cracks can be achieved; and the operation efficiency of the repeated transformation and the production increase effect can be improved.

The invention discloses a dynamic analysis and waterflooding management system of fractured-vuggy type reservoir. The system comprises a dynamic reservoir waterflooding database and a reservoir dynamic analysis and waterflooding management platform. The dynamic reservoir waterflooding database stores reservoir data and information including reservoir basic information, single-well basic information and dynamic reservoir and oil-water well production data; The reservoir dynamic analysis and waterflooding management platform comprises a reservoir dynamic analysis module, a figure making module and a data table making module, wherein the reservoir dynamic analysis module carries out reservoir engineering calculation and analysis on a single well, a single-well fractured-vuggy unit, a multi-well fractured-vuggy unit, a block or an oil field according to the reservoir data and information and obtains an analysis result; the figure making module drafts a figure according to the analysis result; and the data table making module makes a data table according to the analysis result. The dynamic analysis and waterflooding management system of the invention provides theoretical basis for waterflooding exploitation and dynamic reserves calculation as well as support for an application platform, reduces the risk of waterflooding exploitation, and improves the production efficiency and quality.

The invention relates to the field of construction technology and in particular relates to a construction method for a water treatment plant reservoir. The construction working method for a seamless prestressed-concrete self-waterproof clean water reservoir has the main construction technology as follows: preparing, digging a foundation pit, constructing a cushion ply, laying a plastic film, constructing a reservoir bottom plate, laying a plastic film on the bottom of a reservoir wall, constructing a guide wall, columns and side walls of the reservoir, constructing a top plate, pouring the small foot putting concrete of the bottom plate, and carrying out a full-water test. The seamless technology in the construction method mainly means that no construction joints are left during the construction of the reservoir bottom plate, the reservoir wall and the top plate and the concrete can be poured once without leaving a rear pouring zone. The integral construction quality of the reservoir can be guaranteed by purchasing, pouring and nursing concrete materials and controlling the construction of the prestress engineering. The clean water reservoir engineering constructed by the working method has the advantages that seepage flow measured after a full water test is greatly lowered, and a great quantity of water resources are saved.

The invention provides an oil-water relative permeability symptom processing method based on reservoir physical property. The method comprises the following steps: selecting oil-water relative permeability curve data measured by a multi-strip laboratory and capable of reflecting area or reservoir physical property; establishing a function relation of the oil-water relative permeability curve characteristic parameter as well as air permeability and porosity of a rock core sample, performing standardization processing on the water content saturation, oil content saturation, water-phase relativepermeability and oil-phase relative permeability; respectively establishing a power function relation of a standard water phase, the oil-phase relative permeability, the water content saturation, andthe oil content saturation, establishing a function relation of a power exponent as well as air permeability and porosity, and using different reservoir physical property data to obtain the differentoil-water relative permeability curves. The method establishes the base for deduction of a calculating method for oil reservoir engineering, an oil-water displacement theory and oil reservoir value simulation by taking regard of seepage heterogeneity, accurately predicts the oil-water displacement exploitation effect and trend, and guides the oil field exploitation and production practice.

The invention discloses a single hole-single layer mean value well testing interpretation method for a fracture and cavern reservoir, and relates to the technical field of oil reservoir engineering. The single hole-single layer mean value well testing interpretation method comprises the steps that a well testing model is established according to a physical model of which a wellbore is connected with a large cavern and oil reservoir parameters; a real space downhole pressure solution is obtained according to the well testing model; and curve fitting is conducted by utilizing the real space downhole pressure solution and actually-measured downhole pressure data, and thus parameters of fracture permeability, the wellbore reservoir coefficient, the cavern volume and the like are obtained. According to the single hole-single layer mean value well testing interpretation method, a matched interpretation method is provided for parameter calculation and reserve calculation of the fracture and cavern oil reservoir, the volume of the large cavern in the fracture and cavern oil reservoir can be directly interpreted, and technical support is provided for formulation of an oilfield development scheme; the model is simple, solving is convenient, meanwhile, analytic solution does not involve calculation of complex functions, and the calculation speed is high; and meanwhile, the interpretationresults after fitting can directly give the magnitude of the cavern volume, and thus the single hole-single layer mean value well testing interpretation method can be conveniently used for calculatingthe single well reserve.

The invention provides a tight sandstone gas reservoir development well pattern optimization method and belongs to the technical field of effective maximum natural gas extraction and geological and gas reservoir engineering and mineral field experiments. The method comprises the following steps: collecting drilling data in a dense area, finely dissecting an effective sand body and determining the length and width of the effective sand body; establishing a no-interference gas well change rule on the basis that the collection production time is long and the fact that well interference does not exist in actual production data of a gas well is proved; determining that a gas-well production interference change rule exists by adopting a numerical simulation technique and on the basis of establishment of a fine geological model; realizing production forecast of two types of gas wells, and establishing a development well pattern optimization model by using gas reservoir development profits as a reference, so as to determine economic limit well pattern density and economic optimum well pattern density of a gas reservoir; establishing a relationship between a gas reservoir recovery ratio and the well pattern density; and determining a reasonable development well pattern for the gas reservoir by comprehensively considering geological requirements, economic conditions and highest recovery ratio expectation, so as to realize optimization of the tight sandstone gas reservoir development well pattern.

The invention relates to a prediction method of a compact transition rock and relates to the technical field of oil development reservoir engineering. The method comprises the following steps of (1) model forward modeling, wherein fine level calibration is carried out, a compact transition rock section and a sand rock section single well are subjected to model forward modeling, and the earthquake response characteristic difference of a sand rock and the compact transition rock is analyzed; (2) conventional seismic attribution extracting, wherein for a target level, stratum attributions comprising amplitude and frequency are extracted through a conventional seismic attribution extracting method; (3) attribution optimization, wherein the seismic attributions high in reaction lithology difference, namely earthquake amplitude and frequency attributions are optimized, and attribution preprocessing is carried out; and (4) attribution fusion, wherein the earthquake amplitude and the frequency attributions are used, attribution fusion formula selecting is carried out, advantage attributions are expanded, disadvantage attributions are suppressed, and distribution of a compact oil reservoir stratum is detected. According to the prediction method, a large amount of seismic attribution information is fused, the earthquake response features of the sand rock and the transition rock can be distinguished, and the space distribution of the compact transition rock can be predicted effectively.

The invention provides a method for predicting the effective permeability of a carbonate gas reservoir. Based on pressure recovery well-testing theory analysis and on the basis of influence factor analysis of a low-permeability carbonate reservoir, the relational expression of the effective permeability of the reservoir and pressure recovery data of wellhead sleeves as well as the relational expression of the effective permeability of the reservoir and wellhead yields are built, and a method for evaluating the effective permeability of gas wells through conventional production dynamic materials is formed. According to the method for predicting the effective permeability of the carbonate gas reservoir, the evaluation problem of the permeability of the low-permeability and high-density inhomogenous reservoir under the situation of lacking well-testing evaluation materials is solved, the evaluation range of the effective permeability of the low-permeability gas reservoir is widened by a large margin, and important basic parameters are provided for gas reservoir engineering research such as productivity evaluation and calculation of the gas extraction speed.

The invention discloses a rock mechanics and reservoir engineering parameter evaluation method, and belongs to the technical field of rock mechanics. The rock mechanics and reservoir engineering parameter evaluation method comprises the following steps: performing X-ray diffraction on rock debris to obtain mineral components and contents of the rock debris; performing CT scanning on the rock debris, performing observation under a microscope, and obtaining the microstructure characteristics of all mineral particles of the rock debris; carrying out a micro/nano indentation test on the rock debris, and determining the micromechanical parameters of each mineral component of the rock debris; constructing a three-dimensional calculation model according to the rock debris microcosmic characteristic gene, and taking a representative volume unit to obtain rock macromechanics parameters; and evaluating the engineering parameters of the field requirements according to the rock macromechanics parameters and the engineering parameter evaluation model. The rock mechanics and reservoir engineering parameter evaluation method can effectively and accurately obtain engineering parameters required onsite and is of great significance to design and optimization of on-site drilling and fracturing engineering.

The invention discloses a high dam reservoir ultra-deep water retaining and emptying system and an operation method thereof. The water retaining and emptying system comprises first to last stage gate systems and a last stage radial gate system, and the first to last stage gate systems are sequentially arranged on a tunnel; each stage gate system is provided with communicating pipes with water supplement and draining functions, and the communicating pipes perform water flow control by means of valves; all the stages of gate systems achieve water pressure and air pressure balance through the inner and outer communicating pipes, the outer maintaining communicating pipes, ventilation pipes, galleries and the like of the gate systems respectively; the last stage gallery is communicated with the down stream of the water retaining and emptying system through a gallery shaft. The operation method includes four working conditions of water storing, water emptying, maintaining and water retaining. According to the high dam reservoir ultra-deep water retaining and emptying system and the operation method thereof, multiple stages of gates are disposed so as to share burden with a gross head; water filling is performed in rear of each stage of gate so as to counteract the pressure of water retaining heads, and hydraulic thrust which each stage of gate tolerates can be kept within a conventional design range; the defects of metal structures in the prior art can be overcome; the key technical problem of ultra-deep water retaining and emptying designs in the high dam reservoir engineering can be solved.

The invention relates to a middle-seepage complex fault block oil reservoir water flooding development effect quantitative evaluation method, which belongs to the oil field development and oil reservoir engineering field. According to the invention, on the foundation of selecting the factors influencing the water flooding development effect for middle-seepage complex fault block oil reservoir and according to the influencing degrees of the various factors on the development effect as well as the logic relationships among the various factors, the evaluation factors with relative independence and operability are determined, superposed in quantification and combined to establish an evaluation grade membership matrix capable of quantitatively evaluating the water flooding development effect of the middle-seepage complex fault block oil reservoir and to accomplish the purpose of quantitatively evaluating the water flooding development effect of the middle-seepage complex fault block oil reservoir. The method fully considers the shared influences of all individual factors on the oil reservoir and the obtained unique quantitative evaluation result for the target oil reservoir can reflect the water flooding development effect for the middle-seepage complex fault block oil reservoir scientifically and accurately so as to provide an objective basis for scientific decisions on oil reservoir development and technical support for the effective adjustment of the oil reservoir development scheme.