344 results about "Facies" patented technology

An apparatus and method for obtaining facies of geological formations for identifying mineral deposits is disclosed. Logging instruments are moved in a bore hole to produce log measurements at successive levels of the bore hole. The set of measurements at each such level of the bore hole interval is associated with reference sample points within a multidimensional space. The multidimensional scatter of sample points thus obtained is analyzed to determine a set of characteristic modes. The sample points associated with characteristic modes are grouped to identify clusters. A facies is designated for each of the clusters and a graphic representation of the succession of facies as a function of the depth is thus obtained. To identify the clusters, a "neighboring index" of each log measurement point in the data set is calculated. Next, small natural groups of points are formed based on the use of the neighboring index to determine a K-Nearest-Neighbor (KNN) attraction for each point. Independently of the natural group formation, an optimal number of clusters is calculated based on a Kernel Representative Index (KRI) and based on a user-specified resolution. Lastly, based on the data calculated from the prior steps, final clusters are formed by merging the smaller clusters.

A method for creating a reservoir facies model is disclosed. A S-grid is created which is representative of a subterranean region to be modeled. A training image is constructed which includes a number of facies. The training image captures facies geometry, associations and heterogeneity among the facies. A facies probability cube corresponding to the S-grid is derived from a geological interpretation of the facies distribution within the subterranean region. Finally, a geostatistical simulation, preferably a multiple-point simulation, is performed to create a reservoir facies model which utilizes the training image and facies probability cube and is conditioned to subsurface data and information. Ideally, the facies probability cube is created using an areal depocenter map of the facies which identifies probable locations of facies within the S-grid.

A method for estimating properties of porous media, such as fine pore or tight rocks, is provided. The method comprises digital image scanning of sequential sub-samples of porous media at progressively higher resolution to systematically identify sub-sections of interest within the original sample and then estimate properties of the porous media. The resulting properties of the porous media then can be optionally upscaled to further estimate the properties of larger volumes of the porous media such as rock facies or subterranean reservoirs. A system operable for conducting the method also is provided.

The invention of present speaks to a method and system for the prevention of unwanted wireless telecommunications which is implemented as part of a computer program product in (preferentially) the telecommunications operator's network, which meets and / or exceeds much of current, proposed and even academically anticipated legislative (and by necessity, technical) criteria, and indeed, thereby complies with the broader body of prima facie consumer requirements associated with wireless telecommunications spam filtering. Indeed, the invention provides for a remarkably flexible and customizable advance in the art through the utilization of a progressive filtering algorithm. This algorithm offers both the subscriber and the service provider with the capability to block and / or extract potentially harmful or unsolicited SMS, MMS and other such messages on the basis of an extensive range of parameters and rules.

A method for creating a facies probability cube is disclosed. A S-grid containing facies is first created. The grid includes layers of cells and columns of cells. Vertical facies proportion data for the layers of cells is derived from sources such as well data, conceptual vertical geologic sections and graphs describing the proportion of facies found in each of the layers. Areal depocenter maps are created which have defined boundaries to create depocenter regions in which respective facies are likely to occur. Ideally, the boundaries for the depocenter regions for each of the facies are sequentially and independently defined. Horizontal or map facies proportion data are generated for the columns of cells preferably by filtering the depocenter regions so that the proportion of each of the facies ranges from a maximum value to a minimum value. The vertical and horizontal facies proportion data are then integrated to create a facies probability cube in which the cells are assigned probabilities for the occurrence of facies.

A method for generating one or more geological models for oil field exploration. The method includes receiving one or more well facies logs, a vertical facies proportion curve, a lateral proportion map, a variogram model and a global target histogram. The method then includes generating a facies probability cube using a modified Sequential Gaussian Simulation (SGSIM) algorithm, the well facies logs, the vertical facies proportion curve, the lateral proportion map and the variogram model. After generating the facies probability cube, the method includes matching the facies probability cube to the global histogram and generating the geological models based on the matched facies probability cube.

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.

A method and a system are provided to prepare a plurality of cuttings or other rock fragments or other porous media, such as cuttings from a drilling interval or multiple intervals, for computer tomographic scanning at the same time. A method and system also are provided to allow organization of mass quantities of cuttings or other rock fragments obtained from intervals of a well to more accurately categorize the cuttings to assist selections thereof for more detailed digital rock analysis, such as using SEM and FIB-SEM systems, are provided. A method and system also are provided to allow characterization of facies occurrence frequency of a depth interval using drill cuttings or other rock fragments. Computerized systems, computer readable media, and programs for performing the methods are also provided.

The invention relates to an exploration method of faulted basin slope oil reservoir distribution and belongs to the field of oil exploration technology. In allusion to the later period of faulted basin exploration, through statistics of related information of source rock, fluid potential, sedimentary rock phase and fault in a target area and according to the principle of source potential conduction, the above information is comprehensively analyzed so as to determine a favorable oil reservoir distribution area in the target area. Forward oil control exploration limitations are broken and are shifted to negative structure and positive structure. Comprehensive analysis is carried out according to an oil source, fluid potential, sedimentary facies distribution and fault occurrence in the area, the slope is evaluated, and a favorable exploration target area is selected.

Method for gradually modifying a geological model representative of an underground reservoir so as to respect fixed average proportions of these lithologic facies.A group of facies referred to as selection and a subgroup of facies referred to as association are selected. A transformation parameter is defined by the ratio between the average proportions of the facies of the association and those of the selection. Within the context of history matching, a difference between measured dynamic data values and values calculated by means of a flow simulator from the geological model is measured. An optimization algorithm is used to deduce therefrom a new value for the transformation parameter that minimizes this difference and this transformation is applied to the lithologic facies of the selection. The modification can be applied to the entire model or to a given zone.

The invention provides a geological modeling method for horizontal wells in ultra-low permeability tight reservoirs, which includes the following steps: (1) the well information data, single-well logging data, well point layer data and sedimentary microfacies data of the horizontal section of a horizontal well are acquired, and the reservoir stratum parameters of the horizontal section of the horizontal well are determined; (2) vertical wells are added on the horizontal section of the horizontal well to control the horizontal section structure, so that an initial structure model is obtained; (3) a reservoir facies model is created by utilizing the sedimentary microfacies data and in combination with geological knowledge and achievements; (4) the reservoir stratum parameters of the horizontal section of the horizontal well are utilized for analysis, and a reservoir property model is created; (5) the actual locus profiles, production performance and numerical simulation of the horizontal well are applied to verify the geological models, so that a three-dimensional geological model of an exploitation area of the horizontal well is obtained. The method provides a data source for the research on the characteristics of the planar distribution of sand, accurately describes the planar distribution trend and vertical facies distribution trend of a reservoir stratum, increases the precision of the prediction model, and lays a foundation for the optimization of an ultra-low permeability oil reservoir exploitation technology policy and fine injection and production adjustment.

The invention is a method for determining deposition characteristics and distribution of reservoirs by combining logging and seismic information. The method comprises the following steps: on the basis of single-well middle-term and middle-short-term deposition cycle division, inter-well fitting is carried out on a deposition cycle interface, correction is carried out with the use of a seismic structural surface, and the trend surfaces of top-bottom interfaces of corresponding grid cells are obtained; and logging attribute parameters in grid cells in the vertical direction are roughly calculated to obtain a unique logging data thinning value, the minimum well spacing of a work area is selected as the step length of the lateral extrapolation distance, and inter-well interpolation and fitting are carried out to obtain a three-dimensional hierarchical coarsening logging data volume reflecting well logging facies or deposition characteristics of reservoirs. According to the method of the invention, single-well reservoir vertical grid dissection in three-dimensional reservoir geological modeling and multi-phase inferior time deposition cycle structure and frame in geo-science, an inside-grid logging attribute sampling point coarsening technology and a geological method, and the single-well-point vertical grid thinning logging attribute value and a multi-well spatial interpolation algorithm are closely combined so as to obtain a three-dimensional hierarchical coarsening analysis data volume capable of reflecting well logging facies or deposition characteristics and change of reservoirs, thus realizing matching and comparative interpretation on the basis of closely combining logging and seismic data.

A computer-implemented method and system for simulating reservoir property trends, including petrophysical trends within facies geobodies, is provided. One embodiment includes discretizing a range of values of the reservoir property to be modeled into at least two categories and utilizing the categories to discretize the associated well data and training image into categorical well data and a categorical training image. An embodiment includes applying MPS simulation using the categorical training image on a stratigraphic grid of nodes discretizing the reservoir volume to create a categorical property model. The embodiment additionally includes applying variogram-based simulation in each sub-region of the categorical property model to create a reservoir property model that reproduces the category histogram of each associated sub-region and models the reservoir property trends.

A roadmap for a field development strategy for optimal recovery is provided in a high quality 3D geological model. This geological model combines geological attributes, pore and rock properties for an optimum 3D representation of the reservoir thousands feet beneath the surface. The model is based on the pertinent geological facies, derived from well core description and detailed studies of rock, as well as fluid and pore properties (Full Pore System) obtained from laboratory analyses of core material and well log data. These data differentiate various important pore throat and pore body regions and relationships, i.e., macroporosity and microporosity. Understanding hydrocarbon volumes in the various pore type groups and then establishing proper recovery techniques through focused laboratory studies yields a field development strategy that can significantly increase hydrocarbon recovery from a reservoir.

A method of modifying a geological model representative of an underground reservoir is disclosed which respects average proportions of the lithologic facies imposed by a production data calibration process which has application to petroleum reservoir development. A geographical zone Z is defined within the geological model and an average proportion in zone Z allowing the production data to be calibrated is determined for k facies, with an optimization process. The proportions of these facies are modified using a block indicator cokriging method constrained by the average proportions to be respected. A new geological model constrained by the modified facies proportions is simulated and the development of the underground medium is optimized by the simulated model.

The invention relates to a method for history matching a facies geostatistical model using the ensemble Kalman filter (EnKF) technique. The EnKF is not normally appropriate for discontinuous facies models such as multiple point simulation (MPS). In the method of the invention, an ensemble of realizations are generated and then uniform vectors on which those realizations are based are transformed to Gaussian vectors before applying the EnKF to the Gaussian vectors directly. The updated Gaussian vectors are then transformed back to uniform vectors which are used to update the realizations. The uniform vectors may be vectors on which the realizations are based directly; alternatively each realization may be based on a plurality of uniform vectors linearly combined with combination coefficients. In this case each realization is associated with a uniform vector made up from the combination coefficients, and the combination coefficient vector is then transformed to Gaussian and updated using EnKF.

The invention provides a dessert reservoir forecasting method and forecasting device. The method includes the steps: delineating the distribution range of a favorable sedimentary facies belt of a target layer based on ancient landform restoration technology of seismic sequence stratigraphic interpretation; forecasting the spreading range of main channel sand within the distribution range of the favorable sedimentary facies belt based on seismic attribute quantitative analysis technology of forward modeling; forecasting reservoir physical property distribution within the spreading range of the main channel sand based on CRP (common reflection point) gather optimization pre-stack elastic impedance inversion technology. Multiplicity caused by directly forecasting reservoir physical properties by the aid of three-dimensional seismic data in the prior art is reduced, so that low-permeability clastic rock reservoir forecasting accuracy is improved.

The invention discloses a method for identifying a reservoir by combining electrical imaging and a reef geologic model, and belongs to the technical field of marine carbonatite well logging interpretation. The method comprises the following steps of: selecting a carbonatite reef reservoir sedimentary facies model according to a reef reservoir sedimentation model; establishing the correspondence between the reef reservoir sedimentation model and an electrical imaging well logging image characteristic based on an electrical imaging well logging image; establishing an electrical imaging image library of a standard reservoir of the carbonatite reef reservoir; performing rock structure characteristic-based image dynamic enhancement contrast according to images in the electrical imaging image library; and determining a part of a reef phase reservoir, through which a well runs, based on a typical image of an electrical imaging reef phase, and comparing with a typical image of a favorable reservoir to determine the quality of the reservoir. The method greatly improves the coincidence rate of well on-site interpretation and test oil, and is fully applied to various related oil fields in China.

The invention discloses a terrestrial facies shale gas fracture network fracture parameter optimizing method comprising the following steps: S1, based on a large size sample, using a hydraulic fracturing physics simulation test system to design an indoor shale gas hydraulic fracturing physics simulation test, and optimizing indoor shale gas hydraulic fracturing physics simulation test parameters; S2, according to the indoor shale gas hydraulic fracturing physics simulation test optimized test parameters, combining with target block field fracturing construction conditions, optimizing terrestrial facies shale gas hydraulic fracturing construction parameters, and making a terrestrial facies shale gas fracturing scheme; S3, analyzing the difference between field fracturing construction conditions and laboratory conditions, and applying the parameter optimized result in the field fracturing construction, thus obtaining a complex fracture network. The method combines parameter optimizing test under laboratory conditions with field construction parameter optimization, thus adding crack complex level in the terrestrial facies shale gas fracturing process, artificially increasing permeability, and obtaining a more complex fracture network closer to reality.

Facies in wells in areas of a hydrocarbon reservoir are predicted or postulated. Artificial neural networks are utilized to build a training image based on rock phases which are described and interpreted using existing data obtained from certain wells in the reservoir, and also well log characteristics of those same wells for each rock facies. Well logs from which wells where no well core data has been collected are then analyzed against the training image and the rock facies in the non-cored wells are postulated. The cost and also the possibility of damage to the wells from extraction of the core rock during drilling are avoided.

The invention discloses a formula and a preparation method suitable for preparing fracturing fluid from continental facies shale gas well fracturing flow-back fluid treatment water, belonging to the technical field of oilfield chemistry. The formula for preparing the fracturing fluid from the continental facies shale gas well fracturing flow-back fluid treatment water is provided aiming at the deficiencies existing in the prior art. The formula consists of base fluid and a cross-linking agent, wherein the cross-linking agent is an anti-temperature mineralization-degree-resistant cross-linking agent, and the formula comprises 0.4%-0.6% of cross-linking agent and the balance of base fluid; the base fluid consists of the following components in percentage by mass: 0.4%-0.45% percent of hydroxypropylguar gum, 0.3%-0.5% of gas well clean up additive, 1%-2% of stabilizer, 0.1%-0.15% of bactericide, 0.1%-0.2% of modifier, 0.03%-0.05% of antisludging agent, 0.6%-0.8% of gel breaker and the balance of the continental facies shale gas well fracturing flow-back fluid treatment water. The cyclic utilization of the continental facies shale gas well fracturing flow-back fluid treatment water is realized through the formula of the fracturing fluid, and the prepared fracturing fluid has good sand-carrying property.

The present invention discloses a shale gas single well geological comprehensive evaluation method. The method comprises the following steps: stratigraphic division and comparison and sedimentary facies analysis; shale gas reservoir forming condition and main controlling factor analysis; shale fragility analysis; evaluation grading according to a shale gas selection region evaluation parameter table suitable for exploration and development of a research region; and finally, optimization of the layer segments of profitability and the ranges of profitability. Through adoption of the technical scheme, the shale gas single well geological comprehensive evaluation method can objectively and roundly evaluate the shale gas single well geological condition and can provide detailed reference data for well exploitation and geological evaluation of adjacent shale gas single wells and shale gas regions in the later period so as to break the limitation of the current evaluation method, define the shale gas single well geological comprehensive condition and avoid unnecessary waste.

The invention provides a multivariate well logging computing method for the total organic carbon and the hydrocarbon generating potential of hydrocarbon source rocks in salt-lake facies. The method comprises the steps of conducting standardization and normalization on logging curves of different wells, conducting core proper-horizon restoration on hydrocarbon source rock total organic carbon data measured through experiments, classifying the hydrocarbon source rocks in the salt-lake facies, reading logging curve data, obtained after core proper-horizon restoration correction, of total organic carbon experimental points, conducting R-type hierarchical clustering analysis on the logging data and the total organic carbon of the rocks, establishing logging evaluation models of the TOC according to different lithological characters, and conducting computing to obtain TOC data so as to work out rock pyrolysis data. The multivariate well logging computing method for the total organic carbon and the hydrocarbon generating potential of the hydrocarbon source rocks in the salt-lake facies can be used for evaluating the mass and the hydrocarbon generating potential of the hydrocarbon source rocks, of special lithological characters, in the salt-lake facies, and the method can be applied to provide a great number of evaluation data for hydrocarbon source rock evaluation and oil and gas resource quantity evaluation.

The invention provides a recognition method and a device of effective reservoirs of the dolomite of the karstic weathering crust. The method comprises the following steps of: establishing a sedimentary facies belt interpretation model for reservoir logging of the dolomite of the weathering crust; establishing a characteristic chart library for different sedimentary facies belts in the reservoirs of the dolomite of the weathering crust; establishing corresponding relation of different karstic facies belts and effective reservoirs on the basis of typical characteristics of electric imaging of different karstic facies belts and the actual test oil data in an oil field; carrying out recognition on the effective reservoirs in a two-dimensional plane determined by the inclination angle of the formation interface and the productivity of the effective reservoirs; carrying out calculation of mean values and variances on the basis of a porosity spectrum of the electric imaging, determining lower limit values of the porosity and the variance of the effective reservoirs in the two-dimensional plane formed by the mean values and the variances, and carrying out further recognition on the effective reservoirs; recognizing the effective reservoirs of the dolomite of the weathering crust by combining data such as the developmental state of the sedimentary facies belts in the reservoirs of the weathering crust, the size of the inclination angle of the overlying formation and the distribution condition of the mean values and the variances in the porosity spectrum of the electric imaging.

The invention discloses a method of determining oil and gas productivity based on oil and gas control effects of petrophysical facies, the method comprising obtaining reservoir physical property characteristic parameters, including porosity [phi], permeability K and single well production h reflecting the oil and gas productivity of a reservoir, of each exploration point in a research area through analysis; based on the obtained reservoir property characteristic parameters [phi] and K through analysis, and under the correction of actual [phi] and K of a single well in geophysical logging, establishing a reservoir property plane distribution diagram; based on the obtained reservoir property characteristic parameters [phi], K and h through analysis, establishing a relationship graph among [phi], K and h; based on the relationship graph among [phi], K and h, conducting quantitative standardization on petrophysical facies data of the reservoir, establishing a board chart of standardized values FI and h of the petrophysical facies, and conducting verification and feasibility analysis on the board chart of FI with h; and based on the reservoir property plane distribution diagram, and with combination of the board chart of FI with h, determining the oil and gas productivity of each exploration point of the reservoir so as to determine the oil and gas productivity of the entire research area. The method provided by the invention solves the problem of difficulty in predicting the oil and gas productivity of reservoirs, and provides important technical support for reservoir oil and gas research.

The invention relates to a petroleum migration pathways quantitative evaluation method. The method combines geological analysis and hierarchical analysis. Parameters affecting the migration performance of faults and sand bodies in fault-sand body migration pathways are considered more comprehensively, including fault mobility, lithology opposition relationship between the two sides of faults, section morphology in the longitudinal direction, section morphology in the moving direction and level of fault as well as sand body effective thickness, porosity and permeability, sand body top morphology, sand body slope and sedimentary facies. On the basis of fault and sand body migration pathways multiple-parameter geological analysis, a hierarchical analysis mathematical method is adopted, the roles of the multiple parameters in the migration pathways are considered in a unified way, and quantitative evaluation of the fault-sand body migration pathways is realized. Meanwhile, the migration performances of unit migration pathways of different structures are compared quantitatively, and a favorable exploration area is easier to select. Compared with the existing evaluation method, geological analysis and the quantitative evaluation of the migration pathways are more accurate, and the success rate of petroleum exploration is effectively improved.

The invention discloses a three-dimensional human face change simulation method which comprises the steps of constructing a three-dimensional facies cranii database; standardizing a facies cranii model; extracting a human face aging and weight change rule; and simulating the human face aging and weight change. According to the three-dimensional human face change simulation method, aging and weight change are simultaneously considered; and human experience change caused by age increase and weight change can be simulated. According to the three-dimensional human face change simulation method, simulation for aging and weight change of the three-dimensional human face is firstly realized through utilizing facies cranii CT data. According to the three-dimensional human face change simulation method, on condition that three-dimensional time sequence human face data are in shortage, facies cranii data of different persons can be used; the effects of different persons are eliminated from the facies cranii data; and furthermore the aging role and the weight change role of the human face can be extracted. Furthermore an algorithm which is adopted in the three-dimensional human face change simulation method has advantages of simple and high-efficiency operation, and accurate simulation result. The three-dimensional human face change simulation method can be used for searching criminals who have absconded for many years in criminal investigation. The three-dimensional human face change simulation method can be performed in association with medical cosmetic surgery. Furthermore the three-dimensional human face change simulation method can assist cosmetic design, etc. in film and television entertainment.

The invention discloses a method for analyzing the rock facies of a shale bed section. The method includes the following steps that a classification and naming rule of the rock facies is established; the rock facies boundary is recognized; the types of the rock facies are divided; the characteristics of the rock facies are described, and thus the favorable rock facies can be made definite; the distribution range of the rock facies is analyzed; comprehensive assessment of the rock facies is conducted. The analysis method is simple, clear, practical and easy to operate. By the adoption of the analysis method, the exquisite layering problem of a large set of extremely-thick and monotonous shale bed section can be solved quickly, and thus 'selecting the best from the splendid' in layer commenting and section choosing as well as in fracturing layer choosing using the rock facies as the unit is carried out based on the geology, development and engineering integrated principle, and therefore the economic aims of decreasing costs and increasing benefits and the aim of improving the single-well production capacity of shale oil and gas can be achieved.

The invention discloses a seismic information based method for determining coalbed methane enrichment sedimentation control effect. The method uses three-dimensional seismic data, applies seismic sedimentology interpretation techniques to coal-bearing stratum, predicts sedimentary microfacies of a target interval, and predicts a trend of gas content change in the target interval in the area by using relative relationship between sedimentary and lithological changes and gas content, thereby revealing the sedimentation control effect of coalbed methane. The method introduces seismic sedimentology into studies of the coal-bearing stratum, realizes fine characterization of sedimentary facies belts distribution and lithologic boundaries, analyzes and studies the coalbed methane enrichment sedimentation control effect, and provides strong technical support for the exploration and development of favorable areas for coalbed methane enrichment.