11 results about "Cross-plot" patented technology

This invention discloses a method utilizing nuclear magnetic resonance double-T E The method for classifying water flooding levels in well logging is as follows: First, the transverse relaxation rate of nuclear magnetic resonance (NMR), the geometric mean of the mobile fluid portion of the T2 spectrum, and the double T2 spectrum are calculated sequentially using NMR logging data. E The geometric mean difference of the mobile fluid portion of the T2 spectrum was measured. Then, the porosity of different components was obtained by inversion of echo data under long waiting times and short echo intervals. Finally, the percentage content of macroporous components in the total porosity was plotted against the T2 spectrum. E Cross plot of geometric mean difference of the mobile fluid portion of T2 spectrum and plotting of array induced resistivity AT90 and double T E The cross plot of the geometric mean difference of the mobile fluid portion of the T2 spectrum is measured to identify the flooding level of the flooded layer: unflooded layer, low flooded layer, medium flooded layer, and high flooded layer.

The invention belongs to the technical field of oil exploration and development, and discloses a method for identifying volcanic rock weathering crust and interior periods based on multiple seismic attributes, which comprises the following steps: determining a logging chart division boundary; a seismic data volume corresponding to the logging data is read, a cross plot is drawn, and a seismic data volume correction formula is obtained through linear fitting; correcting the seismic data volume of the research area; dividing the corrected data volume through a logging plate division boundary to obtain a first probability volume P1; determining an impedance plate division boundary; performing inversion to obtain an inversion resistance body; dividing the inversion impedance body according to an impedance plate division boundary to obtain a second probability body P2; performing weighted calculation on the P1 and the P2 to obtain a volcanic rock interior period identification parameter body P3; and establishing a recognition plate by using the P3, and determining a division boundary of the recognition plate to obtain a volcanic rock interior period recognition probability body P4. According to the method, well-seismic data unification is realized, and the weathering crust and the inner curtain period can be effectively identified in combination with an impedance inversion data body prediction result.

Provided are a fluid identification method and system, a terminal device, and a machine-readable storage medium, belonging to the field of petroleum exploration. The method comprises: determining a study sample logging curve, a gas logging curve and drilling detection parameters; on the basis of the study sample logging curve, establishing a shallow resistivity and deep resistivity cross plot, and identifying water from among unknown fluids; using the gas logging curve to establish a derived parameter cross plot; using the study sample logging curve and the drilling detection parameters to establish a semi-quantitative evaluation chart of CO2 content based on density porosity and neutron porosity, and a semi-quantitative evaluation chart of CO2 content based on density porosity and porosity difference; on the basis of the derived parameter cross plot, the semi-quantitative evaluation chart of CO2 content based on density porosity and neutron porosity, and the semi-quantitative evaluation chart of CO2 content based on density porosity and porosity difference, identifying CO2, condensate gas and oil in the unknown fluids. By means of the provided method, unknown fluids can be accurately identified, and logging interpretation evaluation accuracy is improved.

The invention belongs to the technical field of formation pore pressure acquisition, and discloses a pore pressure acquisition method and system based on a depth trend line and formation factors, and the method comprises the steps: collecting well leakage, gas cut and overflow in a drilling process, and re-pressing and static pressure data in an oil testing process, and fitting a regression pressure trend line; drawing an engineering pore pressure geological factor interpretation read map, reading interval transit time and density logging values, and calculating formation factors; forming a pressure factor linearly related to the formation pore pressure by combining the regression pressure trend line and the formation factor; and drawing a formation pore pressure-pressure factor cross plot, carrying out linear regression fitting, and calculating the equivalent density of the formation pore pressure. According to the method, various pressure data (such as well leakage, gas cut, overflow and re-pressure and static pressure data in the oil testing process) in the drilling process are collected, the data are used for logarithmic regression fitting, and the obtained pressure trend line can more accurately reflect the change trend of the formation pore pressure along with the depth.

The invention relates to the technical field of oil exploration, and discloses an inter-coal oil-bearing reservoir prediction method and device, a medium and computing equipment. The method comprises the steps that single well curve characteristic analysis is carried out, qualitative analysis is carried out on curves of sound waves, resistivity, porosity and natural potential, and the characteristics of the oil-bearing reservoir are determined; carrying out quantitative analysis on the density and the gamma curve, and carrying out curve fitting; the fitted curve is optimized, and the influence of the coal seam is eliminated; establishing a favorable reservoir indication curve and a sound wave time difference cross plot, carrying out quantitative analysis on the oil-bearing reservoir, and dividing the interval of the oil-bearing reservoir to distinguish the oil-bearing reservoir; well-seismic calibration is carried out, and a coal seam oil-bearing reservoir removal initial model is established based on the favorable reservoir indication curve; and based on the coal seam-removed oil-bearing reservoir initial model, carrying out oil-bearing reservoir prediction, and drawing an oil-bearing reservoir planar graph and an oil-bearing reservoir profile graph. According to the method, the influence of the coal seam is eliminated, the applicability to the oil-containing reservoir between the coal is improved, and the distribution condition of the oil-containing reservoir is conveniently and accurately predicted.

This invention relates to the technical field of reservoir oil-bearing evaluation methods, and discloses a qualitative evaluation method and system for the oil-bearing properties of heterogeneous reservoirs. The qualitative evaluation method for the oil-bearing properties of heterogeneous reservoirs introduces the natural gamma coefficient of variation V. GR This method characterizes the heterogeneity of reservoirs caused by mudstone interlayers. By combining arrayed induced resistivity (RT) and natural gamma (GR) to establish cross plots, the impact of reservoir heterogeneity on oil-bearing evaluation is reduced to some extent, thereby improving the reliability of oil-bearing evaluation for heterogeneous reservoirs. In addition, through actual data statistics and cross plot analysis, combined with well types and sand body structure models, this method establishes an oil-bearing evaluation standard table, making the method highly operable and practical in actual applications. This improves the reliability of oil-bearing evaluation for heterogeneous reservoirs and provides methodological support for reservoir development and reserve upgrading.

The invention relates to the technical field of geophysical well logging interpretation, in particular to a compact sandstone reservoir complex fluid self-adaptive identification method and device, and the method comprises the steps: analyzing the relation between different fluid types and lithology, physical property, pore structure and brittle reservoir characteristic parameters in a histogram and cross plot mode, and qualitatively determining the main control elements of the fluid type difference; constructing required quantization parameters according to the main control elements; performing normalization processing on the logging curve and the quantization parameters; selecting sensitive parameters from the existing logging curve and the constructed quantization parameters by using a spider diagram; fusing the multiple parameters by using a principal component analysis method, and constructing fluid type master control elements; establishing a label database according to the constructed index and the corresponding fluid type; and training and self-adaptive explanation of a complex fluid identification model are carried out. According to the method, the recognition precision of the complex fluid of the compact sandstone reservoir is improved, and a geological foundation is laid for subsequent dessert evaluation and target optimization.

The invention belongs to the technical field of rock mass detection, and provides a basement granite distribution range prediction method, system and device and a medium, and the method comprises the steps: obtaining the logging data of a basement layer section of a research area; establishing a lithology identification graph according to the obtained logging data of the substrate layer section of the research area; the lithology identification graph is an MN cross plot, and M is the slope of a straight line on the sound wave and density cross plot; n is the slope of a straight line on the neutron and density cross plot; determining M value and N value ranges of granite; in the MN cross plot, the area belonging to the range of the M value and the N value of the granite is the granite distribution area.

The invention relates to the technical field of oil-gas exploration and development, and particularly discloses a seismic-electric fusion reservoir fluid identification method, which comprises the following steps of: firstly, obtaining a three-dimensional seismic horizon, further obtaining a geological framework of a work area according to the three-dimensional seismic horizon, and inverting electromagnetic data to obtain an inversion resistivity profile; and the inversion resistivity of the target stratum of the work area is obtained by combining the geological framework and the inversion resistivity profile. And based on the resistivity fluid type cross plot, the fluid type of the target layer can be identified by the inversion resistivity of the target layer. Compared with a traditional fluid identification technology, the reservoir fluid identification method integrates the spatial distribution depiction advantage of well-to-seismic combination and the advantage that an electrical method is sensitive to fluid, is not limited to identification of the fluid at the drilling position, can accurately identify the fluid of each reservoir in a work area, and is high in fluid identification accuracy, large in identification range and easy to operate.

The invention discloses a coal measure strata tight sandstone reservoir identification method and system. The method comprises the following steps: seismic data zero phasing processing; tracking an amplitude zero value reflecting surface corresponding to the coal seam, and extracting wave crest and wave trough amplitude attribute surfaces; calculating an amplitude difference attribute surface; fitting a function relationship by using a scatter cross plot of the amplitude difference attribute value at the well point and the reservoir thickness; threshold value processing is carried out on the amplitude difference attribute surface; the amplitude difference attribute is expanded to the range of the reservoir thickness; constructing equivalent top and bottom reflecting surfaces of the reservoir; filling the amplitude difference attribute value between the equivalent top surface and the equivalent bottom surface of the reservoir to obtain an amplitude difference attribute body; and carrying out tight sandstone reservoir identification by using the amplitude difference attribute surface and the amplitude difference attribute body. According to the method, by calculating the amplitude difference attribute surface and constructing the amplitude difference attribute body, the shielding influence of the seismic strong reflection of the top and bottom surfaces of the coal seam on the sandstone reservoir is counteracted, and the problem that the tight sandstone reservoir of the coal measure strata cannot be accurately identified in the prior art is solved.

The invention discloses a method and system for identifying a basalt construction environment, and the method comprises the steps: calculating a shape coefficient in an REE element composition curve according to the REE abundance of a basalt sample in a to-be-evaluated target region; projecting a first data point formed by a slope coefficient and a curvature coefficient in the shape coefficient into a slope and curvature cross plot, and projecting a second data point formed by an REE logarithmic mean coefficient in the shape coefficient and the magnesium oxide content into a logarithmic mean coefficient and magnesium oxide content cross plot, respectively obtaining projection positions of the two data points; and according to the current projection position, judging the basalt type of the current to-be-evaluated target area. According to the invention, quantitative characterization of construction environment type identification is realized.