614 results about "Petroleum exploration" patented technology

The invention belongs to the petroleum exploration field, and concretely relates to a compact sandstone reservoir complex netted fracture prediction method. The method comprises the steps of: building a geological structure model and a fracture growth model; testing magnitudes and directions of ancient and modern crustal stresses; completing a rock mechanic parameter experiment; testing rock mechanic parameters and fracture stress sensitivities; developing a fracture rock multistage composite rupture criterion; performing a rock deformation physical test to obtain a peak value intensity; building a relation model between single axle state stress-strain and fracture bulk density; building a relation model between triaxial state stress-strain and fracture bulk density and occurrence; building a relation model between single axle state stress-strain and fracture bulk density; calculating and stimulating fracture parameters under modern conditions; and verifying the reliability of a fracture quantitative prediction result. The method can accurately obtain compact sandstone reservoir complex netted fracture parameters, and perform quantitative characterization, is suitable for quantitative prediction of any fracture mainly with a brittle reservoir, and reduces exploitation risks and costs.

A method having application for petroleum exploration or geological storage of generating a mesh of a faulted underground medium, comprising generating a hex-dominant mesh from faults and horizons in a form of a 3D triangulated surfaces. Each 3D triangulated surface is converted to a 2D triangulated surface onto which the faults are projected by an isometric unfolding technique. A regular two-dimensional grid pattern is generated for each 2D triangulated surface. The faults are accounted for by deforming quadrilaterals of the grid pattern intersected by projected faults. The deformed regular grid pattern is then converted to a 3D gridded surface and each quadrilateral which is crossed by a fault is converted into two triangles at a level of a diagonal. Finally, after iterating for all the 3D triangulated surfaces, the mesh is generated by creating links between the nodes of neighboring three-dimensional gridded surfaces with respect to the faults.

The invention relates to a triaxial core holder. A pressure cap, a left plug, a core chamber, a left core plug, a positioning washer and a left small pressure cap are arranged at the left part of the core holder, and an axial pressure piston, a right small pressure cap, a right plug and a right core plug are arranged at the right part thereof. The triaxial core holder is characterized in that a gum cover is arranged on the periphery of the ore chamber and connected with two pairs of pistons through connecting plates; and two pressure-bearing cylinders are connected on the outer sides of the pistons. By adopting three groups of pistons (horizontal, vertical and axial), the triaxial core holder can simulate the holder with two pressures at most than before. The invention can better simulate the three-dimensional stressed situation of the core in a stratum, and the three groups of pressures can be freely adjusted, therefore, the stressed situation of the stratum can be truly simulated, so that the experimental data is closer to actual data inside the stratum. The invention can provide a better manner for petroleum exploration.

The invention relates to a process for exploiting ocean gas hydrate by utilizing terrestrial heat, comprising the following steps: 1) digging a branch well on a target hot rock stratum; 2) utilizing a casing to penetrate through gas hydrate treasure, digging a directional well on the target hot rock stratum, perforating the casing penetrating through the gas hydrate treasure, and sealing the mouth of the well; 3) pressing seawater into the target hot rock stratum by utilizing a pump, pressing the seawater into the directional well after heat exchange heating, leading the seawater into the area of the gas hydrate treasure from the perforation of the casing, and obtaining decomposed gas hydrate and cooled seawater; and 4) transporting the gas hydrate and the cooled seawater to a sea surface by utilizing a gas-liquid recycling tube, separating the gas hydrate from the cooled seawater at an outlet, and collecting natural gas. The invention has the beneficial effect that the invention greatly reduces the heat injection cost in the exploration process, causes the exploration process to continuously develop and has less pollution and damage on environment, and each technical index in the exploration process can refer to the existing petroleum exploration process so as to lower difficulty for realizing the exploration process.

The invention relates to the technical field of petroleum exploration, in particular to a time-frequency decomposition earthquake-fluid recognition method which includes establishing a time-frequency atom dictionary D according to Morlet wavelet function m(t)=exp[-betaXf2(t-tau)2]exp[i(2pif(t-tau)+phi)], and acquiring an initial matching atom of the Morlet wavelet function through calculation with a seismic trace and complex seismic trace method; performing matching decomposition on the seismic trace, performing iterative optimization with constraints of the time-frequency atom dictionary D in the neighborhood of the initial matching atom to acquire an optimal matching atom, stopping matching decomposition when preset conditions are achieved, and representing the initial seismic trace as a series of linear combinations of Morlet wavelet atoms; transforming the optimal matching Morlet atom into the time-frequency domain so as to acquire a time-frequency spectrum distribution of the initial seismic trace; extracting directly properties of earthquake fluid activity on a target stratum section on the time-frequency spectrum of earthquake materials; and predicting distribution range and space distribution of gas deposit according to the properties of the fluid activity. By the method, the distribution range and the space distribution of the gas deposit can be accurately predicted, so that a technical support is provided for favorable target optimization of natural gas exploration.

The invention relates to a method for identifying thin-reservoir subtle lithologic oil and gas reservoir, belonging to the technical field of petroleum exploration and development. The method disclosed by the invention comprises the following steps: calculating a quality factor of the stratum, and performing secondary high-frequency compensation on the post-stack seismic data by utilizing inverse Q filtering according to the quality factor so as to acquire ideal seismic data; performing seismic response feature research on target stratum according to the ideal seismic data, clearing the reservoir waveform features, and making a seismic data skeleton section according to the waveform reflection characters on the top and bottom surfaces of the reservoir; and finely depicting surface distribution of a sand body on the basis of the seismic data skeleton section, determining the boundary of the sand body by utilizing seismic attribution analysis so as to determine the thin-reservoir subtle lithologic oil and gas reservoir. According to the method disclosed by the invention, proved by specific examples, the subtle lithologic oil and gas reservoir can be reliably identified, and the heating identification rate of the thin-reservoir subtle lithologic oil and gas reservoir is improved.

The invention relates to a preparation method of a profile control agent for oil field deep temporary blocking, belonging to the technical field of petroleum exploration. Phenolic resin, organic chromium, glacial acetic acid, resorcinol and polyacrylamide are firstly weighed according to mass percentages, then the weighed polyacrylamide is slowly added in weighed water and stirred, and the weighted other retarding crosslinking agents are sequentially added and stirred. The profile control agent for the oil field deep temporary blocking prepared by the method has the advantages that the gelling time of the profile control agent is controllable during the use by adding different crosslinking agents, the gelling time is 8-48 hours; the gel strength is great, the gel is difficult to break, and the validity period is 1-2 years; the profile control agent can effectively change the water flow of injection water of a formation and have great absorption and blocking effects on the formation.

This invention relates to a method for improving the seismic resolution in the field of petroleum exploration and development. The major problems with regard to the present low vertical seismic resolution, and the thin layer, which is recognized by the seismic data administered with difficult, may be resolved according to the present invention. This method essentially comprises the following steps of: (a) ensuring the depth and the velocity of the low-velocity layer and the high-velocity layer and the characteristic of the frequency spectrum of the seismic wave at the near-surface using the borehole-micro-logging method; (b) separating the virtual reflected wave from the seismic record in the high-velocity layer using the processing method of the vertical seismic section, and improving the SNR of the seismic record of the direct path wave at the high-velocity layer using the stack processing method of porches of the vertical seismic section; (c) evaluating the de-convolution operator of the near-surface by the convolution math-physics type equation; (d) evaluating the seismic record with high resolution by the de-convolution math-physics type equation; (e) providing the band-pass filtering and geologic interpretation to the seismic record with high resolution. Using the method of the present invention, the apparent dominant frequency may be reached to 200 Hz and higher, the vertical seismic resolution is improved, and the problem that it is difficult to recognize the thin layer by the present seismic exploration is resolved.

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 belongs to the petroleum exploration field and relates to a seismic recognition method of low-order strike-slip faults in complex structural areas. The seismic recognition method of the low-order strike-slip faults in the complex structural areas includes the following steps that: post-stack seismic data quality is analyzed; processing is carried out to obtain an advantageous frequency division phase band; processing is carried out to obtain Sobel operators in main directions; processing is carried out to Sobel operators in arbitrary directions; a multi-direction lower-order strike-slip fault system is extracted; and the reliability of the low-order strike-slip faults is verified. The method of the invention is suitable for seismic recognition and verification reliability of lower-order strike slip faults in any complex structural belts and can directly reflect the combination modes and spatial locations of lower-order strike-slip faults on a plane; and the method is an effective measure to determine low-order hidden faults in low signal-to-noise ratio and low-frequency seismic data areas and can provide an important basis for re-understanding of hidden fault oil control rules, reservation and production improvement, development plan deployment and adjustment in complex structural oil and gas fields or fault block oil and gas fields.

The invention provides a shale pore structure detection method based on nuclear magnetic resonance. The method comprises the steps that a sample is processed into a cylinder; the sample is saturated with water at normal pressure for 12h, and then is taken out; CPMG pulse sequence test is carried out on the sample to acquire a spin-echo-series attenuation signal; the spin-echo-series signal is inversed to acquire a T2 spectrum distribution diagram and the details of each peak; and the T2 spectrum of acquired same sample under water saturation and centrifugation is analyzed in a coordinate system to acquire the change of the volume and quantity of pores of the sample. The shale pore structure is mainly studied in a saturated water state in the prior art of nuclear magnetic resonance, and the problems that the study angle is single and limited; only pore distribution can be studied; and fracture prediction cannot be carried out are solved. The method provided by the invention belongs to the technical field of petroleum exploration and development.

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 discloses a method for making artificial rock core, relating to the field of petroleum exploration. The method for making the artificial rock core comprises the following steps: selecting skeleton particles with grain size distribution same as that of the natural rock core; mixing 58-65 parts of skeleton particles and 0-7 parts of stratum water and uniformly mixing after 2-6 parts of a cementing agent is added; and cleaning the inner part of a mold, putting the mixture in the mold and pressing under a hydraulic press, drying and setting shape in an oven, naturally cooling to the normal temperature and taking out the mold to obtain the artificial rock core. According to the method, rock coreswith different porosities, penetration ratesand cementation degrees can be produced through the stratum water under the condition of no change of the consumption amount of the cementing agent and pressing pressure; and the rock cores produced according to the method are close to the natural rock cores in the aspects of physical properties, pore structure, contact way, cementation degree and the like, and can be used for rock core flow experiments.

The invention discloses a seismic sedimentology interpretation method based on frequency-scale matching, and belongs to the field of petroleum exploration and development. The seismic sedimentology interpretation method comprises the following steps: (1) loading post-stack seismic data, (2) carrying out phase switching, obtaining a phase seismic data body with the angle of 90 degrees, (3) confirming the average thickness of a main exploration target sand body according to well-point analysis, (4) confirming the tuning frequency of the target sand body, (5) processing the seismic data in a fractional frequency mode, obtaining a fractional frequency seismic data body reflecting the target sand body, (6) manufacturing strata slices of the fractional frequency data body, (7) interpreting the strata slices, obtaining plane distribution and evolution of the target sand body, (8) when sand bodies with various thickness levels exist, carrying out operations on the sand body at each level according to the step (4) to the step (7), (9) combining the interpretation results of the slices with the same depth of various fractional frequency bodies, and interpreting characteristics and evolution of research area sedimentary microfacies. The seismic sedimentology interpretation method based on the frequency-scale matching is used for interpretation of the thin-layer sedimentary characteristics under a seism vertical resolution ratio, remarkably improves thin-layer sedimentary seismic interpretation accuracy and is wide in application prospect.

The invention relates to a fine well-drilling cuttings oil-abundance analysis method based on nuclear magnetic resonance technology. The method includes the following steps: debugging and calibrating a nuclear magnetic resonance analytical apparatus; making up a rock oil-abundance working curve at target horizon, getting rock cuttings at a reservoir layer without oil gas at the target horizon within the work area and preparing the rock cuttings into a sample mixture of crude oil and cuttings; soaking the sample mixture in water-soluble paramagnetic ion solution; conducting nuclear magnetic resonance analysis; with the intensity of nuclear magnetic resonance signals as the abscissa and the content of crude oil in the sample as the ordinate, drawing a rock oil-abundance working curve of the target horizon; and then calculating the rock oil-abundance data. The method can analyze well-drilling cuttings real-timely, work out the rock oil-abundance data real-timely and carry out quantitative evaluation to the oil-abundance of the reservoir layer, providing real-time technical support to oil exploration, development and production.

A three dimension strata feature interpretation method based on geological information acquired data relates to the interpretation of three-dimensional hydrocarbon reservoir in petroleum exploration and development. To overcome the defect that the existing two-dimensional plane intersection method can not reflect the layer attribute feature faithfully, the invention comprises the following steps: A. establishing a work area, B. loading history data and management, C. processing data and selecting parameters as the variables of X-axis, Y-axis and Z-axis respectively, D. evaluating layer attribute, E. displaying a three-dimension chart, F. loading the data to be detected and judging layer attribute of the data to be detected, G. interpreting output results. The geological information data related to the variables of X-axis, Y-axis and Z-axis is at least one of gas logging data, engineering logging data, geochemical logging data, quantitative fluorescence logging data, nuclear magnetic logging data and logging data, and also can be the combinatorial operation and adjustable coefficient of the above parts. The invention has the advantages of raising the interpretation accuracy in complex condition, faithfully showing the layer attribute feature in working area and providing foundation for exploration and development decision.

Method for exploiting a fluid within an underground formation comprising a layer traversed by a fracture network and a well.

From property measurements relative to the layer, the fracture network is characterized by statistical parameters and a discrete fracture network model is constructed. For each well, three simplification zones surrounding the well are defined. From the statistical parameters, an equivalent permeability tensor and a parameter characterizing the orientation and the vertical continuity of the fractures are determined for each zone. For each zone, a simplification of the discrete fracture network model is determined as a function of the zone, the equivalent permeability tensor and the value of the parameter. An optimum exploitation scheme is defined for the formation fluid from the simplified fracture network model and a flow simulator.

Application: notably petroleum exploration and exploitation.

PCT No. PCT/BE97/00006 Sec. 371 Date Jul. 14, 1998 Sec. 102(e) Date Jul. 14, 1998 PCT Filed Jan. 15, 1997 PCT Pub. No. WO97/26440 PCT Pub. Date Jul. 24, 1997A core sampler, particularly for use in oil prospecting, including a flexible movable ring (5), provided in particular at the front end (2) of the core sampler, which end is connected to a coring bit (3), for grasping a core sample (C) to be brought to the surface. The ring has a cylindrical internal surface (6) to be clamped around the core sample (C), and a frustoconical external surface (7) tapering towards the front end (2). In the end or starting position, the ring (5) is exposed to zero or minimal strain from the bearing surface (12) and has an internal diameter no smaller than the outer diameter of the core sample (C) to be grasped. The core sampler (1) comprises control mechanism for longitudinally moving the movable ring (5) from the end starting position to an end clamping position. A flexible sleeve (15) is advantageously substantially coaxial with the movable ring (5) and engages the side thereof opposite the front end (2) of the core sampler (1).

A method for predicting the state of a geological formation. The method may include generating a separation key effective to extract a first feature from a signal or signals corresponding to a first state and a second feature, distinct from the first feature, from a signal or signals corresponding to a second state. The separation key may list at least one feature operator and a weighting table. The at least one feature operator may expand a test signal collected from a geological formation of unknown state in at least one of frequency space and time space to generate a plurality of feature segments. A weighting table may weight the plurality of feature segments. The weighted plurality of feature segments may be superimposed to form a third feature. The geological formation may be classified as having one of the first state and second state based on the correspondence of the third feature to one of the first feature and second feature.

The invention relates to a method for analyzing the crude oil mass fraction in the drilling well fluid by a nuclear magnetic resonance technology. On the basis of the theory for measuring the oil content by nuclear magnetic resonance, the method realizes the quantitative analysis of the oil mass fraction of the drilling well fluid in a petroleum drilling well by a nuclear magnetic resonance analytical instrument through manufacturing a working curve of the oil mass fraction of the drilling well fluid in a target layer and carrying out the nuclear magnetic resonance continuous analysis of the drilling well fluid along the drilling. The method comprises the steps of calibrating by the nuclear magnetic resonance analytical instrument, manufacturing the working curve of the oil mass fraction of the drilling well fluid, collecting and processing a drilling well fluid sample, analyzing by nuclear magnetic resonance and solving the oil mass fraction in the drilling well fluid. After being applied, the invention can accurately detect the oil content of the drilling well fluid, analyze the drilling well fluid in the well drilling process in time at the well drilling scene, obtain the analytical data of the oil content of the drilling well fluid in time and achieve the quantitative evaluation on the oiliness of a storing and collecting layer, has real, accurate and reliable measured data and provides technology support for the exploration, development and production of petroleum in time.