41results about How to "Reduce exploration and development costs" patented technology

The invention discloses an identification method and system for a complex basin edge super-stripped belt subtle trap boundary. The identification method includes the following steps that firstly, structural features of a plane of unconformity are analyzed and defined with data of earthquakes, well drilling, well measuring, well logging and the like as the basis; secondly, a geologic model is designed, forward modeling of earthquake responses is conducted, instantaneous phase earthquake attributes are extracted along the stratum, and a stratum super-stripped line for earthquake identification is depicted; thirdly, a geologic model capable of reflecting the super-stripped concept of the stratum is selected, earthquake forward modeling is conducted, and main factors affecting an error distance are defined; fourthly, an error distance formula under the stratum super-stripped condition is established; fifthly, the stratum subtle strap boundary is described according to the stratum super-stripped line and the error distance for the earthquake attribute identification. According to the identification method and system for the complex basin edge super-stripped belt subtle trap boundary, the position of the super-stripped line for earthquake identification can be accurately described, the subtle trap boundary is quantitatively identified based on an extrapolation formula built through multi-model forward modeling, an oil-gas accumulation boundary can be easily and accurately determined, and the oil exploration risk can be effectively lowered.

The invention belongs to the technical field of natural gas exploration and development, and particularly provides a geological stratum selection method based on natural gas multi-stratum series partial pressure combined solution. The method includes the following steps that firstly, single-stratum productivity factors are analyzed; secondly, multi-stratum series combined test inter-stratum interference is analyzed; thirdly, according to the analysis of the single-stratum productivity factors and the analysis of the multi-stratum series combined test inter-stratum interference, multi-stratum series gas test stratums are selected. The method is used for achieving geological stratum selection based on multi-stratum series partial pressure combined solution of a tight sandstone gas reservoir, is reasonable and guarantees accurate stratum selection based on multi-stratum series partial pressure combined solution of the tight sandstone gas reservoir. The method can increase the single-well yield, improve the exploration and development efficiency and lower the exploration and development cost and has great practical guiding significance.

The invention relates to the field of petroleum exploration and development, in particular to a lithologic boundary identification method based on well-seismic combination. The method comprises the steps of obtaining seismic data and well logging data of a research area, manufacturing a synthetic seismic record according to an acoustic wave curve and a density curve, calibrating the synthetic seismic record, carrying out seismic response characteristic analysis on a main reservoir, and identifying lithologic boundaries by comprehensively utilizing a stratigraphic body slicing technology, a seismic attribute analysis technology and sand body spread characteristic research, firstly, carrying out the research of seismic attribute depiction in a research area through analysis, carrying out seismic attribute extraction in a sandstone plane spread range of the main reservoir, overcoming the defect that reservoir prediction cannot be carried out through post-stack wave impedance inversion dueto sand shale velocity stacking, improving the lithologic boundary prediction precision, and reducing the exploration and development cost.

The invention provides a post-stack seismic fluid identification method based on time-frequency analysis. The method comprises the steps that post-stack seismic data processing is performed by using the wavelet decomposition and energy reconstruction method so as to eliminate the influence of complex lithology on the seismic frequency; the seismic data are transformed to the frequency domain fromthe time domain by using the matching tracking frequency division technology, and the corresponding frequency component of the reservoirs including different fluid is determined through combination ofthe logging result and the production dynamic data; the reservoir fluid frequency limit is established by using single well spectral energy normalization processing and the multichannel seismic spectrum statistical technology; and the post-stack seismic frequency attributes are extracted, and the favorable oil and gas zones are predicted according to the determined oil and gas frequency threshold. The oil and gas can be accurately detected and the oil and gas distribution range can be predicted so that the success rate of drilling can be enhanced and the method has wide application prospect.

The invention belongs to a method for recognizing oil and gas reservoirs in oil exploration and development and particularly relates to a method for fast recognizing a low-resistivity zone through optimizing drilling mud to determine oil content. The method includes optimizing drilling mud parameters according to drilling coring materials in a zone to be detected and earth's surface physical materials, establishing evaluation to form a drilling mud resistivity model of the low-resistivity zone; and detecting the drilling mud resistivity value of the zone to be detected and recognizing the process of the low-resistivity oil and gas reservoirs through combining the model, wherein Rmf>KRw in the drilling mud resistivity model. By means of the method, the recognition rate of the low-resistivity oil and gas reservoirs can be improved, therefore the exploitation rate of the low-resistivity oil and gas reservoirs can be improved, and exploratory and development costs can be reduced.

The invention discloses rapid drilling agent which according to mass portion comprises 80-120 parts of vegetable protein, 160-240 parts of water, 24-36 parts of phosphoric acid with concentration of 30-50%, 40-60 parts of divinyl polyamine, 16-24 parts of sulfonating agent and pH modifying agent. The producing technique is that 1, 80-120 parts of vegetable protein are weighed and added into 160-240 parts of water. After resting under normal temperature for 100-1140 minutes, the mixture is stirred uniformly under a constant temperature from 45 DEG C to 55 DEG C. 2, the mixture is heated to 50-70 DEG C, and the pH of the solution is modified between seven and nine. 3, 24-36 parts of phosphoric acid with concentration of 30-50% are weighed and added into the solution which is then stirred to react for 80-100 minutes under constant temperature. 4, the temperature is lowered to 30-40 DEG C, 16-24 parts of sulfonating agent are weighed and added into the solution which is then stirred to react for 60-80 minutes under constant temperature. 5, the pH of the solution is modified between seven and nine. 6, 40-60 parts of divinyl polyamine are weighed and produce rapid drilling agent with the solution via polycondensation in 50-70 DEG C. The drilling agent can raise drilling speed to deep wells and ultra deep wells, thereby reducing exploratory development cost, decreasing development risk, protecting hydrocarbon reservoirs, and increasing recovery percent.

The invention belongs to the field of oil-gas exploration and exploitation and provides a continental facies fracture-cavity type reservoir stratum identification method. The method comprises the following steps: rock core information and logging information of a cored well of a drilled fracture-cavity type reservoir stratum in an object zone are collected, and a development position of the fracture-cavity type reservoir stratum of the cored well can be determined according to the rock core information; according to how a logging curve of the cored well is sensitive to fracture-cavity type reservoir stratum characterization, logging curve data is selected; a logging identification standard for the fracture-cavity type reservoir stratum in the object zone is established; the established logging identification standard for the fracture-cavity type reservoir stratum in the object zone is used for identifying the fracture-cavity type reservoir stratum in the object zone. The continental facies fracture-cavity type reservoir stratum identification method can be used for effectively identifying the fracture-cavity type reservoir stratum via conventional logging data; costs of well drilling, coring and imaging logging can be reduced in subsequent exploration and exploitation processes; exploration and exploitation costs can be lowered; improvement of oil-gas exploration and exploitation proceeds can be guaranteed.

The invention belongs to the technical field of petroleum exploration and development, in particular to an oil and gas reservoir recognition method applied to qualitatively analyzing existence of oil reservoirs through detection data, and provides a method of judging a low-resistivity annulus formed in a formation. The method includes: acquiring core data and determining irreducible water saturation Swb and residual oil saturation Sor of a core; acquiring a ratio of drilling fluid resistivity Rmf and formation water resistivity Rw according to the irreducible water saturation Swb and residual oil saturation Sor of the core; detecting a target formation to acquire the formation water resistivity Rw and the drilling fluid resistivity Rmf; if an actual physical value is larger than a calculated value, determining the low-resistivity annulus is formed. Through the application of the method in low-resistivity oil and gas fields, efficiency of exploiting low-resistivity oil and gas reservoirs can be improved effectively, the low-resistivity oil and gas reservoirs are recognized visually and quickly, exploration cost is reduced, and economic benefit is increased. As China possesses many low-resistivity oil and gas reservoirs, the method has promising application prospect.

The invention discloses a simulating calculation method for porosity of a clastic rock reservoir on the basis of a diagenetic facies logging identification technology. According to the method, diagenetic facies in a research area is researched in a detailed manner with the diagenetic facies logging identification technology, so that a PDFP (present diagenetic facies profile) of the research area is established, and finally, porosity of an interval of clastic rock is subjected to simulating calculation through combination with burial history, thermal history, fluid history and pressure historyof the research area.

The invention discloses a method and a system used for predicting initial productivity after shale formation fracturing. The method includes: a productivity model establishment step, wherein a model of the initial productivity after shale formation fracturing is established according to geological sweet-spot parameters and engineering sweet-spot parameters; and an initial-productivity determination step, wherein the initial productivity after shale formation fracturing is determined according to the model of the initial productivity. According to the method, quickly predicting the initial production productivity of a shale gas well after fracturing is completed is facilitated, influence parameters of the initial productivity after shale formation fracturing are simplified, exploration and development costs of a shale gas formation are reduced, and development efficiency of the shale formation is improved.

The invention discloses an earthquake identification method and device for the connectivity of a fault-dissolved body reservoir, and the method comprises the steps: building an earthquake maximum likelihood body based on a three-dimensional earthquake data volume; performing space engraving on the earthquake maximum likelihood body through the threshold value of the attribute of the earthquake maximum likelihood body to obtain the space contour of the fault-dissolved body; selecting a first point and a second point at the same altitude in the space of the fault-dissolved body, and obtaining the formation pressure at the first point and the formation pressure at the second point; comparing the formation pressure at the first point with the formation pressure at the second point, and judgingwhether the reservoir between the first point and the second point is connected or not according to a comparison result. According to the method, the earthquake maximum likelihood body is constructedby utilizing the three-dimensional earthquake data body, the formation pressures of the two points at the same altitude are calculated, reservoir connectivity identification is carried out based on the principle that the formation pressures at the same depth in the same fracture-cavity unit are equal, and the effective identification problem of reservoir connectivity in a well-free area or an area outside a well is solved.

The invention discloses a quantitative forecasting method for a clastic rock reservoir corrosion hole increasing amount. The method establishes a "geological parameter-dissolution function-porosity" prediction model under different dissolution functions is established on the basis of the research of clastic rock reservoir sedimentary facies, rock facies, fluid properties, sedimentary cycle, a diagenetic stage and a fault development situation, and therefore, the clastic rock reservoir, especially, the sizes of low-hole and low-permeability tight reservoir corrosion holes can be predicted and evaluated.

A shale brittleness sweet spot evaluation method is provided, comprising: determining a brittleness evaluation formula of shale brittleness indexes, shale mineral volume percent content and shale total organic matter mass percent content according to a shale volume-mass conversion formula and a brittleness calculation formula containing shale total organic matter volume percent content and the shale mineral volume percent content; drawing a shale brittleness grading chart of a research area target interval according to the brittleness evaluation formula and measured shale mineral volume percent content values and shale total organic matter mass percent content values of multiple shale samples of the research area target interval; and evaluating shale brittleness sweet spots of the research area target interval. By adopting the method, the shale brittleness sweet spots can be accurately and quantitatively recognized, shale exploration and development cost is reduced, and production capacities of gas-bearing shale formation are increased.

The invention provides a method for determining a pressure coefficient and drilling mud density of a carbonate rock fracture-cavity type oil and gas reservoir. The method comprises the steps of obtaining the original formation pressure of a fracture-cavity type reservoir development horizon of a target area; determining the fracture-cave body volume of the fracture-cave type reservoir developmentlayer of the target area; obtaining the mud leakage amount and stratum fluid parameters in the drilling process of the fracture-cavity type reservoir development horizon of the target area; based on the original formation pressure, the fracture-cave body volume, the mud leakage amount and the formation fluid parameters, determining the formation pressure after mud leakage in the drilling process through a material balance equation; and determining the true formation pressure coefficient of the fracture-cavity type reservoir development layer of the target area based on the determined formationpressure after mud leakage.

The invention discloses a method for quantitatively predicting the cementation porosity decrement of a clastic rock reservoir. The method, by identifying the key geological factors of different geological processes and the differences thereof, and the influences of geological factors in different geological processes on the cementation porosity decrement in the reservoir, constructs a porosity response quantitative equation, simulates the reservoir porosity evolution process according to the quantitative response equation, reproduces the influences of cementation in the diagenetic process of the sediment reservoir on the reservoir physical property change law, and can well quantitatively predict the cementation porosity decrement of the clastic rock, so as to provide new ideas and basis for the study of reservoir physical properties in the basin.

The invention discloses a seismic identification method and device for fault-karst reservoir connectivity. The method includes: constructing an earthquake maximum likelihood body based on a three-dimensional seismic data volume; The likelihood body performs space carving to obtain the spatial outline of the fault-karst body; select the first point and the second point at the same altitude in the space of the fault-karst body to obtain the formation pressure at the first point and the formation pressure at the second point ; Comparing the formation pressure at the first point and the formation pressure at the second point, and judging whether the reservoir between the first point and the second point is connected according to the comparison result. The present invention utilizes three-dimensional seismic data volumes to construct seismic maximum likelihood volumes, calculates formation pressures at two points at the same altitude, and identifies reservoir connectivity based on the principle that formation pressures at the same depth in the same fracture-cavity unit are equal, solving the problem of no-well The problem of effective identification of reservoir connectivity in regional or out-of-well regions.

The invention discloses a method for continuously explaining lithology of mixed-accumulation fine-grained rock and a modeling method of a model thereof, which comprises the following steps of: firstly, selecting a continuous coring well section rock core in a research area according to geological conditions and research target requirements, systematically observing and describing rock core data ofthe continuous coring well section, and acquiring a rock core element continuous distribution curve of the continuous coring well section; an analyzing lithological characteristics corresponding to the core data of the continuous coring well section observed and described by the systm, and determining typical lithology of the research area; determining different element content values and differences of typical lithology of the research area, determining elements capable of continuously and quantitatively explaining the typical lithology of the research area, and defining the elements as sensitive elements; and in combination with the core element continuous distribution curve of the continuous coring well section, establishing a mixed fine-grained rock lithology interpretation model based on the content difference of sensitive elements, and carrying out lithology continuous interpretation by utilizing the model. The method solves the problems that an existing mixed fine-grained rocklithology distinguishing method is large in distinguishing difficulty in an oil field drilling site and not high in practicability.

The invention discloses a method and a system used for predicting shear fracture capacity of a formation. The method includes: a critical-condition calculation step, wherein a critical condition of shear fracture occurrence of the formation is calculated according to relationships of formation polymerization strength and formation stress; a polymerization strength calculation step, wherein the polymerization strength of the formation in shear fracture occurrence is calculated according to the critical condition and the relationships of the formation polymerization strength and the formation stress; and a critical-stress model establishment step, wherein a critical-stress model is established according to the polymerization strength and an internal friction coefficient of the formation in shear fracture occurrence. According to the method, fracturing construction parameters can be optimized, exploration and development costs of the shale gas formation can be reduced, and development efficiency of the shale formation can be improved.

The invention discloses a waterproof guide pipe device with a protective pipe and a using method. The waterproof guide pipe device comprises a pipe body, the protective pipe arranged outside the pipe body in a sleeving mode, a female connector installed on the lower portion of the pipe body, a feeding male connector and a tie-back male connector, wherein a wedge block is mounted on the pipe body; a protective tube cap covers the upper end surface of the protective tube; a fishing lug for feeding and tieback is arranged in the protective tube cap in a sleeving mode; an anti-rotation insertion block is inserted between the female connector and the feeding male connector; the female connector and the tie-back male connector are locked together through a locking ring; and a quioning corner used for preventing the anti-rotation insertion block from moving upwards is arranged in the anti-rotation insertion block, and the upper end of the quioning corner is connected with a steel wire rope. According to the device, two modes of permanent well abandoning and development well transferring are considered, and when the well is not converted into a development well, a drilling ship does not need to be mobilized for discarding; when the well is converted into a development well, wellhead tie-back can be conducted on the well, development is smooth, and the treatment scheme of the exploratory well meets the permanent discarding standard; and therefore oil-gas exploration and development cost is greatly reduced, and rolling exploration and development of oil and gas fields are achieved.

The invention discloses a simulating calculation method for porosity of a clastic rock reservoir on the basis of a diagenetic facies logging identification technology. According to the method, diagenetic facies in a research area is researched in a detailed manner with the diagenetic facies logging identification technology, so that a PDFP (present diagenetic facies profile) of the research area is established, and finally, porosity of an interval of clastic rock is subjected to simulating calculation through combination with burial history, thermal history, fluid history and pressure historyof the research area.

According to the method and device for calculating the pore volume compression coefficient of the rock. The basic parameters of the resource reservoir are counted, the basic parameters are used for calculating the pore volume compression coefficient of the rock, the basic parameters of the resource reservoir are easy to obtain, the calculation difficulty of the pore volume compression coefficient of the rock is reduced, and the method can be widely applied. Besides, when the pore volume compressibility coefficient of the rock is calculated, the change of the effective stress is considered, and the pore volume compressibility coefficient of the rock under the zero effective stress is calculated, so that the pore volume compressibility coefficients under different effective stresses are obtained according to different effective stresses and the pore volume compressibility coefficient of the rock under the zero effective stress; the method is suitable for any reservoir stratum, and the application is wider. The rock pore volume compression coefficients of different reservoirs are calculated through a unified method, so that resource exploration such as reservoir elastic energy evaluation, oil and gas reservoir reserve calculation and pressure instability analysis is more accurate and easy to implement, and the exploration and development cost is reduced.

The invention discloses a method for optimizing a horizontal drilling azimuth of a shale formation. The method comprises the following steps: obtaining an azimuth angle of a formation shear fracture type fracture plane; optimizing a drilling azimuth according to the azimuth angle of the shear fracture type fracture plane. The method optimizes the drilling azimuth according to the azimuth of the shear fracture plane, is convenient to form a network fracture in case of formation fracturing, reduces the exploration and development cots of a shale gas formation, and improves the development efficiency of the shale formation.

The invention discloses a method for optimizing a horizontal drilling azimuth of a shale formation. The method comprises the following steps: obtaining an azimuth angle of a formation shear fracture type fracture plane; optimizing a drilling azimuth according to the azimuth angle of the shear fracture type fracture plane. The method optimizes the drilling azimuth according to the azimuth of the shear fracture plane, is convenient to form a network fracture in case of formation fracturing, reduces the exploration and development cots of a shale gas formation, and improves the development efficiency of the shale formation.

The invention belongs to the technical field of natural gas exploration and development, and particularly provides a geological stratum selection method based on natural gas multi-stratum series partial pressure combined solution. The method includes the following steps that firstly, single-stratum productivity factors are analyzed; secondly, multi-stratum series combined test inter-stratum interference is analyzed; thirdly, according to the analysis of the single-stratum productivity factors and the analysis of the multi-stratum series combined test inter-stratum interference, multi-stratum series gas test stratums are selected. The method is used for achieving geological stratum selection based on multi-stratum series partial pressure combined solution of a tight sandstone gas reservoir, is reasonable and guarantees accurate stratum selection based on multi-stratum series partial pressure combined solution of the tight sandstone gas reservoir. The method can increase the single-well yield, improve the exploration and development efficiency and lower the exploration and development cost and has great practical guiding significance.