249 results about "Reservoir evaluation" patented technology

A method of managing a fluid or gas reservoir is disclosed which assimilates diverse data having different acquisition time scales and spatial scales of coverage for iteratively producing a reservoir development plan that is used for optimizing an overall performance of a reservoir. The method includes: (a) generating an initial reservoir characterization, (b) from the initial reservoir characterization, generating an initial reservoir development plan, (c) when the reservoir development plan is generated, incrementally advancing and generating a capital spending program, (d) when the capital spending program is generated, monitoring a performance of the reservoir by acquiring high rate monitor data from a first set of data measurements taken in the reservoir and using the high rate monitor data to perform well-regional and field-reservoir evaluations, (e) further monitoring the performance of the reservoir by acquiring low rate monitor data from a second set of data measurements taken in the reservoir, (f) assimilating together the high rate monitor data and the low rate monitor data, (g) from the high rate monitor data and the low rate monitor data, determining when it is necessary to update the initial reservoir development plan to produce a newly updated reservoir development plan, (h) when necessary, updating the initial reservoir development plan to produce the newly updated reservoir development plan, and (i) when the newly updated reservoir development plan is produced, repeating steps (c) through (h). A detailed disclosure is provided herein relating to the step (a) for generating the initial reservoir characterization and the step (b) for generating the initial reservoir development plan.

A method of managing a fluid or gas reservoir is disclosed which assimilates diverse data having different acquisition time scales and spatial scales of coverage for iteratively producing a reservoir development plan that is used for optimizing an overall performance of a reservoir. The method includes: (a) generating an initial reservoir characterization, (b) from the initial reservoir characterization, generating an initial reservoir development plan, (c) when the reservoir development plan is generated, incrementally advancing and generating a capital spending program, (d) when the capital spending program is generated, monitoring a performance of the reservoir by acquiring high rate monitor data from a first set of data measurements taken in the reservoir and using the high rate monitor data to perform well-regional and field-reservoir evaluations, (e) further monitoring the performance of the reservoir by acquiring low rate monitor data from a second set of data measurements taken in the reservoir, (f) assimilating together the high rate monitor data and the low rate monitor data, (g) from the high rate monitor data and the low rate monitor data, determining when it is necessary to update the initial reservoir development plan to produce a newly updated reservoir development plan, (h) when necessary, updating the initial reservoir development plan to produce the newly updated reservoir development plan, and (i) when the newly updated reservoir development plan is produced, repeating steps (c) through (h). A detailed disclosure is provided herein relating to the step (a) for generating the initial reservoir characterization and the step (b) for generating the initial reservoir development plan.

The invention provides a method for carrying out shale gas reservoir evaluation and finding a dessert area for shale gas exploration and development comprehensively through comprehensive application of rock physics, log data and omnibearing or wide-azimuth three-dimensional seismic data. The method is characterized by analyzing the characteristics of the dessert area in a shale reservoir by applying comprehensive geophysical exploration technologies of laboratory rock geophysical measurement, log data comprehensive analysis, rock physical modeling, vertical seismic section data, omnibearing or wide-azimuth three-dimensional seismic data high precision surface layer comprehensive modeling static correction processing, prestack de-noising processing, amplitude relative fidelity processing, resolution enhancement processing which is carried out by utilizing well constraint and well seismic data to drive ground seismic data, fine excision, iteration velocity analysis, interval velocity field analysis, prestack depth migration processing, high resolution processing, azimuth classification processing, high-precision anisotropy processing, prestack and post-stack data inversion processing, and neural network analysis and the like, and thus gas bearing characteristic prospect of the shale gas reservoir is evaluated accurately and the dessert area for shale gas exploration and development is delineated.

The invention provides a low permeability gas reservoir turning repeated fracturing technological method. The specific technological method comprises the following steps of gas well initial fracturing failure or low-efficiency reason analyzing, reservoir stratum evaluating conducted before turning repeated fracturing, turning repeated fracturing well selection and stratum selection decision making, rock mechanical parameter and ground stress testing, turning repeated fracturing ground stress field changing simulating, fracture geometrical parameter and flow conductivity optimizing, turning repeated fracturing technology optimizing, fracturing liquid and turning agent studying, repeated fracturing constructing and evaluating conducted after repeated fracturing. The well selection and stratum selection decision making and residual gas detecting serve as verification systems of each other, fracturing design and fracture detecting serve as verification systems of each other, and a novel fracture turning agent is used in the low permeability gas reservoir turning repeated fracturing technological method. The integrated design of the low permeability gas reservoir turning repeated fracturing is achieved, and the low permeability gas reservoir turning repeated fracturing technological method has the advantages that the design links are macroscopically integrated, local innovation is achieved, linkage is close, mutual verification is achieved, the design is advanced, and the technological advantage is obvious.

A method and system for evaluating status and response of a mineral-producing field (e.g., oil and / or gas) by monitoring selected chemical and physical properties in or adjacent to a wellsite headspace. Nanotechnology sensors and other sensors are provided for one or more underground (fluid) mineral-producing wellsites to determine presence / absence of each of two or more target molecules in the fluid, relative humidity, temperature and / or fluid pressure adjacent to the wellsite and flow direction and flow velocity for the fluid. A nanosensor measures an electrical parameter value and estimates a corresponding environmental parameter value, such as water content or hydrocarbon content. The system is small enough to be located down-hole in each mineral-producing horizon for the wellsite.

A Gas Reservoir Evaluation and Assessment Tool utilizes an Analytical Engine to produce predictions of pressure values and other production data at any point in space and at any point in time in a reservoir. A computer system, such as a workstation, stores a Gas Reservoir Evaluation and Assessment software which includes the Analytical Engine and responds to input data (which includes a reservoir description and fluid properties) by generating an output record which represents a prediction of the pressure values and other data at ‘any point in space’ and at ‘any point in time’ in a reservoir. The Analytical Engine will first calculate a pressure value in 1D for a single layer of a reservoir at a single point in space and time; it will then calculate a pressure value in 1D for multiple layers in the reservoir at the single point in space and time; it will then calculate a pressure value in 2D for the multiple layers at the single point in space and time; it will then calculate a pressure value in 3D for the multiple layers at the single point in space and time; and it will then calculate a pressure values in 3D for multiple layers not only at a single point in space but also at any future point in time.

The invention relates to a quantitative lithogenous phase evaluation method for a compact sandstone reservoir, and belongs to the technical field of oil and gas reservoir evaluation. Under a condition of little coring information of a region to be evaluated, the types of lithogenous phases of the compact sandstone reservoir in the region to be evaluated are classified according to core information of the region to be evaluated and logging information, and a relation between the types of the lithogenous phases of the compact sandstone reservoir in the region to be evaluated and logging parameters of a coring well is constructed, so that the types of the lithogenous phases of the compact sandstone reservoir in the region to be evaluated and the types of the lithogenous phases of a non-coring well are determined, quantitative evaluation on the lithogenous phases of the compact sandstone reservoir in the region to be evaluated is realized, and distribution features of favorable lithogenous phase zones and favorable reservoirs of the compact sandstone reservoir are determined; a reliable basis is provided for forecasting a favorable exploration and development zone and instructing oil-gas exploration and development, and the exploration and development cost is lowered.

The invention discloses a reservoir classification method based on rock electricity parameters, and belongs to the field of hydrocarbon reservoir evaluation. The method is based on rock electricity experiment theoretical model deduction, a theoretical value range and a value trend of rock electricity experiment data of reservoirs under different pore structures are formed, and reservoir pore structure subareas on a rock electricity data F-phi plate are formed; and corresponding electrical logging data are utilized in combination with rock electricity experiment data and mercury injection capillary pressure curve data to determine rock electricity method quantitative classifications, and the method at least includes: Step 1) establishing a rock electricity method classification bases; Step 2) forming a classification plate; Step 3) establishing a quantitative classification evaluation basis; and Step 4) determining classification grades of the reservoirs. According to the reservoir classification method based on rock electricity parameters in the invention, by checking distribution of the rock electricity data on the F-phi plate and discovering that rock samples of reservoirs of different classes fall on distinguishable different subareas on the F-phi plate, continuous evaluation knowledge can be provided, and a verification effect is good.

The invention provides a method of using absorption and attenuation characteristics of seismic waves for reservoir analysis, belonging to the field of seismic exploration and development of oil gas and coal bed gas. Based on the theory of absorption and attenuation of seismic waves and the technology of seismic spectral decomposition, seismic forward modeling techniques are adopted for different types of thin reservoirs, the amplitude is corrected via analyzing the relationship between the reservoir thickness and the seismic amplitude and frequency, and then the reservoir evaluation and analysis based on the stratum unit are performed under constraints of geologic horizons according to the properties of seismic absorption and attenuation. The purpose of evaluating the gas content of the reservoir according to the properties of absorption and attenuation of seismic waves is realized, and the method has broad application values in the evaluation and description of heterogeneous reservoirs, in particular the evaluation and fine description of coal bed gas and other unconventional reservoirs.

The invention discloses a multi-level evaluation method of horizontal-well volume fracturing effect influence factors. The method sequentially includes the following steps: 1) establishing an evaluation index database, which includes a sample set, a fracturing effect influence factor set and an evaluation index main-factor set; 2) establishing a multi-level evaluation system according to the evaluation index database; 3) utilizing a grey correlation analysis method to calculate all influence factor weight coefficients in the multi-level evaluation system, sorting the same to clarify primary-secondary relationships, and evaluating a fracturing effect; and 4) calculating a comprehensive reservoir evaluation factor, classifying reservoirs where all fracturing wells are located, and evaluatingthe fracturing effect. According to the method, the factors of volume-fracturing horizontal-well reservoir physical-properties, fracturing construction and production dynamics and the like are comprehensively considered, a purpose of multi-level evaluation on the horizontal-well volume fracturing effect influence factors is achieved through calculating the weight coefficients of all the influencefactors of different levels and the comprehensive reservoir evaluation factor, and an important guiding role is played on horizontal-well volume fracturing optimization design and development of tight oil reservoirs.

The invention relates to a method for synchronously realizing seismic lithofacies identification and quantitative assessment of uncertainty of the seismic lithofacies identification. The method comprises the steps of determining the type of the lithofacies and performing logging lithofacies definition, establishing a rock physical response relation between logging physical parameters and elasticity, establishing a probability statistical relation between the lithofacies and logging attributes, establishing the probability statistical relation of well-seismic scale elasticity parameters and constructing the statistical relation of the lithofacies and the seismic scale elasticity parameters, inverting the information of the probability distribution of the elasticity parameters of a target layer, obtaining the lithofacies probability information of the target layer by combining the inverted probability information of the elasticity parameters of the target layer and the statistical relation of the lithofacies and the seismic scale elasticity parameters, obtaining the maximum posterior probability solution of the lithofacies distribution according to the probability information of the lithofacies and outputting final model parameters. The method is capable of quantitatively characterizing the uncertainty of each link of lithofacies identification and the propagation and accumulation characteristics of the uncertainty in the lithofacies identification process, and also capable of performing uncertainty analysis on the seismic lithofacies identification; as a result, the reservoir evaluation risk is reduced; in short, the method is wide in application range.

A Gas Reservoir Evaluation and Assessment Tool utilizes an Analytical Engine to produce predictions of pressure values and other production data at any point in space and at any point in time in a reservoir. A computer system, such as a workstation, stores a Gas Reservoir Evaluation and Assessment software which includes the Analytical Engine and responds to input data (which includes a reservoir description and fluid properties) by generating an output record which represents a prediction of the pressure values and other data at ‘any point in space’ and at ‘any point in time’ in a reservoir. The Analytical Engine will first calculate a pressure value in 1D for a single layer of a reservoir at a single point in space and time; it will then calculate a pressure value in 1D for multiple layers in the reservoir at the single point in space and time; it will then calculate a pressure value in 2D for the multiple layers at the single point in space and time; it will then calculate a pressure value in 3D for the multiple layers at the single point in space and time; and it will then calculate a pressure values in 3D for multiple layers not only at a single point in space but also at any future point in time.

The invention discloses a resistivity anisotropy recognition method in a horizontal well stratum environment. Firstly, an azimuth natural GR and an azimuth resistivity logging are obtained through logging, and then a stratigraphic dip and a stratigraphic azimuth angle are extracted. Secondly, the instrument azimuthal resistivity logging response value at multiple spacings and different frequencies in a horizontal well are acquired through logging. Through the environmental correction and automatic layering process, a false layer is removed, and standardized logging data and a stratum layering interface are obtained. Thirdly, according to a stratigraphic dip extracting result, the layering interface, an apparent resistivity measured value and adjoining well data, a horizontal well stratum model is constructed. Finally, the stratum model is subjected to back calculation, and then an anisotropy coefficient and a stratum resistivity inversion result are outputted. According to the method, the real resistivity information and the anisotropy coefficient information of the stratum in the horizontal well environment are extracted based on azimuthal resistivity logging data while drilling, so that the existing logging evaluation data of the horizontal well are perfected. During the comprehensive interpretation and evaluation process of the logging data of the horizontal well, the reservoir oil saturation and the like can be accurately calculated based on the stratum real resistivity and the anisotropy coefficient. As a result, the method provides reliable parameters for reservoir evaluation.

The invention provides a reservoir evaluation classification method and device. The method comprises classifying according to the spatial distribution density of the sample points and the accumulateddistance between the sample points; classifying reservoir multivariate exploration data; the method is simple in concept, the classification effect is superior to that of a conventional clustering algorithm, the clustering method is not applied to the field of petroleum geophysical prospecting, the method has good adaptability to complex multivariate exploration data, the classification effect has high resolution, reliability, robustness and ideal effect, and the method has high application value in the field of oil and gas exploration.

The invention discloses a pressure-limited and discharge-quantity-unlimited fracturing method for increasing the shale gas crack transforming size. The pressure-limited and discharge-quantity-unlimited fracturing method comprises the steps that (1) reservoir evaluation before fracturing and real-time evaluation of the fracturing construction earlier stage are conducted; (2) a layered small testing fracturing test is conducted on a straight well guiding well; (3) simulation analysis is conducted through software MEYER; (4) normal fracturing construction is conducted, and in the construction midway, one-time or two-time instantaneous pump stopping is conducted; (5) the wellhead construction anticipated pressure is derived reversely through the well bottom pressure; (6) as long as the wellhead construction pressure is lower than the anticipated pressure of the step (5), the discharge quantity is increased to enable the wellhead pressure to approximate the anticipated value; and (7) if the wellhead construction pressure after the discharge quantity is increased still does not reach the anticipated pressure, the construction sand-liquid ratio is increased. According to the pressure-limited and discharge-quantity-unlimited fracturing method for increasing the shale gas crack transforming size, the various problems caused by using a discharge-quantity-limited method can be solved, so that the actual after-fracturing transforming size of a shale reservoir is increased, and the complexity of man-made cracks is improved.

The invention discloses a nuclear magnetic resonance spectrum coefficient based method for calculating saturation of irreducible water, and belongs to the field of reservoir evaluation. The method comprises the following steps: first conducting nuclear magnetic resonance (NMR) standard T2 test experiment on the core to obtain a core NMR T2 distribution spectrum, and using a weighing method to calculate actual irreducible water saturation STURE of a rock specimen; determining undetermined coefficients under different aperture components by using NMR T2 spectrum and irreducible water saturation STURE of the rock specimen through a least squares method; establishing and calculating a new model of irreducible water saturation; and finally acquiring the calculated irreducible water saturation of the rock specimen. The present invention realizes determination of reservoir irreducible water saturation by using nuclear magnetic resonance spectrum coefficient method; by comparing the calculation result of the new model, the reservoir irreducible water saturation can be obtained more accurately and more reliably; and the method provides reliable reservoir parameters for oil exploration and reservoir development evaluation.

The invention discloses a fracturing oil displacement method for improving the economic efficiency of thin-difference reservoir recovery of an old oil field. The method is based on oil reservoir evaluation and residual oil description. A fracturing measure process scheme is designed in a targeted manner, and a fine control fracturing technology is adopted the fracturing oil-displacing agent is injected into the stratum at high strength within a short time, the fracturing oil-displacing agent with good fracturing performance and a good displacing and washing effect is used for pressing open thestratum to generate cracks, meanwhile, a large amount of oil permeates into the stratum, the stratum energy is increased, stratum remaining oil can be efficiently displaced and washed, and then the recovery ratio of a thin-difference oil layer is greatly increased. According to the method, reservoir transformation, energy supplementing and chemical flooding washing are combined into a whole, therecovery efficiency can be comprehensively improved, construction parameters and fracturing oil displacement agent performance in fracturing can be reasonably optimized, and fracturing-injection-flooding washing integrated novel technology for improving the recovery ratio, which realizes the organic combination of a reservoir transformation technology and oil reservoir development integration andimproves the economic efficiency of thin-difference reservoir recovery of an old oil field.

The invention provides a new method for evaluating the reservoir fluid property through the gasometry component ratio based on gas logging data. The method includes the steps of firstly, calculating ITn serial indexes; secondly, explaining the application method according to the ITn serial indexes; thirdly, drawing an explanation drawing according to the well depth corresponding to an IT index. Compared with the prior art, according to the method, great innovation is achieved for an existing triange method, and a new explanation drawing application form is established. The quantized ITn serial indexes can be combined with other gasometry parameters and even logging parameters, use is flexible, and convenience is provided for hydrocarbon reservoir evaluation.

A method for comprehensively evaluating a crack-hole type carbonate reservoir based on karst parameters comprises the following steps: firstly, establishing a reservoir concept mode, and identifying the crack-hole type carbonate reservoir; making an applicable classification evaluation standard for the reservoir, and performing semi-quantitative-qualitative division and evaluation on the single well reservoir; carrying out carbonate rock crack evaluation and prediction through ancient structure stress field analysis to obtain key crack parameters of reservoir evaluation; characterizing two karst parameters, namely the vertical karst rate and the karst strength, and conducting calculating to obtain key karst parameters for reservoir evaluation; integrating the sedimentary microfacies type,the key crack parameters and the key karst parameters, and carrying out multi-factor reservoir development probability evaluation by utilizing a superposition probability evaluation method; and underthe constraint of a crack evaluation prediction plane graph, combining a single well reservoir evaluation result and a reservoir development probability evaluation result to realize reservoir evaluation and prediction on the plane. The method has the advantages of being high in comprehensiveness, quantitative in evaluation and operable.

The invention provides a method for evaluating brittleness of a shale reservoir and belongs to the technical field of nonconventional oil and gas reservoir evaluation. The method comprises the following steps: acquiring an elastic parameter and a brittleness mineral parameter of the shale reservoir to be evaluated, wherein the elastic parameter comprises Young modulus*density; carrying out cross analysis on the Young modulus*density and other elastic parameters and / or the brittleness mineral parameter and according to a cross analysis result, determining a value domain of the Young modulus*density; according to p-wave and s-wave impedances obtained by prestack inversion, establishing a Young modulus*density attribute volume; evaluating the brittleness of the shale reservoir to be evaluated by the Young modulus*density attribute volume in the value domain. According to the invention, accuracy of evaluating the brittleness of the shale reservoir is improved, prediction on planar distribution of the brittleness in the integral research region is implemented and the method has wide application prospect in the field of exploration and development of shale gas.

The invention discloses a reservoir diagenetic simulation system. The reservoir diagenetic simulation system comprises a sample room system which is used for providing solid samples, gas samples, and liquid samples needed by a reservoir diagenetic simulation experiment, an assembly control device which is connected with the sample room system, and used for controlling the temperature and pressure of the solid samples, the gas samples, and the liquid samples in the sample room system and controlling the injection, exhaust, and quantity of the gas samples and the liquid samples, a sampling device which is connected with the assembly control device and is used for taking the gas samples and the liquid samples from the sample room system under the control of the assembly control device, and a data collection and processing device which is connected with the sampling device and is used for setting parameters of the gas samples and the liquid samples taken out by the sampling device and collecting and processing data. The reservoir diagenetic simulation system is fully functional, close to the actual geological conditions, and high in automation degree, and can provide theoretical basis for reservoir evaluation prediction and effective reservoir evaluation.

The invention relates to a double lower limit low permeability-compact sandstone reservoir classification method, comprising: calculating physical property lower limit of reservoirs of different depths, obtaining a changing curve of the physical property lower limit long with depth change; identifying day economy capacity lower limit and a function thereof changing with the depth, determining a relation between the day economy capacity lower limit and the porosity and permeability of the reservoir; obtaining an economic capacity curve of the porosity and permeability of the reservoir changing with depth according to the relationship between the function and the relation; respectively establishing a relational graph of the day economy capacity porosity lower limit with the effective reservoir porosity lower limit and the depths, and a relational graph of the day economy capacity permeability lower limit with the effective reservoir permeability lower limit and the depths. The classification method provided by the present invention effectively solves application of reservoir physical property lower limit changing with depths in reservoir evaluation, combines drilling and economy capacity in production, and helps to establish an objective, accurate, intuitive and easy reservoir classification evaluation program.

The invention relates to a complex lithology identification method and system based on a decision tree data mining algorithm. It relates to the technical field of oil exploration reservoir evaluation. The method includes: establishing a lithology profile of a closed coring well section, forming a lithology identification data set according to the lithology profile; performing data preprocessing on the lithology identification data set; and using different logging parameters to correspond to lithology Identify different lithologies in the data set; perform data mining on the lithology in the preprocessed lithology identification data set to form a tree identification model, so that complex Lithology is identified. The present invention forms the lithology identification data set through the lithology profile, performs unified lithology identification, and corresponds to different logging parameters according to the characteristics of lithology, and forms a clear and clear tree after data mining on the lithology identification data set The identification model can perform accurate lithology identification under complex lithology conditions.

A Gas Reservoir Evaluation and Assessment Tool utilizes an Analytical Engine to produce predictions of pressure values and other production data at any point in space and at any point in time in a reservoir. A computer system, such as a workstation, stores a Gas Reservoir Evaluation and Assessment software which includes the Analytical Engine and responds to input data (which includes a reservoir description and fluid properties) by generating an output record which represents a prediction of the pressure values and other data at ‘any point in space’ and at ‘any point in time’ in a reservoir. The Analytical Engine will first calculate a pressure value in 1D for a single layer of a reservoir at a single point in space and time; it will then calculate a pressure value in 1D for multiple layers in the reservoir at the single point in space and time; it will then calculate a pressure value in 2D for the multiple layers at the single point in space and time; it will then calculate a pressure value in 3D for the multiple layers at the single point in space and time; and it will then calculate a pressure values in 3D for multiple layers not only at a single point in space but also at any future point in time.