88 results about "Carbonatite" patented technology

A system and method for modeling technology to predict accurately water-oil relative permeability uses a type of artificial neural network (ANN) known as a Generalized Regression Neural Network (GRNN) The ANN models of relative permeability are developed using experimental data from waterflood core test samples collected from carbonate reservoirs of Arabian oil fields Three groups of data sets are used for training, verification, and testing the ANN models Analysis of the results of the testing data set show excellent correlation with the experimental data of relative permeability, and error analyses show these ANN models outperform all published correlations

There is disclosed a method for enhancing recovery of crude oil from a porous subterranean carbonate formation of which the pore spaces contain crude oil and connate water, the method comprising determining an ionic strength of the connate water; and injecting an aqueous displacement fluid having a lower ionic strength than the connate water into the formation.

The invention provides a visual experiment device and method for simulating fracture-vug type carbonatite oil reservoir gas injection. The visual experiment device for simulating fracture-vug type carbonatite oil reservoir gas injection comprises a computer, a camera, a visual core clamping device, a planar light source, a simulation formation water piston container, a stratigraphic simulation oil piston container, a gas piston container, a constant-flux pump, a six-way valve, a pressure meter, a pressure stabilizing tank, a back-pressure valve, an oil, gas and water metering device and a pressure-resistant gas flow meter. The visual experiment device is adopted in the experiment method. By means of the device and method, fracture-vug type carbonatite oil reservoir gas injection can be simulated, production performance of the recovery efficiency is improved, and flow states and distribution conditions of a crude oil phase, a gas phase and a water phase in the gas injection huff and puff process can be observed.

The invention relates to natural gas exploitation technology, in particular to a well spacing method for a karst carbonate reservoir. The method comprises the following steps of: selecting an upper isochronous surface and a lower isochronous surface close to end time of caledonian tectogenesis and starting time of Hercynian tectogenesis; reflecting an ancient landform which is high in the west and low in the east and partially develops residual hills and depressions by using a contour diagram; acquiring seismic data; determining a low relief structure form and an evolution process according to inversion section and cross-well seismic data; dividing sedimentary facies of the carbonate reservoir into sedimentary subfacies and sedimentary microfacies; dividing favorable sedimentary microfacies; determining that the reservoir of each well area is communicated by means of yield of the conventional production well and pressure measurement data; and dividing a favorable well spacing area andplacing well at the area with reservoir thickness of more than 20m. The method has the advantages of rational well spacing, measured drilling ratio of well spacing gas reservoir of 100 percent, drilling success rate of 82 percent and capability of obtaining an industrial gas flow from a lower-palaeozoic gas reservoir section and saving capital.

The invention provides a method for predicting the transversal wave velocity of a carbonatite rock reservoir and relates to the technical field of geophysical exploration. The method comprises the following steps: determining the mineral component, the reservoir porosity as well as the fluid saturation of the reservoir; dividing the reservoir porosity into a rigid porosity, a fracture porosity and a clay porosity; obtaining the parameters of each mineral in the reservoir; calculating the bulk modulus Km and the shear modulus mum of a rock matrix through a Voigt-Reuss-Hill average model; calculating rhom; generating kfl and rhofl; generating the equivalent density rhodry of a rock dry skeleton; sequentially adding the porosities into the rock matrix through a DEM model, and calculating Kdry and mudry; carrying out fluid replacement on the rock dry skeleton through a low-frequency Gassmann equation so as to generate the density rho of a saturated fluid rock; calculating Ksat and musat; calculating the longitudinal wave speed (as shown in the description) and the transversal wave speed (as shown in the description) of the saturated fluid rock, inverting a virtual fracture porosity phi'f by a simulated annealing method according to a first relative error (as shown in the description) or a second relative error of rho and rhoo; replacing phif with phi'f, returning and calculating to generate the transversal wave speed V1 of the carbonatite rock reservoir.

The invention belongs to the field of exploration geophysics, and particularly relates to a carbonatite oil and gas reservoir crack earthquake detection method. The method comprises the steps of: carrying out amplitude versus offset and azimuth angle analysis, speed versus offset and azimuth angle analysis, frequency versus offset and azimuth angle analysis respectively based on pre-stack seismic azimuth angle dataset, further carrying out ellipse fitting respectively to obtain a crack development azimuth angle, and predicting a crack development azimuth through a seismic attribute comprehensive analysis way; carrying out quality factor parameter extraction, anisotropic parameter inversion and non-hyperbolic moveout velocity analysis respectively based on pre-stack seismic trace dataset and shear wave velocity data, and predicting a reservoir crack development region by comprehensively utilizing the parameters above through a seismic attribute comprehensive analysis way. The carbonatite oil and gas reservoir crack earthquake detection method can give more comprehensive consideration to the geology of the reservoir and the physic characteristics of the globe, and the estimated crack azimuth and the predicted crack development region are more exact.

The invention provides a numerical simulation method of a fractured-vug carbonate reservoir and belongs to the field of oil-gas field development. The method includes: 1, judging whether a representative region of the fractured-vug reservoir has fractures and caves; if not, performing single-pore medium numerical simulation to obtain a mathematical model, and going to the step 6; if yes, going to the step 2; 2, setting dimensional limits l<v1>, l<v2>, l<f1> and l<f2> of intra-medium fractures and caves of the fractured-vug reservoir; 3, according to the determined dimensional limits, dividing a medium region of the fractured-vug reservoir into small-size fractures, medium-size fractures, large-size fractures, small-size caves, medium-size caves and large-size caves according to the fractured-vug sizes l<v> and l<f>; 4, according to medium modelling rules of the fractured-vug reservoir and experimental results of representative elementary volumes, judging whether the representative elementary volumes REV<f> and REV<v> exit; if yes, going to the step 5, and if not, returning to the step 2.

The invention provides a calibration method for oil recovery ratio of a karst-fissure-cavity carbonatite reservoir. The method takes production wells with the ending of oil recovery in the oil reservoir as calculation units, calculating the primary recovery rate of each calculation unit, judging the type of a reservoir body of a reservoir stratum of each calculation unit, calculating fitting recovery rates of different types of calculation units according to a karst-fissure-cavity recovery ratio empirical formula and a fissure type recovery empirical formula, and finally evaluating calculation results through error analysis and scatter diagram analysis. The influence of reservoir property, flow property, oil reservoir property and oil reservoir energy on the recovery ration is fully considered; the main controlling factor items in the formulas are sufficient in theoretical basis and complete in data; all factors with influence on the recovery rate are objectively reflected. The calculation ideas and methods serve as supplement and completion of the conventional method for calculating the oil reservoir recovery ratio of carbonatite; the method has a practical value in calibration and calculation of the recovery rate in the last stage of exploration and the initial stage of the development of the oil reservoir of the carbonatite.

The invention discloses a method for judging carbonatite hole crack growth characteristics. The method comprises the following steps: a) processing three-dimensional seismic data and performing breakage explanation and position tracking; b) utilizing seismic data to forecast effective reservoir thickness and effective reservoir porosity; c) analyzing reservoir lithology, reservoir space type, filled degree of hole crack reservoir and change rule of the filled degree of hole crack reservoir along longitudinal direction and horizontal direction; d) while confirming boundary, researching connectivity of reservoir along the longitudinal direction and horizontal direction, inter-well connectivity and oil-gas-water boundary; e) establishing regional oil and gas reservoir profile and unit oil and gas reservoir profile according to fault line, tectonic line, fluid line, pinch-out line and phase-change line, depicting, dividing a developing unit and drawing a developing unit and oil bearing area graph. According to the method provided by the invention, the drilling rate of the reservoir is increased, the leading comprehensive success rate of exploration and development drilling in China is achieved and single-well high yield and stable yield are achieved.

A method and composition for stimulating petroleum production from carbonate reservoirs by employing chelating agents, such as EDTA, which are in particulate form rather than aqueous solutions of chelating agents. The use of particulate chelants, which are relatively unstable in acidic solutions, results in a stimulation fluid with a very high dissolution capability.

The invention provides a proppant-carrying acid fracturing method for a high-temperature ultra-deep carbonate reservoir. The proppant-carrying acid fracturing method for the high-temperature ultra-deep carbonate reservoir comprises the following steps that (1) fracture forming is conducted through fracturing fluid; (2) ground crosslinked acid is adopted and is made to react with rock, so that an acid-etched fracture is generated in a formed fracture, and a proppant is carried with the ground crosslinked acid for supporting the acid-etched fracture; and (3) linear glue is used for replacement, and thus acid fracturing is completed. According to the proppant-carrying acid fracturing method for the high-temperature ultra-deep carbonate reservoir, the technique is simple, operation is convenient, and the construction effect is remarkable; and the proppant-carrying acid fracturing method is suitable for transforming construction of deep well carbonatite at the high temperature of 150-170 DEG C, a supporting fracture which has deep penetration and longer flow conductivity can be formed in a stratum, the productivity is increased and the production time is prolonged after acid fracturing and well fracturing, and the length of the formed fracture is larger than 120 m.

The invention discloses a carbonatite gas and water relative permeability determination method and device. The method includes determining the distribution of pores of carbonatite; determining the gas phase and water phase flow velocities of the pores; determining the gas phase and water phase flow of the pores; according to the gas phase and water phase flow velocities and the gas phase and water phase flow of the pores, determining the carbonatite gas and water relative permeability. According to the method, manual intervention is omitted, water or mercury injection is omitted, and the defects of long time and large errors can be solved during carbonatite gas and water relative permeability determination.

The invention provides a water controlling and acid fracturing method suitable for a carbonate reservoir. The method includes the steps that sliminess water prepad fluid is injected into stratum at the displacement of 1.0 m<3> / min-3.0 m<3> / min; the displacement is increased to 3.5 m<3> / min-4.5 m<3> / min, and gelled fracturing fluid is injected to the stratum; the gelled sand-carrying fluid is injected into the stratum at the displacement of 3.5 m<3> / min-4.5 m<3> / min, and meanwhile precoated sand with the mesh being 70 to 140 is injected into the stratum according to the sand ratio of 4%-6%; the gelled fracturing fluid or the sliminess water prepad fluid is injected into the stratum at the displacement of 3.5 m<3> / min-4.5 m<3> / min; gelled acid is injected into the stratum at the displacement of 3.5 m<3> / min-4.5 m<3> / min, when the injection volume is the sum of the volume of an oil pipe and the volume of a shaft on the lower portion of the oil pipe, the displacement is increased to 5.0 m<3> / min-6.0 m<3> / min, and gelled acid is injected continuously; replacement liquid is injected into the stratum at the displacement of 4.0 m<3> / min-5.0 m<3> / min. By means of the water controlling and acid fracturing method, extension of the downward fracture is controlled effectively, the water cut rising speed is lowered, and water control and oil production enhancing of the carbonate reservoir are achieved.

The invention relates to a method for establishing a logging prediction mathematic model about TOC (Total Organic Carbon). The method comprises the following steps: (1) obtaining organic carbon data and logging curve data; (2) making a single well comprehensive columnar diagram; (3) carrying out signal well depth location on organic carbon data, and regulating the depth position of an organic carbon sampling point; (4) computing correlated coefficients of each logging curve and the TOC; (5) going to the next step if the TOC and GR have highest correlated coefficients and best correlation, otherwise, failing to establish the logging prediction mathematic model about the TOC; (6) making scatter diagrams of the TOC and the GR, respectively establishing a linear relational expression, a quadratic function expression and an index relational expression of the TOC and the GR; (7) selecting the relational expression with the best correlation between the TOC and the GR, wherein the relational expression is a mathematic model for predicting the TOC of multiple wells in a destination zone in the next stage. According to the method for establishing the logging prediction mathematic model about the TOC, disclosed by the invention, the prediction problem of the TOC in a low-organic matter abundance carbonatite hydrocarbon source rock is simply and effectively solved.

The invention provides a water plugging agent for carbonatite and a preparation method and a using method thereof. The water plugging agent consists of the following raw materials in part by weight: 5 to 14 parts of cement, 4 to 8 parts of quartz, 0.1 to 0.5 part of cement flocculating agent, 4 to 11 parts of density lightening admixture, 1 to 2 parts of grid structure agent and 72 to 74 parts of water. The water plugging agent has high bonding strength and low density, and is suitable for high-temperature and high-mineralization carbonatite oil wells so as to solve the problem that the water plugging agent in the prior art is not suitable for the high-temperature and high-mineralization environment, has poor bonding strength and high density, and cannot effectively control water or improve the oil recovery ratio.

The invention discloses an evaluation method of the carbonatite reservoir volume acid fracturing flow guiding capacity and belongs to the technical field of exploration and development of oil and gas.An artificial joint forming device is adopted to conduct joint cutting and transverse slipping on a carbonatite rock board, and an upper rock board body and a lower rock board body with cracks are obtained; a first flow guiding capacity test is conducted, and the value of the first flow guiding capacity is obtained; acid liquid is injected between the upper rock board body and the lower rock board body, a second flow guiding capacity test is conducted, and the value of the second flow guiding capacity is obtained; the values of the first flow guiding capacity and the second flow guiding capacity are compared, and thus the increased degree of the flow guiding capacity after acid injection can be known; the crack forming mode of the test rock board accords with the actual stratum situationbetter, and thus the evaluation method of the carbonatite reservoir volume acid fracturing flow guiding capacity can provide scientific guidance for actual carbonatite reservoir volume acid fracturingconstruction parameter optimization, acid liquid system preferable selection and process optimization; and meanwhile the evaluation method is easy to operate, high in guidance and wide in applicationrange.

An embodiment of the invention provides a device and a method for determining multiscale porous characteristics of carbonatite. The method includes: acquiring a first scanning image by subjecting a carbonatite sample with the diameter larger than a full diameter to millimeter CT (computed tomography) scanning; taking a portion with micron-diameter voids or pores densely distributed from the carbonatite sample as a first plunger sample, and subjecting the first plunger sample to millimeter CT scanning to obtain a second scanning image; taking a portion with nano-diameter voids or pores densely distributed from the first plunger sample as a second plunger sample, and subjecting the second plunger sample to millimeter CT scanning to obtain a third scanning image; determining porosity of the carbonatite sample and distribution modes of the voids and pores in different diameters on the carbonatite sample according to the first scanning image, the second scanning image and the third scanning image after binaryzation. By adoption of the scheme, quantitative, precision and reliable analysis on the multiscale porous characteristics of the carbonatite can be realized.

The invention discloses a water-injection oil-replacement mining method applicable to fracture-cavity type carbonatite condensate gas reservoirs, wherein three-dimensional geologic models of condensate gas reservoirs with different reservoir types and different gas condensate contents are established through a modeling technology in combination with materials related to earthquake, logging, drilling and mud logging and dynamic production; a dual-media water-injection oil-replacement mechanism is then researched by a numerical simulation technology in combination with pilot production characteristics; an injection well, a water injection moment, a water injection amount, a water injection speed, quantity of water injection rounds and water injection intensity are optimized in order to realize multiple rounds of mining after a well soaking period is reached; and the water injection moment, the water injection amount, the water injection speed and the water injection intensity need to be optimized before each round of the mining. By the method, a life cycle of the fracture-cavity type carbonatite condensate gas reservoir can be prolonged, and rate of oil and gas recovery can be effectively increased.

The present invention provides a method of producing a pelletized composition containing leonardite, sedimentary rock and gypsum. The method calls for pre-mixing the humic substance and the sedimentary rock for at least two weeks to yield a developed mixture prior to addition of other materials such as gypsum and pelletizing and drying the pellets to produce the final product. The invention also includes several pelleted compositions containing leonardite, rock phosphate and gypsum. In one aspect of the invention the rock phosphate comprises a mixture of sedimentary rock phosphate and igneous rock phosphate. In another aspect of the invention, the igneous rock phosphate comprises carbonatite and the sedimentary rock phosphate comprises phosphorite.

The embodiment of the invention provides a nonequivalent modeling method and a device for a heterogeneous reservoir stratum. The nonequivalent modeling method comprises the following steps: selecting a field outcrop of the heterogeneous reservoir stratum and analyzing the field outcrop to obtain an internal structure of the heterogeneous reservoir stratum; collecting imaging logging data, carrying out statistic analysis on the imaging logging data, dividing the heterogeneous reservoir stratum into a cave type, a fracture type and a fracture-cave type; and collecting conventional logging data and determining elastic parameters of a fracture-cave body in different positions according to the logging data so as to form a nonequivalent model of the heterogeneous reservoir stratum. According to the nonequivalent modeling method and the device disclosed by the invention, by analyzing the imaging logging data, the trend and distribution characteristics of fracture and caves of a carbonatite heterogeneous reservoir stratum are researched in microcosm and the guarantee can be provided for finely engraving the fracture-cave body; and according to the statistical analysis of the logging data, all elastic parameters of the fracture-cave reservoir stratum are accurately positioned.

The invention discloses a carbonatite fracture-cave type reservoir displacement physical model combination method and an experiment device. 15 kinds of typical fracture-cave structures are extracted; 14 fracture-cave combination modularized units are finally obtained; and 25 kinds of fracture-cave combination modes are summarized by analyzing different main control factors and combining the practical fracture-cave units. A fracture-cave type reservoir displacement experiment physical model system combination module experiment device for performing the experiment on the carbonatite fracture-cave type reservoir displacement physical model combination method comprises a raw material storage system, a fracture-cave combination device, a pressure supply device, a power supply, a metering system, a data processing system and relevant accessories such as a pipeline and a valve. A serious of novel fracture-cave combination modes for the experiment are provided; devices required by the experiment method are subjected to integral experiment device and technical flow process design; and a whole set of fracture-cave type reservoir displacement experiment physical model system combination module experiment device is finally formed.

The invention discloses a mineral content-based brittleness evaluation method for a shale gas reservoir. By taking the brittleness of quartz as the standard, the relative brittleness degree, called as a mineral brittleness coefficient, of each essential mineral in the shale gas reservoir is determined; the essential minerals comprise the quartz, clay-contained quartz, kaolinite, Mexico clay, mixed clay, calcite, dolomite, rock salt, kerogen, perthite, anorthose, feldspar, anhydrite, zeolite and natrolite; the overall brittleness degree of reservoir rock is computed by utilizing mineral volume content and the brittleness coefficient of each mineral; the mineral volume content refers to the percentage that the volume of minerals in porous rock accounts for the total volume of the porous rock. The brittleness evaluation method is superior to a method, used in oil exploration industry at present, for evaluating brittleness by comparing the volume content of the quartz and carbonatite and the total volume of the minerals.

The invention discloses a method for treating mine acidic wastewater by means of mixed packing of organic matter and carbonatite. A closed reaction area is divided into a plurality of levels of processing units; the organic matter and the carbonatite are fed into each processing unit; the mixing ratios of the organic matter to the carbonatite of all the processing units are different; the organic matter at the front end accounts for larger proportion; the proportions of the organic matter along the direction of a reaction tank are gradually reduced; the mixture only contains the carbonatite in the last level; all the levels of processing units are arranged level by level in a stair manner, the front processing units are high, and the rear processing units are low; and water inlets and water outlets of all the units meet the requirements of upper inlet and lower outlet or lower inlet and upper outlet and stable water flow. The method has the advantages of good effect, low investment and low wastewater treatment cost.

The invention discloses a carbonatite fracture-cavity unit body injection-production simulation experiment evaluation device.The device comprises a gas-liquid injection system, a bottom water simulation system, a fracture-cavity unit simulation system, an oil-gas-water separating and metering system and a data collection control and processing system; the gas-liquid injection system comprises a fluid storage mechanism and a fluid displacement control mechanism used for simulating displacement experiments and injecting a fluid into the fracture-cavity unit simulation system; the bottom water simulation system is used for simulating influences of bottom water with different strengths on injection and production of a fracture-cavity unit; the fracture-cavity unit simulation system comprises a fracture-cavity unit body model body and preset simulation pressure measuring points; the oil-gas-water separating and metering system comprises a gas-liquid separator, an oil-water separator and an oil-gas-water measuring meter; the data collection control and processing system comprises sensors, a simulation light source and an industrial personal computer.The carbonatite fracture-cavity unit body injection-production simulation experiment evaluation device can simulate oil well production situations of different fracture-cavity storage and collection unit spaces and simulate the influences of different bottom water on oil well production.

The invention discloses a carbonatite microflow simulating method and device. The method comprises the steps of reading a CT scanning photo of carbonatite; performing binaryzation treatment for the CT scanning photo of carbonatite; reading a binaryzation image of the porous medium in carbonatite from the CT scanning photo of carbonatite after binaryzation treatment; building a physical model of carbonatite according to the binaryzation image of the porous medium; performing physical field initializing, inner node collision migration and boundary point treatment for the physical model of carbonatite; performing carbonatite microflow simulating according to the treated physical model of carbonatite. The method can quickly and accurately to perform carbonatite microflow simulating.

The stability of subterranean, laminated, carbonate-containing formations that have strongly hydrophilic-wet surfaces is improved by introducing into the formation an aqueous fluid having dispersed therein relative permeability modifiers (RPMs). The RPMs are designed to enter the fractures and gaps between the layers in the formation and alter their surface wettability to inhibit water from further entering into the shale rock, thereby improving stability.

The invention discloses an imaging method of wide angle reflection waves of deep carbonate reservoirs in a large desert region. The method comprises steps of acquiring original single shot record information, and defining a seismic data processing observation system according to the record information, wherein the record information comprises seismic data including the wide angle reflection waves; picking up the primary arrival of seismic waves and carrying out chromatography static correction on the wide angle reflection waves; compensating the amplitude of the seismic data; carrying out noise compression on the wide angle reflection waves; carrying out resolution increasing processing on the wide angle reflection waves; carrying out high-order dynamic correction on the wide angle reflection waves and carrying out speed analysis; cutting the seismic data and keeping the wide angle reflection waves; carrying out speed modeling on the wide angle reflection waves; and optimally selecting imaging parameters of the wide angle reflection waves so as to obtain migration imaging result data of the wide angle reflection waves. According to the invention, according to the seismic data spreading mechanism, based on the wave field analysis, the wide angle reflection waves in the single shot records can be effectively recognized; and by use of the wide angle reflection wave imaging, the quality of the deep seismic data imaging is improved.

The invention discloses a method and device for predicting relative impedance based on dipole seismic wavelet multiple integrals. The method includes the first step of carrying out well logging and seismic joint calibration according to well logging and seismic data so as to extract wavelets and determine time depth relations, and extracting parameter characteristics of the top and bottom of a reservoir, the second step of building reservoir response characteristic wave functions of the dipole seismic wavelets according to the wavelets, the time depth relations and the parameter characteristics of the top and bottom of the reservoir, the third step of carrying out multiple integral operation on seismic sections according to the reservoir seismic response characteristic wave functions to extract and form a seismic response model database, and determining the best calculating integral multiple number and sliding window parameters, and the fourth step of carrying out the relative impedance operation on an actual seismic data volume according to the best calculating integral multiple number and the sliding window parameters to generate a relative impedance data volume. The method and device have the advantages that the integral characteristics of the seismic data are directly utilized to extract reservoir thickness characteristic parameters, the accuracy of reservoir seismic prediction is improved, and the effect for predicting the relative impedance of the reservoirs such as a carbonatite karst cave and sand shale is ideal.

The invention provides a recognition method of lithology of sand-shale-carbonatite. The method is characterized by comprising the following steps: S1) detecting the content of Si, Al, Ca and Mg elements in a to-be-detected rock debris sample; and S2) calculating the total content XSS of SiO2 and Al2O3 and the total content XLD of CaO and Mgo in the to-be-detected rock debris sample; and judging the lithology of the to-be-detected rock debris sample according to the XSS and the XLD. Compared with the prior art, the method provided by the invention has the beneficial effects that firstly, the content of the Si, Al, Ca and Mg elements in the rock debris sample is detected, and the data of the content of the XSS and the XLD is calculated, so that quick, automatic and accurate recognition of the sand-shale-carbonatite is realized; the defects existing in the prior art are overcome; the method is convenient to operate; a recognition result of the lithology is accurate; and the method is beneficial to the recognition of oil and gas resource reservoirs, can improve the exploration and development benefits of oil and gas resources, and guides safe and efficient well drilling construction.