77 results about "Reservoir modeling" patented technology

A method for estimating and / or reducing uncertainty in reservoir models of potential petroleum reservoirs comprises receiving the results of a stochastic seismic inversion, and transforming the inversion data into a form suitable for reservoir modelling and flow simulations, while honoring inter-property and inter-layer correlations in the inversion data as well as measured well data and other geological constraints.

In one embodiment of the present invention, a plunger for use in a plunger lift system of an oil or natural gas well is described. The plunger includes one or more sensor assemblies, each including one or more sensors for measuring various physical and operational conditions during the operation of the well. The data acquired from the sensors is stored in memory within the sensor assemblies and downloaded to the plunger lift system controller when the plunger is located in the catch / lubricator. The data can then be analyzed by the controller or other computer to vary the well's operating parameters to maximize the well's operating efficiency and the data can be used in reservoir management, such as transient testing, reservoir modeling and interference testing.

The invention provides a fissure-cave type carbonate-reservoir reservoir body modeling method, and belongs to the field of carbonate reservoir exploitation geology. The method comprises the steps of (1) distinguishing karst cave reservoir body development segment in a single well; (2) building karst zone models along the vertical direction, building ancient landform unit distribution models in a plane; (3) respectively imitating three-dimensional distribution of the karst cave reservoir body in different karst zones and different ancient landform units, obtaining a three-dimensional distribution model of the karst cave reservoir body of a modeling target stratum; (4) counting development occurrence of a fissure reservoir body and single-well fissure development density; and (5) under control of a fault, building a three-dimensional discrete distribution model of the fissure reservoir body. According to the fissure-cave type carbonate-reservoir reservoir body modeling method, accuracy of the class of reservoir modeling is improved, a true condition of the reservoir is approached in a more objective mode, and important practical significance is provided for exploitation of the reservoir.

A multiple point simulation technique for generating a model realization of a subterranean formation having different facies is described which uses a non-stationary training image which reflects facies spatial trends across the formation. The realization is formed by sequentially populating each cell; a facies pattern of neighboring cells is identified for each cell in the model grid, and then corresponding facies patterns identified in the training image. The probability of a target cell in the model grid having a given facies is calculated based on the proportion of occurrences of the corresponding facies pattern where the central cell has that facies. The contribution of each corresponding facies pattern occurrence in the training image to this proportion or probability is weighted according to the distance between its central cell and the training image cell corresponding in location to the target cell in the model grid.

This invention relates to petroleum reservoir characterization. It uses a novel system and method to generate a system of reservoir models, and then use a series of simulation techniques to simulate the models. The models are refined through each simulation and comparison step by comparing the results of the simulation with the known data from the reservoir. The invention can be applied to different reservoirs which have different known properties. Simulation techniques such as EM test forward calculation, stochastic reservoir modeling, streamline forward calculation are all candidates of simulation methods disclosed in the invention.

Production based saturation models of subsurface reservoirs of interest are formed in a computer based on data from well logs, production data and core data. Data of these types obtained over a period of time are used to form 4-D actual or measured production based saturation models of a reservoir illustrative of fluid movement in the reservoir over time. Simulation models of fluid saturation of the reservoir are also formed for comparable times. Composite models of the production based saturation models and the simulation models are formed for analysts to evaluate accuracy of the simulation models of the reservoir taking into account production experience. The simulation models can then be adjusted for changes noted in the reservoir and based on how gas and water have actually moved within the reservoir over time.

A method and system for well test design and interpretation, comprising a testing manager system, which includes at least one of testing hardware and gauge metrology; a geological model coupled to the testing manager system; a dynamic and static engineering data acquisition system coupled to the geological model; and a reservoir modeling system coupled to the dynamic and static engineering data acquisition system to generate a reservoir model. Also provided is a method and computer program for controlling, driving, and enabling the devices, systems, and subsystems presented herein through interaction with a human user, or the like.

A method is disclosed of characterizing a well using a series of measurements taken along the sandface of that well in order to optimize a well model. The method may comprise providing a well model with a plurality of adjustable physical parameters, providing a data set made up of a plurality of sandface measurements, and running the well model with different combinations of adjustable physical parameters so that the results of the well model substantially match the results of the sandface measurements. In one embodiment, the method may comprise creating a communication pathway between the surface and the sandface including an inductive coupler. A further step may include pre-processing the plurality of the sandface measurements. In addition, a further step may be to establish or set at least one control device in order to change the flow characteristics of the production fluid in the well.

The invention discloses a method for analyzing sand bodies in reservoirs based on an inversion technique of the sedimentary dynamics under the condition of sparse wells. The method is characterized in that through building a sand-body inversion model of sedimentary dynamics based on a principle of three-dimensional sedimentary transport geology and considering the control action of fluid velocity on sedimentary evolution and the reconstructive function of tectonic movements, the analysis on the distribution evolution of sand bodies in complex sedimentary basins under the condition of sparse wells can be realized. The method is implemented through the following steps: re-simulating the relationship between the three-dimensional attribute distribution data of a single sand layer of a reservoir and the time variation; carrying out variance making on the pre-simulated results and the results obtained by simulating well-point data as well as well logging interpretation and bore-hole data of the reservoir; according to the concept of a negative gradient search algorithm, modifying the terrain, flow field and source distribution of the reservoir; and operating the steps until the accuracy conditions of reservoir modeling are satisfied. The method disclosed by the invention provides a basis for the development of analysis on sand bodies in basin reservoirs under the condition of sparse wells, and is especially suitable for being applied to the research on sand bodies in sea basins with less drill holes.

The present invention discloses a tight sandstone reservoir modeling method. The tight sandstone reservoir modeling method comprises the steps of: taking drilling and logging information as constraints to perform lithology inversion based on post-stack three-dimensional seismic interpretation data to obtain a plurality of inversion data volumes; comparing the inversion data volumes with a logginginterpretation conclusion to optimize an inversion data volume which can most reflect different lithologies; determining a lithology partition criterion according to the dependency of lithology data interpreted from the logging and the values in the optimized inversion data volumes; obtaining a three-dimensional logging lithology data volumes through lithology identification of the values of the inversion data volumes in each three-dimensional grid in the three-dimensional space based on the lithology partition criterion; setting virtual wells at the main body centers of sedimentary facies andthe internal portion of each boundary, and determining the values in the three-dimensional lithology data volumes corresponding to the virtual wells as the lithology data of the virtual wells; and taking the lithology data of the actual drilling wells and the virtual wells as modeling basic data to perform random simulation modeling to obtain a three-dimensional reservoir lithology model so as toachieve the purpose of fine description of the reservoir.

The invention discloses a modeling method for a sand shale interbed type sedimentary body reservoir architecture. The method comprises three aspects of hard data control, layered modeling, and reservoir and interlayer nesting, wherein the layered modeling mainly comprises reservoir modeling, spacing layer modeling, and interlayer modeling. According to the modeling method, thin layer division is performed by adopting a half amplitude point based thin layer division principle, so that the defect that true thicknesses and depths of a reservoir and a spacing layer cannot be obtained in a conventional method for determining a boundary line of a thin layer based on relative maximum of natural gamma and / or positive anomaly of natural potential is overcome; and the hard data control is adopted for architecture modeling, so that a demarcation point of sand shale is accurately positioned, three-dimensional spatial distribution of single sand bodies and sub sand bodies is accurately depicted, the architecture effect is good, the precision is high, the difficulty in development is lowered, and the development benefits are increased.

The present disclosure describes a method that improves the long-range geobody continuity in Multiple Point Statistical methods, wherein the coarsest multi-grid level cells are simulated in a regular path, and the subsequent level cells are simulated in a random path as usual. The method is general and is applicable to different cases: such as hard data conditioning, soft data conditioning, non-stationarity modeling, 2 or more than 2 types of facies modeling, and 2D and 3D modeling. The method is particularly useful in reservoir modeling, especially for the channelized systems, but can be generally applied to other geological environments.

The disclosure is directed to a method of representing fluid flow response to imposed conditions in a physical fluid reservoir through wells. The invention utilizes techniques and formulas of unprecedented accuracy and speed for computations for a fundamental element in analysis of fluid movement through subterranean reservoirs—the calculation of Green's and Neumann functions in finite three-dimensional space. The method includes modeling of pressure and / or flow rate observables at wells in said reservoir using an easily computable, closed-form Green's or Neumann function for a linear well segment in arbitrary orientation within a three dimensional cell of spatially invariant but anisotropic permeability. The method further includes the modeling of fluid flow in the physical fluid reservoir with an assemblage of linear well segments operating in unison with uniform flux density to represent arbitrary well trajectory. The method further includes modeling reservoir flow through one or more linear well segments of non-uniform flux related by a constitutive expression linking pressure distribution and flow rate within the well. The method further includes generalization through integration of easily computable Green's or Neumann functions to represent fractures or fractured wells in modeling fluid flow in a physical reservoir. The system includes modeling fluid flow through a mesh representation of the physical fluid reservoir containing one or more wells represented by easily computable Green's or Neumann functions. The system further includes modeling of flow in the physical reservoir via a numerical method in which the values of pressure and flux assigned to the mesh are related to observables at the well using aforementioned easily computable Green's or Neumann functions. The system further includes the coupling of well and mesh values within the numerical solution method for well observation or feedback control. The system still further includes the localization of the well model to the properties assigned to only those mesh elements penetrated by the well using boundary integral equation methods. The invention also incorporates the addition of transients in fluid flow towards a steady or pseudo-steady state, and use thereof, in the above constructs.

The invention provides a multi-scale facture modeling method. Fractured oil-gas reservoir is a new field in modern oil-gas exploration and development, and fracture modeling becomes a focus and a difficulty in reservoir modeling technology at home and abroad. The existing reservoir fracture modeling method ignores the essential relationship between rock microscopic pore attribute random distribution characteristics and an oil reservoir macroscopic fracture expansion principle, so that effective regional fracture multi-scale three-dimensional information cannot be given out. According to the invention, aiming at the difficulty of multi-scale modeling of fractures, a random expanded finite element multi-scale fracture modeling study based on geological statistics principle and fracture mechanics is planned to be developed, and the multi-scale fracture modeling simulated based on random expanded finite elements is finally realized. The method provided by the invention and the developed software tools contribute to understand reservoir fracture multi-scale characteristics and improve application effects of a reservoir fracture model.

A method for hydrocarbon exploration and extraction is described. Specifically, the method includes using synthesis in reservoir modeling. The method may include obtaining local coordinates associated with a subsurface region. Then, a synthesis is performed with the local coordinates to determine continuous parameters and / or categorical parameters based on the synthesis. Then, a fluid flow simulation is performed from the continuous parameters and / or categorical parameters.

The invention discloses a drilling and logging data depth matching method and system. The drilling and logging data depth matching system comprises a curve processing module, a pseudo three-dimensional seismic interpretation work area creating module, a pseudo seismic interpretation position generating module, a modeling module, a depth matching factor data volume generating module, a data volume matching module and a logging curve conversion module. According to the drilling and logging data depth matching method and system, the problem that logging curve depth matching is low in working efficiency according to an existing software technology method can be solved under the situation of hundreds of drilled wells. The efficiency of logging curve depth matching is remarkably improved, the drilling and logging data depth matching quality is guaranteed by the utilization of the functions of a seismic interpretation system, and reliable basic drilling and logging data are provided for reservoir geological research and reservoir modeling.

The invention discloses a carving method of the fault-karst rock mass of the carbonate rock. The method comprises steps of carrying out post-stack inversion on seismic data to obtain underground wave impedance data; calculating ant attributes of the seismic data; determining an ant attribute threshold representing fracture growth, and according to the ant attribute threshold, carrying out hollowing carving processing on the ant attribute threshold; and by taking the underground wave impedance data as background data, superposing the ant attribute threshold subjected to the hollowing carving processing on the underground wave impedance data, thereby achieving carving of a reservoir body and the fractures. According to the invention, the method is capable of helping oil reservoir geological workers to quite clearly know the underground oil reservoir distribution and filling paths, and data basis is provided for following well position deployment and oil reservoir modeling.

The invention provides a new karst stage judgment method. The karst reservoir is a new field of recent oil and gas exploration and development, and the judgment of karst development stage is the difficulty in a karst reservoir modeling technology at home and abroad. The existing karst stage judgment method mainly takes an exposure marker as basis of judgment, but various karst process forms exist, so that the karst processes caused by factors such as hydrothermal solution are difficult to judge due to the lack of an exposure marker. The invention provides a new method for objectively judging the karst stage by combining a method for judging the filling stage by carbon and oxygen isotopes of karst fillings and a method for judging the karst fluid active stage by inclusion homogenization temperature aiming at the problem of karst stage judgment. A carbon and oxygen isotope discrimination chart and an inclusion homogenization temperature comparison diagram are established by the new karst stage judgment method, so that the karst development stage can be accurately and rapidly judged, the limitation that the traditional karst stage judgment takes the exposure marker as basis is broken through, and the problem that karst stage judgment is difficult under the condition that the underground deep layer is short of exposure marker can be solved.

An electronically stored model for a reservoir can include a plurality of hierarchical levels and a plurality of cells representing corresponding portions of the reservoir. The model can include a dimension and a cell number corresponding to the reservoir. A dimension of a cell of an nth hierarchical level can be defined in terms of a dimension of a cell of a first hierarchical level and an array of vertex coordinates along one or more axes can be generated. The model can include a ratio of dimensions among hierarchical levels for improved reservoir modeling. The model can include a ratio of permeability among hierarchical levels for improved reservoir modeling.

A method and apparatus for generating a simulation grid for a reservoir model based on a geological model comprising horizons, constraints and multiple geological grid cells. A pre-image is generated corresponding to the geological grid cells, the pre-image comprising a surface and the modeling constraints being mapped onto the surface. A constrained two- dimensional grid is generated on the pre-image, the two-dimensional grid comprising multiple grid cells. Simulation layer boundaries are selected from the geological model and the constrained two-dimensional grid is projected onto the simulation layer boundaries. Prismatic cells are then generated to form the three-dimensional simulation grid. The method of generating a grid as herein described may be incorporated in existing reservoir simulators to improve their accuracy.

The invention belongs to the technical field of reservoir modeling for oil field development, and specifically relates to an automatic modeling method for point bar reservoirs based on a meandering ring shape database, which mainly includes: first constructing a meandering ring shape database; Simulate the plane distribution range of the channel belt, and simulate the plane distribution of the meandering ring under the constraints of grid attributes and specified rules; finally, establish a 3D point bar model. The method of the invention realizes the automatic simulation of the point bar in the channel belt, improves the accuracy and efficiency of reservoir characterization, and serves oil field development and production.

The invention provides a method for conducting reservoir property simulation through multi-direction variation function analysis. The method includes the steps that (1), sedimentary microfacies division is conducted according to the regional sedimentary feature; (2), partition is conducted in combination with the reservoir development direction on the basis of the sedimentary microfacies division; (3), variation functions with different phase bands are analyzed respectively for each partition; (4), simulation is conducted on property parameters, such as reservoir porosity and permeability on the basis of the accurate variation function adopting the mode of area dividing and phase belt dividing, and a property parameter model of a reservoir is obtained. By means of the method for conducting reservoir property simulation through multi-direction variation function analysis, the problems that in the process of reservoir property simulation, the meandering river sedimentary sand body is varied and the variation functions are simplex are solved, and a feasible method is provided for fluvial facies reservoir modeling.

The invention discloses a fluid detection method based on shear wave splitting amplitude difference attribute, which includes the following steps: modeling a 3D viscoelastic HTI model thin reservoir,and carrying out forward modeling; based on data of forward modeling, analyzing the amplitude attributes of the fast and slow shear waves of the data; determining the fluid threshold of the amplitudedifference between the fast and slow shear waves through logging data intersection analysis; obtaining a fast and slow shear wave amplitude difference profile according to the amplitude attribute analysis and the fluid threshold; and detecting fluid according to the amplitude attribute analysis and the fast and slow shear wave amplitude difference profile. Through the method of the invention, theproblem that the splitting velocity anisotropy of fast and slow shear waves in a fractured thin reservoir is not sensitive to fluid detection due to short propagation time is solved.