Abstract

A VSP-based depth domain seismic profile horizon calibration method includes steps: obtaining VSP wavefield data of a depth domain (S10); determining first arrival time information on the basis of the VSP wavefield data (S20); processing the VSP wavefield data on the basis of a preset filtering method and the first arrival time information to obtain upgoing wave data (S30); generating a zero offset profile of the depth domain on the basis of the upgoing wave data (S40); and calibrating, on the basis of the zero offset profile, a depth-domain profile to be calibrated, so as to generate a corresponding calibration result (S50). Also provided are a VSP-based depth domain seismic profile horizon calibration apparatus and a computer-readable storage medium.

IPC Classes  ?

• G01V 1/50 - Analysing data

Abstract

LMHLMHLMHMGIMGIMGI. High-resolution wave-impedance inversion is therefore effectively performed.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

The present application relates to the technical field of seismic data imaging and migration in geophysical prospecting for petroleum. Provided are a multi-wave migration imaging method and apparatus based on an iterative deconvolutional imaging condition. The method comprises: acquiring a seismic wave forward wave field and a seismic wave reverse wave field; using a deconvolutional imaging condition to perform multi-wave imaging on the seismic wave forward wave field and the seismic wave reverse wave field so as to obtain an initial imaging result; taking the seismic wave forward wave field, the seismic wave reverse wave field and the initial imaging result as inputs, using an iterative deconvolutional imaging method to perform multi-wave imaging, so as to obtain an iterative deconvolutional multi-wave imaging result; during the multi-wave imaging, determining an objective function value of the deconvolutional imaging; if the objective function value does not meet a preset condition, iterating the imaging result until the objective function value of the deconvolutional imaging meets the preset condition, and generating a final iterative deconvolutional multi-wave imaging result according to an imaging result obtained after iteration.

IPC Classes  ?

• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

The present invention belongs to the field of fault diagnosis. Provided are a construction method for a fault grouping model, and a fault grouping method and system. The construction method for a fault grouping model comprises: training a cyclic generative adversarial network by using a first style image dataset consisting of a plurality of straight lines and a second style image dataset consisting of faults, so as to obtain an image sample having a fault style, wherein the cyclic generative adversarial network comprises a first generator, a second generator, a first discriminator and a second discriminator, the first generator being used for generating a fault image from a first style image, the second generator being used for generating a straight line image from a second style image, and the first discriminator and the second discriminator being used for determining the probability that an input image is a real image; performing fault tag labeling on the image sample to obtain an image sample having a fault tag; and training a fault grouping neural network by means of the image sample having the fault tag, so as to obtain a fault grouping model. The embodiments of the present invention can improve the accuracy of the fault grouping model.

IPC Classes  ?

• G06V 10/764 - Arrangements for image or video recognition or understanding using pattern recognition or machine learning using classification, e.g. of video objects
• G06T 3/00 - Geometric image transformations in the plane of the image

Abstract

A method for inverting a formation wave impedance using DAS borehole seismic data, including: acquiring an initial magnitude at a time window after the initial arrival time of seismic wavefield data in a well; mapping the initial magnitude to a relative wave impedance; and correcting the relative wave impedance to obtain an inverted wave impedance. Also provided are an apparatus for inverting a formation wave impedance using DAS borehole seismic data, a device, and a computer-readable storage medium.

IPC Classes  ?

• G01V 1/30 - Analysis
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging

Abstract

A method for global phase IQ Demodulation of optical fiber DAS data includes: acquiring initial optical fiber DAS IQ data from DAS instrument; determining a corresponding direct phase value based on the initial optical fiber DAS IQ data, performing an interrogation pulse phase correction operation on the initial optical fiber DAS IQ data based on the direct phase value to obtain first processed data; performing a receiving point initial phase correction operation on the first processed data to obtain second processed data; performing an interrogation pulse linear phase correction operation on the second processed data to obtain third processed data; performing a receiving point linear phase correction operation on the third processed data to obtain fourth processed data; and performing phase unwrapping processing and de-near DC component processing on the fourth processed data to obtain global phase demodulated data.

IPC Classes  ?

• G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means

Abstract

The present disclosure provides a device for full-wave field seismic source based on a gas explosion technology and a method for acquiring seismic data. The device includes a cylindrical explosion-proof metal outer barrel, and four sides of the explosion-proof metal outer barrel are fixedly connected to four high-strength steel plates. The device also includes a cylindrical explosion-proof metal gas explosion inner barrel and pipelines for injecting high-pressure air and high-pressure gas into the gas explosion inner barrel. A center of the gas explosion inner barrel is installed with an electronic ignition gun, which is connected to a GPS timing module connected to the electronic ignition gun. The device further includes a controller configured to control a seismic source of a gas explosion full-wave field. Longitudinal wave source signals propagating vertically downward and perpendicular to ground, shear wave source signals propagating downward and parallel to a seismic source line direction, and shear wave source signals propagating downward and perpendicular to the seismic source line direction are triggered in sequence at each seismic source point. Longitudinal wave data and two transverse wave data orthogonal to each other and parallel to the ground excited through the each seismic source point are recorded in sequence by three-component geophones deployed on the ground, thereby achieving full-wave field exploration.

IPC Classes  ?

• G01V 1/137 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids which fluids escape from the generator in a pulsating manner, e.g. for generating bursts
• G01V 1/04 - Generating seismic energy Details

Abstract

A viscous medium based migration imaging method, relating to the technical field of oil geophysical prospecting, and comprising: determining a total attenuation travel time and a phase compensation function of seismic waves in a viscous medium; constructing an amplitude compensation function related to absorption attenuation; constructing the amplitude compensation function having gain control; determining a new viscous medium compensation function on the basis of the phase compensation function and the amplitude compensation function of the seismic waves in the viscous medium; performing Fourier transform on seismic records of receiver points of the seismic waves in the viscous medium to obtain the seismic record of a frequency domain; performing frequency division compensation on the seismic record of the frequency domain on the basis of the new viscous medium compensation function to obtain seismic data obtained after compensation; and performing pre-stack depth migration processing on said seismic data to obtain a viscous medium based migration imaging profile. Further provided is a viscous medium based migration imaging device. The problem of absorption attenuation compensation of a region having a small Q value can be solved, and the resolution of a seismic imaging profile is improved.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/30 - Analysis

Abstract

A method and device for suppressing interference fading noise of optical fibre sensing data are disclosed. The method contains acquiring optical fibre sensing data not subjected to interference fading noise suppression; determining a fading point amplitude threshold based on the optical fibre sensing data; determining a signal fading point based on the fading point amplitude threshold; performing signal interpolation processing on the optical fibre sensing data corresponding to the signal fading point to obtain a signal subjected to interference fading noise suppression; performing phase demodulation and phase unwrapping processing on the signal subjected to interference fading noise suppression to obtain processed optical fibre sensing data.

IPC Classes  ?

• H04B 10/2537 - Arrangements specific to fibre transmission for the reduction or elimination of distortion or dispersion due to scattering processes, e.g. Raman or Brillouin scattering
• G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• H04B 10/071 - Arrangements for monitoring or testing transmission systemsArrangements for fault measurement of transmission systems using a reflected signal, e.g. using optical time domain reflectometers [OTDR]

Abstract

Disclosed are an improved method and device for calibrating the depth of an optical fibre in a well. The method includes acquiring borehole seismic wave field data based on an optical fibre acoustic wave sensor; determining first arrival time information based on the borehole seismic wave field data; determining a downgoing wave first arrival amplitude based on the first arrival time information and the borehole seismic wave field data; determining an optical fibre amplitude feature point based on the downgoing wave first arrival amplitude; determining a wellhead initial position and a receiving point spacing of the optical fibre in the well based on the optical fibre amplitude feature point and logging curve feature points; and determining depth calibration information of the optical fibre in the well based on the wellhead initial position and the receiving point spacing.

IPC Classes  ?

• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01V 1/50 - Analysing data

Abstract

A stable convergence least squares migration inversion method: acquiring seismic observation data (S1); performing pre-stack depth migration processing, anti-migration processing, and amplitude regularization processing on the seismic observation data, so as to obtain amplitude-regularized seismic data (S2-S6); performing matching subtraction on the seismic observation data and the amplitude-regularized seismic data to obtain a seismic data residual value (S7); on the basis of the seismic data residual value, and on the basis of least squares reverse time migration, solving an inverse gradient field by using an adjoint state method (S8); performing amplitude calibration processing on the gradient field by using an amplitude calibration operator to obtain a processed gradient field (S9); on the basis of the processed gradient field, using an inversion method to calculate an update step length, and updating the inversion coefficient until the inversion converges (S10). Also provided is a stable convergence least squares migration inversion apparatus. The least squares objective function can be converged, and the convergence and stability of inversion are improved.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/30 - Analysis
• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
• G06F 17/10 - Complex mathematical operations

Abstract

A method for creating a seismic geosteering profile, comprising: sequentially acquiring planar coordinate points of a vertical section and a build-up section of a horizontal well according to a drilling trajectory (101); on the basis of a preset seismic grid spacing, adjusting the positions and quantity of the planar coordinate points to obtain adjusted planar coordinate points (102); obtaining a target curve on the basis of the adjusted planar coordinate points and a preset drilling target, and determining intersection points between the target curve and lines of a seismic grid (103); determining a target seismic trace in the seismic grid on the basis of the intersection points (104); and obtaining a seismic geosteering profile on the basis of the target seismic trace (105). Also provided is an apparatus for creating a seismic geosteering profile. The present invention has the advantages of reducing the amount of calculation and the calculation time, rapidly and accurately obtaining an apparent stratigraphic dip to guide horizontal drilling, and improving the drilling encounter ratio.

IPC Classes  ?

• G01V 1/30 - Analysis
• E21B 7/04 - Directional drilling

Abstract

The present invention relates to the technical field of seismic data processing; provided are a shear wave splitting correction method, a system, a storage medium, and an electronic device. The method comprises: acquiring shear wave data, performing fast and slow wave separation on the shear wave data to obtain fast shear wave data and slow shear wave data, and performing post-stack processing on the fast shear wave data and the slow shear wave data to obtain post-stack fast shear wave data and post-stack slow shear wave data; calculating time difference data between the post-stack fast shear wave data and the post-stack slow shear wave data using a dynamic time adjustment algorithm; and performing shear wave data correction on the basis of the time difference data. The present method prevents shortcomings such as the shear wave correction process of manual picking of fast shear wave layer positions and corresponding slow shear wave layer positions being time-consuming and laborious, and there being picking errors, and a cross-correlation method having low time window length selection and calculation efficiency, and large result errors being.

IPC Classes  ?

• G06F 18/15 - Statistical pre-processing, e.g. techniques for normalisation or restoring missing data

Abstract

The present disclosure provides a method and a system for acquiring seismic data of a four-component ocean bottom node (OBN). The method is implemented by the system, comprising controlling installations of a plurality of ocean bottom submerged buoys and a plurality of four-component OBN seismic data acquisition instruments and sending positioning signals and timing signals to the plurality of ocean bottom submerged buoys through armored opto-electronic composite cables. The method also includes obtaining real-time and uninterrupted water temperature data, pressure data, density data, and salt saturation data along the armored opto-electronic composite cables from the ocean surface to locations of the plurality of ocean bottom submerged buoys, and calculating real-time and three-dimensional data of waters of a whole measurement work area through interpolation. The method further includes performing real-time correction on a hydroacoustic velocity of each hydroacoustic propagation trajectory based on the location, the hydroacoustic propagation trajectory and the three-dimensional data of each acquisition instrument.

IPC Classes  ?

• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern

Abstract

The present disclosure provides a device for full-wave field seismic source based on a gas explosion technology and a method for acquiring seismic data. The device includes a cylindrical explosion-proof metal outer barrel, and four sides of the explosion-proof metal outer barrel are fixedly connected to four high-strength steel plates. The device also includes a cylindrical explosion-proof metal gas explosion inner barrel and pipelines for injecting high-pressure air and high-pressure gas into the gas explosion inner barrel. A center of the gas explosion inner barrel is installed with an electronic ignition gun, which is connected to a GPS timing module connected to the electronic ignition gun. The device further includes a controller configured to control a seismic source of a gas explosion full-wave field. Longitudinal wave source signals propagating vertically downward and perpendicular to ground, shear wave source signals propagating downward and parallel to a seismic source line direction, and shear wave source signals propagating downward and perpendicular to the seismic source line direction are triggered in sequence at each seismic source point. Longitudinal wave data and two transverse wave data orthogonal to each other and parallel to the ground excited through the each seismic source point are recorded in sequence by three-component geophones deployed on the ground, thereby achieving full-wave field exploration.

IPC Classes  ?

• G01V 1/137 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids which fluids escape from the generator in a pulsating manner, e.g. for generating bursts
• G01V 1/04 - Generating seismic energy Details

Abstract

A chronostratigraphic-domain stratigraphic sedimentary cycle analysis method, comprising: performing multi-horizon tracking on seismic data by using horizon tracking technology, so as to obtain a chronostratigraphic body (101); transforming all horizons in the chronostratigraphic body from a time domain to a chronostratigraphic domain (102); extracting a depositional-hiatus sequence or a stratigraphic denudation amount sequence on the basis of endpoint positions of each horizon in the chronostratigraphic domain (103); converting the depositional-hiatus sequence or the stratigraphic denudation amount sequence into a stratigraphic sedimentary cycle curve (104); and obtaining a stratigraphic sedimentary cycle sequence on the basis of the stratigraphic sedimentary cycle curve (105). Further provided are a chronostratigraphic-domain stratigraphic sedimentary cycle analysis apparatus and a machine-readable storage medium. The chronostratigraphic-domain stratigraphic sedimentary cycle analysis method and apparatus can effectively improve the accuracy and objectivity of sequence stratigraphic analysis, and improve the efficiency and precision of seismic interpretation.

IPC Classes  ?

• G01V 1/30 - Analysis

Abstract

The present invention provides a multi-wave multi-domain adaptive seismic horizon auto-tracking method and device. The multi-wave multi-domain adaptive seismic horizon auto-tracking method comprises: acquiring seismic data, and setting seed points on the seismic data; determining seismic relative resolutions according to seismic waveforms of seismic traces where the seed points are located; determining horizon tracking parameters according to the seismic relative resolutions; determining horizon points according to the horizon tracking parameters and the seismic traces where the seed points are located; replacing the seed points with the horizon points, and then performing corresponding iterative calculation to obtain a plurality of horizon points having one-to-one correspondence to the seismic traces in the seismic data; and combining the horizon values corresponding to the plurality of horizon points into seismic horizon data and then outputting the seismic horizon data. According to the present invention, the precision and adaptability of horizon auto-tracking for different types of seismic data can be remarkably improved.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

The present invention provides an SV-wave elastic impedance inversion method and device. The method comprises: according to SV-wave seismic data of a target working area, generating angle-stack seismic data of the target working area; according to an initial transverse wave velocity model and an initial density model of the target working area and incident angles in the seismic data, generating an initial SV-wave elastic impedance model; and performing inversion on the initial SV-wave elastic impedance model according to the seismic data to determine SV-wave elastic impedance. According to the SV-wave elastic impedance inversion method and device provided in embodiments of the present invention, elastic impedance inversion can be performed by using SV-wave seismic data, and parameters such as SV-wave elastic impedance, transverse wave velocity, and density are obtained by calculation, thereby providing high-resolution reservoir parameters for reservoir and oil reservoir description in multi-wave exploration.

IPC Classes  ?

• G01V 1/30 - Analysis

Abstract

A noise identification method and apparatus (200), and a device (300) and a storage medium. The method comprises: respectively performing TAUP transformation on water detection component data and land detection z component data, and acquiring the transformed water detection component data and the transformed land detection z component data; determining corresponding first amplitude envelope component data according to the transformed water detection component data, and determining corresponding second amplitude envelope component data according to the transformed land detection z component data (102); determining a corresponding similarity coefficient according to the first amplitude envelope component data and the second amplitude envelope component data (103); performing median filtering processing on the similarity coefficient, so as to determine a corresponding transverse wave leakage noise data interval (104); and determining corresponding transverse wave leakage noise data according to the transverse wave leakage noise data interval and the transformed land detection z component data (105). Noise data is further identified by means of the degree of similarity between amplitude envelope component data, such that the noise data can be effectively identified.

IPC Classes  ?

• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas

Abstract

A method for determining the speed of a subsurface medium, comprising: by using an ocean bottom node, collecting seismic data generated by exciting a monopole seismic source at a shot point (101); determining a dipole seismic source and a zero-phase monopole seismic source according to the monopole seismic source, and combining the dipole seismic source and the zero-phase monopole seismic source to obtain a directional sub-wave (102); exchanging the position of the ocean bottom node and the position of the shot point and, by using the exchanged node, collecting seismic simulation data generated by exciting the directional sub-wave at the exchanged shot point (103); and, according to an upgoing wave of the seismic data and the seismic simulation data, determining a target speed model (104). By processing the monopole seismic source as well as obtaining the directional sub-wave having directional features, collecting the seismic simulation data generated by exciting the directional sub-wave at the shot point, and determining the speed model by means of the seismic simulation data and the upgoing wave of the seismic data, the precision of the speed model can be improved. Further provided are an apparatus for determining the speed of a subsurface medium, an electronic device, a computer-readable storage medium, and a program product.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

000011112222333 after imbalance correction. By means of the method, I/Q signals can be accurately corrected, and fiber demodulation noise can be accurately and efficiently suppressed, thereby improving the acquisition quality of distributed fiber acoustic sensing data.

IPC Classes  ?

• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means

Abstract

Embodiments of the present invention disclose a coherent fading noise suppression method and a noise suppression apparatus for optical fiber sensing data. The method comprises: acquiring optical fiber sensing data before coherent fading noise suppression; determining a fading point amplitude threshold on the basis of the optical fiber sensing data; determining a signal fading point on the basis of the fading point amplitude threshold; performing signal interpolation processing on optical fiber sensing data of the signal fading point to obtain a coherent fading noise-suppressed signal; and performing phase demodulation and phase unwrapping processing on the coherent fading noise-suppressed signal to obtain processed optical fiber sensing data. Collected original optical fiber sensing data is analyzed, a signal fading point of the optical fiber sensing data is determined by means of a mode for determining a fading point amplitude threshold, and interpolation processing is performed on the original optical fiber sensing data according to the signal fading point. Thus, the problem of coherent fading of optical fiber sensing data during a collection process is solved, the accuracy of the collected optical fiber sensing data is improved, and actual requirements of technicians are met.

IPC Classes  ?

• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
• G06K 9/00 - Methods or arrangements for reading or recognising printed or written characters or for recognising patterns, e.g. fingerprints

Abstract

The present invention provides an intelligent geophysical data acquisition system and acquisition method for shale oil and gas optical fiber. A pipe string is arranged in a metal casing, and an external armored optical cable is fixed outside the metal casing; an, internal armored optical cable is fixed outside the pipe string; the external armored optical cable comprises a downhole acoustic sensing optical cable, two multi-mode optical fibers, a strain optical cable and a pressure sensor array, and further comprises horizontal ground acoustic sensing optical cables arranged in the shallow part of the ground according to an orthogonal grid, and artificial seismic source excitation points arranged on the ground according to the orthogonal grid.

IPC Classes  ?

• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus
• G01D 5/353 - Mechanical means for transferring the output of a sensing memberMeans for converting the output of a sensing member to another variable where the form or nature of the sensing member does not constrain the means for convertingTransducers not specially adapted for a specific variable using optical means, i.e. using infrared, visible or ultraviolet light with attenuation or whole or partial obturation of beams of light the beams of light being detected by photocells influencing the transmission properties of an optical fibre
• G01V 1/50 - Analysing data
• E21B 47/07 - Temperature
• E21B 47/09 - Locating or determining the position of objects in boreholes or wellsIdentifying the free or blocked portions of pipes
• E21B 47/007 - Measuring stresses in a pipe string or casing
• E21B 17/02 - CouplingsJoints
• E21B 43/116 - Gun or shaped-charge perforators
• E21B 47/12 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
• E21B 43/26 - Methods for stimulating production by forming crevices or fractures
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• E21B 47/107 - Locating fluid leaks, intrusions or movements using acoustic means

Abstract

A method for improving a DAS signal-to-noise ratio by means of local FK transform. The method comprises: acquiring seismic wave field data (101); segmenting the seismic wave field data into a plurality of pieces of local data, wherein each piece of local data has the same dimension as the seismic wave field data (102); processing each piece of local data by means of the following steps: performing FK transform to obtain an intermediate signal, removing some FK spectrum components from the intermediate signal according to scanning energy which corresponds to the intermediate signal under different apparent slowness, and performing two-dimensional inverse FFT on the intermediate signal, from which some FK spectrum components are removed (103); and combining all the processed local data, so as to obtain new seismic wave field data (104). The method can effectively improve the signal-to-noise ratio of seismic data collected by an optical fiber, and is suitable for the denoising processing process of other seismic data. Further provided are an apparatus for improving a DAS signal-to-noise ratio by means of local FK transform, and a device and a computer-readable storage medium.

IPC Classes  ?

• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy

Abstract

A method for inverting a formation wave impedance using DAS well seismic data, comprising: acquiring an initial magnitude at a time window after the initial arrival time of seismic wavefield data in a well (101); mapping the initial magnitude to a relative wave impedance (102); and correcting the relative wave impedance to obtain an inverse wave impedance (103). Also provided are an apparatus for inverting a formation wave impedance using DAS well seismic data, a device, and a computer-readable storage medium.

IPC Classes  ?

• G01V 1/30 - Analysis

Abstract

Disclosed in the embodiments of the present invention are a depth calibration method for a downhole optical fiber, and a depth calibration apparatus for a downhole optical fiber. The method comprises: acquiring downhole seismic wave field data on the basis of an optical fiber acoustic wave sensor; determining first break time information on the basis of the downhole seismic wave field data; determining a first break amplitude of a downlink wave on the basis of the first break time information and the downhole seismic wave field data; determining an optical fiber amplitude feature point on the basis of the first break amplitude of the downlink wave; determining an initial wellhead position and a receiving point spacing of a downhole optical fiber on the basis of the optical fiber amplitude feature point and a well-logging curve feature point; and determining depth calibration information of the downhole optical fiber on the basis of the initial wellhead position and the receiving point spacing. By means of improving an existing optical fiber depth correction method, after denoising processing and first break pickup are performed according to downhole seismic wave field data collected by an optical fiber acoustic wave sensor, an initial wellhead position and a receiving point spacing of a downhole optical fiber are determined in combination with existing well-logging data, thereby calibrating the depth position of the downhole optical fiber, and improving the accuracy of depth calibration.

IPC Classes  ?

• G06T 7/80 - Analysis of captured images to determine intrinsic or extrinsic camera parameters, i.e. camera calibration

Abstract

A global phase quadrature demodulation method and apparatus for optical fiber sensing data. The method comprises: acquiring initial optical fiber sensing IQ data; determining a corresponding direct phase value on the basis of the initial optical fiber sensing IQ data, and executing a light source phase correction operation on a direct phase to obtain first processed data; executing a reception point initial phase correction operation on the first processed data to obtain second processed data; performing a light source linear phase correction operation on the second processed data to obtain third processed data; executing a reception point linear phase correction operation on the third processed data to obtain fourth processed data; and performing phase unwrapping processing and near-direct current component removal processing on the fourth processed data to obtain global phase demodulated data. According to the present solution, various influence factors of initial optical fiber sensing data are analyzed, a corresponding data optimization processing method is employed, the problems existing during the acquisition process of optical fiber sensing data are solved, and the accuracy of the optical fiber sensing data is improved.

IPC Classes  ?

• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means

Abstract

A VSP-based level calibration method for a depth-domain seismic profile, comprising: obtaining vertical seismic wave field data of a depth domain (S10); determining first-arrival time information on the basis of the vertical seismic wave field data (S20); processing the vertical seismic wave field data on the basis of a preset filtering method and the first-arrival time information to obtain upgoing wave data (S30); generating a self-stimulating and self-receiving profile of the depth domain on the basis of the upgoing wave data (S40); and calibrating, on the basis of the self-stimulating and self-receiving profile, a depth-domain profile to be calibrated, so as to generate a corresponding calibration result (S50). Also provided are a VSP-based level calibration apparatus for a depth-domain seismic profile and a computer-readable storage medium.

IPC Classes  ?

• G01V 1/30 - Analysis

Abstract

The present invention provides a full-wave-field seismic source apparatus based on a gas explosion technology, and a seismic source data acquisition method. The full-wave-field seismic source apparatus comprises: a cylindrical explosion-proof metal outer barrel, wherein four high-strength steel plates are connected and fixed to the four sides of the explosion-proof metal outer barrel; a cylindrical explosion-proof metal gas explosion inner barrel; pipelines for injecting high-pressure air and high-pressure gas into the gas explosion inner barrel; an electronic ignition gun, placed at the center of the gas explosion inner barrel; a GPS time service timing module, connected to the electronic ignition gun; and a controller for controlling a gas explosion full-wave-field seismic source. According to the present invention, a longitudinal wave seismic source signal that is perpendicular to the ground and vertically downwards propagated, a shear transverse wave seismic source signal that is parallel to the direction of a seismic source line and downwards propagated, and a shear transverse wave seismic source signal that is perpendicular to the direction of the seismic source line and downwards propagated are sequentially excited at each seismic source point, and a three-component geophone arranged on the ground can sequentially record longitudinal wave data that is excited by the full-wave-field seismic source apparatus and perpendicular to the ground, and two pieces of transverse wave data that is excited by the full-wave-field seismic source apparatus, and is orthogonal to each other and parallel to the ground, and thus, full-wave-field exploration is truly realized.

IPC Classes  ?

• G01V 1/137 - Generating seismic energy using fluidic driving means, e.g. using highly pressurised fluids which fluids escape from the generator in a pulsating manner, e.g. for generating bursts
• G01V 1/18 - Receiving elements, e.g. seismometer, geophone

Abstract

An ocean bottom four-component node seismic data acquisition system, comprising multiple ocean bottom subsurface buoys (1), multiple ocean surface buoys (4), armored photoelectric composite cables (10), multiple ocean bottom four-component node seismic data acquisition instruments (11), and an ocean surface energy source boat (13). A data acquisition method of the ocean bottom four-component node seismic data acquisition system, comprising: the ocean surface buoys (4) transmit positioning and timing signals to the ocean bottom subsurface buoys (1) by means of the armored photoelectric composite cables (10), and the four-component node seismic data acquisition instruments (11) arranged in the ocean bottom perform accurate positioning and timing by means of underwater acoustic signals emitted from underwater acoustic signal emission sources (2) in the ocean bottom subsurface buoys (1) arranged around a work area. A composite modulation and demodulation instrument (8) and a continuous grating fiber cable built in the ocean surface buoy (4) measure a seawater temperature, pressure, density and salt saturation values from the ocean surface to the ocean bottom in real time for realtime correction of underwater acoustic velocity for an underwater acoustic propagation track between each ocean bottom subsurface buoy (1) to each ocean bottom four-component node seismic data acquisition instrument (11), so as to ensure that the positioning and timing accuracy of the ocean bottom node seismic instruments (11) meets an error requirement.

IPC Classes  ?

• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
• G01H 9/00 - Measuring mechanical vibrations or ultrasonic, sonic or infrasonic waves by using radiation-sensitive means, e.g. optical means
• G01D 21/02 - Measuring two or more variables by means not covered by a single other subclass

Abstract

A comprehensive geophysical exploration system for a high-temperature geothermal field, and a geothermal sweet spot area evaluation method. A large-area infrared remote sensing measurement and a radioactive measurement are performed, and three-component seismic longitudinal wave and seismic transverse wave data collection, ground three-dimensional broadband magnetotelluric data collection, and ground high-density three-dimensional gravity data collection are performed in a high-surface-temperature and high-radioactivity area. Geophysical parameters that are highly sensitive to a high-temperature geothermal field are searched by using well logging and DAS-VSP data during well drilling in an exploration area of a high-temperature geothermal field; longitudinal wave velocity fields, transverse wave velocity fields, longitudinal and transverse wave velocity ratios, Poisson ratios, resistivity, and density data volumes of underground three-dimensional spaces at the same depth position are compared and calibrated, a geothermal sweet spot area with a high temperature, fault fracture development and a rich underground water source supply is delineated according to the selected geophysical parameters that are highly sensitive to the high-temperature geothermal field, and detailed investigation and comprehensive evaluation are performed on the predicted geothermal sweet spot area, such that a high-temperature geothermal field is quickly and efficiently explored and found at a low cost.

IPC Classes  ?

• E21B 47/00 - Survey of boreholes or wells
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves
• E21B 49/00 - Testing the nature of borehole wallsFormation testingMethods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
• G01V 9/00 - Prospecting or detecting by methods not provided for in groups

Abstract

A method for removing tube wave interference from optical fiber acoustic wave sensing seismic data, including: acquiring seismic wavefield data which contains a tube wave and is collected by an optical fiber acoustic wave sensing instrument; calculating a root-mean-square amplitude of the waveform data cut on the seismic trace as an amplitude normalization factor; performing normalization processing on the amplitude value; performing de-tail mean filtering processing on the normalized amplitude value along the travel time of the tube wave, to obtain a predicted amplitude value; performing tube wave interference removal processing on each seismic trace, and performing inverse normalization processing to obtain the seismic wavefield data without tube wave interference. The method effectively suppresses the tube wave interference in the optical fiber acoustic wave sensing seismic data. An apparatus for removing tube wave interference from optical fiber acoustic wave sensing seismic data, and a computer device are further provided.

IPC Classes  ?

• G01V 1/48 - Processing data
• G01V 1/18 - Receiving elements, e.g. seismometer, geophone

Abstract

Provided in the prevent application are an underground fluid pressure measurement system based on a continuous grating optical fiber, and a measurement method. The system comprises metal sleeves, wherein tubular columns are arranged in the metal sleeves. The system further comprises armored optical cables, wherein the armored optical cables each comprise an outer armored optical cable and an inner armored optical cable; the outer armored optical cables are fixed on outer sides of the metal sleeves, and are used for measuring a fluid pressure in a pore of an underground rock stratum at each grating position; the inner armored optical cables are fixed on outer sides of the tubular columns, and are used for measuring a fluid pressure in a well at each grating position in the well; and the armored optical cables each comprises two continuous grating optical fibers, which are respectively a first continuous grating optical fiber and a second continuous grating optical fiber. The system further comprises a composite modem, which is placed near a wellhead, wherein the composite modem is respectively connected to first continuous grating optical fibers and second continuous grating optical fibers of two armored optical cables. By means of the present system, the real-time measurement and monitoring of fluid pressures inside and outside a whole well section are realized.

IPC Classes  ?

• E21B 47/06 - Measuring temperature or pressure
• E21B 47/13 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range
• E21B 47/135 - Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling by electromagnetic energy, e.g. of radio frequency range using light waves, e.g. infrared or ultraviolet waves

Abstract

An optical-fiber intelligent geophysical data acquisition system for shale oil and gas, and an acquisition method. A tubing string (6) is placed in a metal sleeve (1), and an outer armored optical fiber cable (2) is fixed on the outer side of the metal sleeve (1); an inner armored optical fiber cable (22) is fixed outside the tubing string (6); the outer armored optical fiber cable (2) internally comprises a downhole acoustic wave sensing optical fiber cable (10), two multi-mode optical fibers (11), a strain optical fiber cable (12) and a pressure sensor array (13); ground acoustic wave sensing optical fiber cables (14) are horizontally arranged at a shallow part of the ground according to orthogonal grids, and artificial seismic source excitation points (7) are arranged on the ground according to orthogonal grids; and six DAS signal ports of a composite modem (5) are respectively connected to the downhole acoustic wave sensing optical fiber cable (10) and the ground acoustic wave sensing optical fiber cables (14), two DTS signal ports of the composite modem (5) are connected to the two downhole multi-mode optical fibers (11), a DSS signal input port of the composite modem (5) is connected to a head end of the strain optical fiber cable (12), and a DPS signal input port of the composite modem (5) is connected to a head end of the pressure sensor array (13).

IPC Classes  ?

• G01V 1/30 - Analysis

Abstract

A submarine optical fiber four-component seismic instrument system and a data collection method thereof. Four-component node seismic instruments are connected, by means of a circular cable ring (2), in series on an armored photoelectric composite cable (3) at certain intervals; the armored photoelectric composite cable (3) is connected to a computer; an external near-field wireless transmission module (6), an external photoelectric conversion module (7) and an external wireless charging module (8) are arranged on a side face of each four-component node seismic instrument in a matching manner, and the modules are all fixed on the armored photoelectric composite cable (3) by means of a functional module sleeve (4); and the four-component node seismic instruments are connected to the computer by means of the external near-field wireless transmission modules (6), and perform communication and data transmission. The system has the characteristics of high sensitivity, wide frequency band, good high-frequency response, linear phase change, good technical parameter consistency, etc. Moreover, there is no electronic element at a front end, so that the system has a higher reliability, that is, the system has the advantages of resistance to high temperature and high voltage, no need of power supply, water resistance, corrosion resistance, capability of being arranged for a long time, electromagnetic interference resistance and small channel crosstalk.

IPC Classes  ?

• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting

Abstract

A safe operation monitoring system and monitoring method for an underground gas storage. The system comprises armored optical cables (6, 7) and quasi-distributed optical fiber pressure sensors (9, 10), which are arranged on the inside and outside of casing pipes (4) of all gas injection wells (1), gas recovery wells (2) and monitoring wells (3) and on the outside of in-well gas injection and recovery pipes (5); underground three-component detector arrays (8), which are arranged in some of the monitoring wells (3); and composite modulation and demodulation instruments (11), which are placed in the vicinity of wellheads. According to the monitoring method, by comprehensively using all underground noise, temperature, pressure and stress/strain changes and distribution features of microseismic events that are monitored in real time online, intelligent comprehensive analysis and evaluation are performed on all parameters and information that are monitored in real time online, various risks or accidents affecting the safe and stable operation of a gas storage are graded and classified, and early warning signals and information of accident risks are released in a timely manner, so as to ensure the long-term stable and safe operation of the gas storage.

IPC Classes  ?

• E21B 47/00 - Survey of boreholes or wells
• E21B 47/06 - Measuring temperature or pressure
• E21B 47/07 - Temperature

Abstract

A method for removing tube wave interference from optical fiber acoustic wave sensing seismic data. The method comprises: acquiring seismic wave field data which contains tube wave interference and is collected by an optical fiber acoustic wave sensor; along the travel time of a tube wave, downwardly intercepting, on each seismic wave, waveform data of a preset time window length, and calculating the root-mean-square amplitude of the waveform data intercepted from each seismic wave and taking same as an amplitude normalization factor for each seismic wave; performing normalization processing on the amplitude value of each seismic wave at each time sampling point; performing trimmed-mean filtering processing, along the travel time of the tube wave, on the normalized amplitude value of each seismic wave at each time sampling point, so as to obtain a predicted amplitude value of the tube wave at each time sampling point; and according to this, performing tube wave interference removal processing on each seismic wave at each time sampling point, and finally performing inverse normalization processing so as to obtain seismic wave field data from which tube wave interference is removed. By means of the method, tube wave interference in optical fiber acoustic wave sensing seismic data is effectively suppressed. An apparatus for removing tube wave interference from optical fiber acoustic wave sensing seismic data, and a computer device and a computer-readable storage medium are further comprised.

IPC Classes  ?

• G01V 1/48 - Processing data
• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy

Abstract

A method for extracting a downgoing wavelet and attenuation parameters by using vertical seismic data, comprising: performing upgoing and downgoing wave separation processing on vertical seismic wave field data to obtain downgoing longitudinal wave data; performing a Fourier transform on seismic trace data having a first arrival time window length being a set value in the downgoing longitudinal wave data, and obtaining downgoing longitudinal wave data having experienced the Fourier transform and a multi-trace downgoing longitudinal wave logarithmic spectrum; removing a downgoing wavelet logarithmic spectrum from the multi-trace downgoing longitudinal wave logarithmic spectrum, to obtain a downgoing longitudinal wave logarithmic spectrum having experienced multi-trace wavelet correction; performing, according to parameter data of the downgoing longitudinal wave logarithmic spectrum having experienced multi-trace wavelet correction, correction and an inverse Fourier transform on the downgoing longitudinal wave data having experienced the Fourier transform to obtain a downgoing wavelet; and obtaining attenuation parameters according to a longitudinal wave first arrival time and the parameter data of the downgoing longitudinal wave logarithmic spectrum having experienced multi-trace wavelet correction. The method has high accuracy in extracting a downgoing wavelet and attenuation parameters. Also provided are an apparatus for extracting a downgoing wavelet and attenuation parameters by using vertical seismic data, a computer device, and a computer readable storage medium.

IPC Classes  ?

• G01V 1/40 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging
• G01V 1/48 - Processing data

Abstract

A mounting device (2) and hooking device for hooking a geophone node (100), and a separation device. The mounting device comprises a rope (21), a plurality of hanging rings (22), and hooks (23) having one-to-one correspondence to the hanging rings (22). The mounting device (2) can improve the placement efficiency and recovery efficiency of the geophone node (100). The hooking device comprises a hooking mechanism (1). The hooking mechanism (1) comprises a portal frame (11), a rope passing tube (12), and two hook bins (13). The hooking device can quickly achieve the hooking of the hanging rings (22) and the hooks (23) between the geophone node (100) and the rope (21) while releasing the rope (21), thereby improving the hooking efficiency of the geophone node (100) and the rope (21). The separation device comprises a pulling mechanism (4) and a separation mechanism (5). The separation device can improve the separation efficiency of the geophone node (100) and the rope (21) while pulling the rope (21).

IPC Classes  ?

• G01V 1/18 - Receiving elements, e.g. seismometer, geophone
• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern

Abstract

A drilling rig and a matching drill pipe (5) for use with same. The drilling rig comprises a gear-type pneumatic motor (1), a decelerator (2), a power shaft (3), a rotary seal device (4) and a matching drill pipe (5) for use with same. An output end of the gear-type pneumatic motor (1) and the decelerator (2) mesh with each other and are drive-connected. One end of the power shaft (3) is connected to the decelerator (2) and the other end is in threaded connection with the drill pipe (5). An air pump air supply interface (1-1), a pneumatic motor air inlet (1-2) and an air-blowing opening (1-3) are respectively disposed at one side of the gear-type pneumatic motor (1). The rotary seal device (4) comprises a U-shaped rotary seal housing (4-1), a seal gasket (4-2) and an oil seal (4-3). A rotary seal air inlet (4-4) is formed at each of two sides of the rotary seal housing (4-1). The rotary seal air inlet (4-4) is in communication with an inner cavity of the power shaft (3). The rotary seal air inlet (4-4) is in communication with the air-blowing opening (1-3) by means of an air duct.

IPC Classes  ?

• E21B 7/00 - Special methods or apparatus for drilling
• E21B 21/16 - Methods or apparatus for flushing boreholes, e.g. by use of exhaust air from motor using gaseous fluids

Abstract

A method for evaluating accuracy in positioning a receiver point, which is associated with at least one shot point, and for which a derived position data is obtained, wherein a pair of the receiver point and a respective shot point is associated with a characteristic parameter which includes an offset, a velocity of first arrival wave and a first arrival time, the method comprising: step S10, constructing a residual vector associated with the receiver point and the respective shot point based on the characteristic parameter; step S12, determining a characterization parameter of the derived position data based on the residual vector; and step S14, evaluating accuracy of the derived position data based on the characterization parameter. An apparatus for evaluating accuracy in positioning a receiver point is also provided.

IPC Classes  ?

• G01S 5/22 - Position of source determined by co-ordinating a plurality of position lines defined by path-difference measurements

Abstract

A geophone locating accuracy evaluation method, provided with a geophone, wherein the geophone is correspondingly provided with at least one shot point and has locating position data; the geophone has a characteristic parameter corresponding to each shot point; and the characteristic parameter comprises a shot-geophone distance, a first arrival wave speed and a first arrival time. The method comprises: step S10, constructing a residual vector between the geophone and each shot point on the basis of the characteristic parameter; step S12, determining a characterization parameter for locating position data on the basis of the residual vector; and step S14, evaluating the accuracy of locating position data by using the characterization parameter. Further provided is a geophone locating accuracy evaluation device.

IPC Classes  ?

• G01V 1/20 - Arrangements of receiving elements, e.g. geophone pattern
• G01V 13/00 - Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups

Abstract

i-1, i=1, . . . N, and D is an initial side length of the grid cell and not more than a double of a distance between the respective observation points; searching all nodes in a first layer of grid to acquire a node satisfying a preset condition therefrom; from i=2, determining and searching nodes satisfying a first preset requirement in the i-th layer of grid, to acquire a node satisfying the preset condition therefrom, until a search in an N-th layer of grid is completed, wherein a node satisfying the preset condition acquired in the N-th layer of grid is a seismic source point location.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• G01V 1/30 - Analysis

Abstract

The present application provides a method and device for determining overall metrics of seismic geometry repeatability, wherein the method comprises: selecting baseline geometry and monitor geometry; matching shot-receiver pairs of the baseline geometry with shot-receiver pairs of the monitor geometry to obtain multiple matching relationships; calculating overall geometry repeatability of each of the multiple matching relationships according to a predetermined calculation formula for multi-trace geometry repeatability, to obtain overall geometry repeatabilities corresponding to the multiple matching relationships; taking the minimum value among the overall geometry repeatabilities corresponding to the multiple matching relationships as overall repeatability metrics between the monitor geometry and the baseline geometry. In the embodiments of the present application, by using the above method, the aim of accurately determining repeatability of multiple shot-receiver pairs in time-lapse seismic acquisition can be achieved, and thus the monitoring efficiency of seismic geometry repeatability can be improved.

IPC Classes  ?

• G01V 1/30 - Analysis
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting

Abstract

A method and system for epicentre positioning in microseism monitoring. The method comprises: acquiring a monitoring area and each observation point in the monitoring area (S101); dividing the monitoring area into N grids according to epicentre positioning accuracy, wherein side length of a grid unit of an i-th grid is D/2 i-1, i=1,N, and D being an initial edge length of the grid unit (S102); searching for all nodes in a first grid to acquire a node meeting a preset condition (S103); starting from i=2, determining and searching for a node meeting a first preset requirement in the i-th grid to obtain a node therein which meets the preset condition, continuing until completing search of the Nth grid, wherein a node in the Nth grid which meets the preset condition is an epicentre position (S104). Said method and system for epicentre positioning may implement high-precision positioning of a microseism epicentre and have a small number of calculations.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

A method and system for epicentre positioning in microseism monitoring. The method comprises: acquiring a monitoring area and each observation point in the monitoring area (S101); dividing the monitoring area into N grids according to epicentre positioning accuracy, wherein side length of a grid unit of an i-th grid is D/2 i-1, i=1,…N, and D being an initial edge length of the grid unit (S102); searching for all nodes in a first grid to acquire a node meeting a preset condition (S103); starting from i=2, determining and searching for a node meeting a first preset requirement in the i-th grid to obtain a node therein which meets the preset condition, continuing until completing search of the Nth grid, wherein a node in the Nth grid which meets the preset condition is an epicentre position (S104). Said method and system for epicentre positioning may implement high-precision positioning of a microseism epicentre and have a small number of calculations.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

A method and device for determining an overall measurement of seismic observation system repeatability, wherein the method comprises: selecting a baseline observation system and a monitoring observation system (101); matching offset pairs from the baseline observation system with offset pairs from the monitoring observation system to obtain multiple matching relationships (102); respectively performing calculation on the multiple matching relationships according to a preset multi-track observation system repeatability formula, so as to obtain overall repeatability values of the observation system corresponding to each of the multiple matching relationships (103); using a minimum value of the overall repeatability values of the observation system corresponding to each of the multiple matching relationships as an overall measurement of repeatability between the monitoring observation system and the baseline observation system (104). By using the above method, the situation in which offset pairs are different and matching cannot be confirmed between the baseline observation system and the monitoring observation system can be solved, and the aim of accurately determining repeatability of multiple offset pairs in time-lapse seismic acquisition can be realized, thus increasing the monitoring efficiency for repeatability in seismic observation systems.

IPC Classes  ?

• G01V 1/30 - Analysis

Abstract

An automatic inspection and monitoring method based on time domain slotting control, belonging to the technical field where the field personnel can automatically inspect and monitor a field device of a seismic apparatus in the seismic exploration production. A method of extraction and transmission of a seismic apparatus host on the information of a field device is implemented by a master control program, test information about the seismic apparatus host on the field device can be automatically extracted and classified from the seismic apparatus host, and according to a designed push protocol, a protocol encoding is conducted; a data frame block is automatically generated; and then the information is delivered via a broadcasting station; an encoding protocol of information push is designed for avoiding information loss caused by signal instability, etc. during information push. According to the protocol, the state information on the field device is encoded to generate a data frame block. There is no more need in the present invention for the operating personnel of the seismic apparatus to read and broadcast the content of the field device item by item, and it only needs to set a software operation mode, so that the automatic extraction and transmission of the state information on the field device can be extracted and transmitted.

IPC Classes  ?

• G05B 19/048 - MonitoringSafety
• H04B 13/02 - Transmission systems in which the medium consists of the earth or a large mass of water thereon, e.g. earth telegraphy
• H04L 29/08 - Transmission control procedure, e.g. data link level control procedure
• H04L 12/911 - Network admission control and resource allocation, e.g. bandwidth allocation or in-call renegotiation
• H04L 12/26 - Monitoring arrangements; Testing arrangements
• G05B 19/418 - Total factory control, i.e. centrally controlling a plurality of machines, e.g. direct or distributed numerical control [DNC], flexible manufacturing systems [FMS], integrated manufacturing systems [IMS] or computer integrated manufacturing [CIM]
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• G01V 1/22 - Transmitting seismic signals to recording or processing apparatus

Abstract

A monitoring system for use in seismic instrument arrangement in petroleum exploration, belonging to the technical field of network transmission of seismic instrument arrangement information, comprises a host server and a hand-held terminal device, wherein the host server is configured to be connected to a host machine of a seismic instrument, manipulated by an instrument operator, can extract the seismic instrument arrangement information, classify field arrangement information based on the corresponding setting and transmit the arrangement information by using a 2G/3G network; the hand-held terminal device can receive the field arrangement information transmitted by the host server, by the 2G/3G network, and alarm and remind line inspection personnel to conduct an arrangement check; after completing the inspection task, the line inspection personnel can send inquiry information via the hand-held terminal device to inquire of the instrument operator about the line inspection condition. The present invention reduces the difficulty of checking an arrangement at the time of the seismic exploration and production, shortens the required time for checking an arrangement and plays an important role in improving a production efficiency of seismic exploration.

IPC Classes  ?

• G01V 1/42 - SeismologySeismic or acoustic prospecting or detecting specially adapted for well-logging using generators in one well and receivers elsewhere or vice-versa
• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting

Abstract

A method for looking for an oil and gas reservoir on the basis of TRAP-3D software. The method comprises: establishing the three-dimensional lithological character and fault data cube of an exploration work area according to three-dimensional earthquake information and logging information (S101); dividing the three-dimensional lithological character and fault data cube into a plurality of depth slices with an equal depth, and performing separate sand body unit division on each depth slice (S102); and sequentially inputting the depth slices of the three-dimensional lithological character and fault data cube into the TRAP-3D software to perform the oil and gas reservoir evaluation (S103a, S103b). By means of the method, the accuracy of the three-dimensional trapping evaluation is improved, precise seeking of the oil and gas reservoir is facilitated, the dessert map on the plane can be drawn out, the oil and gas trapping amount of different depths in the longitudinal direction is displayed, and the total trapping amount of the oil and gas reservoir in the exploration work area can be obtained.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/30 - Analysis

Abstract

The present invention provides a method of searching for oil-gas reservoir based on TRAP-3D software, including: establishing a three-dimensional lithology and fault data cube of an exploration working area according to three-dimensional seismic data and logging data; dividing the three-dimensional lithology and fault data cube into several depth slices of the same depth, and performing an individual sand body unit division for each depth slice; sequentially inputting the depth slices of the three- dimensional lithology and fault data cube into the TRAP-3D software for oil-gas reservoir evaluation. The present invention imporves the accuracy of three-dimensional trap evaluation, is conducive to precise searching of the oil-gas reservoir, can plot a Sweet-Spot diagram on a plane, and get exhibits oil-gas trap amounts of different depths in a longitudinal direction, and can obtain a total trap amount of the oil gas reservoir in the exploration working area.

IPC Classes  ?

• G01V 11/00 - Prospecting or detecting by methods combining techniques covered by two or more of main groups

Abstract

The present invention provides a method of searching for an oil-gas reservoir based on TRAP-3D software, including: establishing a three-dimensional lithology and fault data cube of an exploration working area according to three-dimensional seismic data and logging data; dividing the three-dimensional lithology and fault data cube into several depth slices of the same thickness, and performing an individual sand body unit division for each depth slice; sequentially inputting the depth slices of the three-dimensional lithology and fault data cube into the TRAP-3D software for oil-gas reservoir evaluation. The present invention improves the accuracy of three-dimensional trap evaluation, is conducive to precise searching of the oil-gas reservoir, can plot a Sweet-Spot diagram on a plane, and get exhibits oil-gas trap amounts of different depths in a longitudinal direction, and can obtain a total trap amount of the oil gas reservoir in the exploration working area.

IPC Classes  ?

• E21B 43/00 - Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
• G01V 1/30 - Analysis
• G01V 1/34 - Displaying seismic recordings
• G01V 1/50 - Analysing data

Abstract

A monitoring system for use in seismic instrument arrangement in petroleum exploration, belonging to the technical field of network transmission of seismic instrument arrangement information, comprises a host server and a hand-held terminal device, wherein the host server is configured to be connected to a host machine of a seismic instrument, manipulated by an instrument operator, can extract the seismic instrument arrangement information, classify field arrangement information based on the corresponding setting and transmit the arrangement information by using a 2G/3G network; the hand-held terminal device can receive the field arrangement information transmitted by the host server, by the 2G/3G network, and alarm and remind line inspection personnel to conduct an arrangement check; after completing the inspection task, the line inspection personnel can send inquiry information via the hand- held terminal device to inquire of the instrument operator about the line inspection condition. The present invention reduces the difficulty of checking an arrangement at the time of the seismic exploration and production, shortens the required time for checking an arrangement and plays an important role in improving a production efficiency of seismic exploration.

IPC Classes  ?

• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting

Abstract

An automatic inspection and monitoring method based on time domain slotting control, belonging to the technical field where the field staff can automatically inspect and monitor a field device of a seismic apparatus in the seismic exploration production. An extraction and transmission method for information about a field device of a seismic apparatus host is achieved via a master control program. In this method, testing information about the seismic apparatus host on the field device can be automatically extracted and classified from the seismic apparatus host; according to a designed push protocol, the protocol encoding is conducted; a data frame block is automatically generated; and then the information is transmitted via a broadcasting station. An encoding protocol of information push is designed for avoiding information loss caused by signal instability, etc. during information push. According to the protocol, the state information about the field device is encoded to generate a data frame block. Therefore, the operating staff of the seismic apparatus has no need to read and broadcast the content of a field device item by item, and only needs to set a software operation mode, so that the automatic extraction and transmission of the state information about the field device can be achieved.

IPC Classes  ?

• G05B 19/418 - Total factory control, i.e. centrally controlling a plurality of machines, e.g. direct or distributed numerical control [DNC], flexible manufacturing systems [FMS], integrated manufacturing systems [IMS] or computer integrated manufacturing [CIM]

Abstract

A seismic instrument arrangement monitoring system for use in petroleum exploration comprises a host server and a hand-held terminal device. The host server is used to connect to a seismic instrument host, and is operated by an instrument operator to extract seismic instrument arrangement information, classify field arrangement information according to corresponding settings, and send the arrangement information by using a 2G/3G network. The hand-held terminal device receives the field arrangement information from the host server by using the 2G/3G network and sends an alarm to prompt a line check personnel to perform arrangement check. After finishing the check task, the line check personnel sends query information by using the hand-held terminal device to query the instrument operator for a line check situation. The present invention reduces the difficulty of arrangement check in seismic exploration and production, shortens the time required for arrangement check, and has a significant role in improving the yield of seismic exploration and production.

IPC Classes  ?

• G01V 1/00 - SeismologySeismic or acoustic prospecting or detecting
• H04L 29/12 - Arrangements, apparatus, circuits or systems, not covered by a single one of groups characterised by the data terminal

Abstract

An automatic inspection and monitoring method based on time domain slotting control, belonging to the technical field where the field staff can automatically inspect and monitor a field device of a seismic apparatus in the seismic exploration production. An extraction and transmission method for information about a field device of a seismic apparatus host is achieved via a master control program. In this method, testing information about the seismic apparatus host on the field device can be automatically extracted and classified from the seismic apparatus host; according to a designed push protocol, the protocol encoding is conducted; a data frame block is automatically generated; and then the information is transmitted via a broadcasting station. An encoding protocol of information push is designed for avoiding information loss caused by signal instability, etc. during information push. According to the protocol, the state information about the field device is encoded to generate a data frame block. Therefore, the operating staff of the seismic apparatus has no need to read and broadcast the content of a field device item by item, and only needs to set a software operation mode, so that the automatic extraction and transmission of the state information about the field device can be achieved.

IPC Classes  ?

• G05B 19/418 - Total factory control, i.e. centrally controlling a plurality of machines, e.g. direct or distributed numerical control [DNC], flexible manufacturing systems [FMS], integrated manufacturing systems [IMS] or computer integrated manufacturing [CIM]

Abstract

Provides is a method for performing layer Q factor inversion by using an amplitude spectrum attribute of a downlink wave of vertical seismic profile data in a geophysical data processing technology. In the method, first an F-K (frequency-wave number) method is used to perform wave field separation on VSP original data, so as to obtain a downlink wave; a downlink sub-wave and a monitoring sub-wave are selected to undergone Fourier transform to obtain an amplitude spectrum, polynomial fitting is performed on the amplitude spectrum to obtain an equivalent Q, and a formula between the equivalent Q and a layer Q is used to perform inversion, so as to obtain the layer Q. The method has a strong capability of resisting random disturbance, and is capable of removing a difference of triggering sub-wave. The algorithm is simple and can greatly save workload; moreover, the layer Q value obtained through inversion has a desirable stability and high precision.

IPC Classes  ?

• G01V 1/30 - Analysis
• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection

Abstract

The present invention is a method for determining a best low-frequency scanning signal of a controlled seismic source. The method comprises: using equifrequency scanning signals, gradually increasing the output force of a seismic source to perform excitation, fitting the actually output maximum output force of actually measured low-frequency sampling points of the seismic source using the least square method, determining a low-frequency output curve of the controlled seismic source according to the focuses of a maximum fitted weight dropper displacement curve and a system flow curve, calculating the scanning duration of a low frequency range, and the frequency, the amplitude and the phase of each sampling point of the low frequency range, generating a scanning signal and practically testing same on the seismic source, and obtaining a best low-frequency scanning signal until the vibration results don't exceed the weight dropper displacement limit or the flow limit. The present invention enables low-frequency components of a scanning signal of a controlled seismic source to be apparently strengthened, is applicable to the existing controlled seismic source, and can exert the maximum potential of the low frequency of the controlled seismic source. The distortion of a low-frequency signal is small, and the output spectrum of the controlled seismic source is smoothly whitened, thereby being able to better protect the controlled seismic source.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/30 - Analysis
• G01V 1/147 - Generating seismic energy using mechanical driving means using impact of dropping masses
• G01V 1/143 - Generating seismic energy using mechanical driving means

Abstract

The present invention is a method of poles configuration with four poles inter-combination for marine electromagnetic surveying and acquisition. The method of the present invention adopts six horizontal electric field components with four poles inter-combination. The six horizontal electric field components are respectively constituted from tri-pins grounding electrodes of four poles pairwise. One of the pins of each of the tri-pins grounding electrodes and the pins of the other three tri-pins grounding electrodes mutually constitute the six horizontal electric field components. The data for electromagnetic field over time series are simultaneously recorded. The present invention effectively ensure that the electric field recording with an angle less than 22.5 degree to the activation direction is achieved regardless of the orientation of the acquisition station, and that the worst effective activation signal may reach 76.5% of that under collinear activation. It is ensured that the activation field source and the couple pole for recording the electric field are under strong coupling, the requirements on the orientation of the acquisition station and on the dragging direction and position of the activation field source in data acquisition are lowered, and loss of electromagnetic data is prevented.

IPC Classes  ?

• G01V 3/12 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with electromagnetic waves
• G01V 1/38 - SeismologySeismic or acoustic prospecting or detecting specially adapted for water-covered areas
• G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
• G01R 33/10 - Plotting field distribution

Abstract

A method for exploring of gradient geochemistry includes the following steps: densely collecting soil samples and gas samples along a longitudinal direction in a certain depth range of a superficial layer; collecting soil samples and gas samples in the range from 1 m to 50 m deep by a special drilling machine; after conventionally analyzing and processing the geochemical indexes, extracting and figuring the bathymetric curve and its gradient curve, the section curve and its gradient section curve along a certain direction, contour section and its gradient contour section of the various indexes, so as to process the data and to represent the figure in 3D. More plentiful information, especially the longitudinal change information, can be obtained by this method than by conventional geochemical exploration. Gradient prospecting is realized through the formed method prospecting the change of geochemical indexes with depth by collecting the samples along depth.

IPC Classes  ?

• G01N 1/02 - Devices for withdrawing samples

Abstract

A four electrodes combination and arrangement method for sea electromagnetic exploration comprises the step of recording six horizontal electric field components ((M11N11, M12N21, M13M21, N13N22, M23N23, M22N12)) by combining the four electrodes, wherein each electrode has three separate grounded pins, and respectively connects to the other three electrodes through a wire. The loss of electromagnetic data is prevented according to the method above.

IPC Classes  ?

• G01V 3/30 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation specially adapted for well-logging operating with electromagnetic waves

Abstract

Three dimensional small bins electromagnetic consecutive array data acquisition method in oil exploration, the steps are, when gathering and recording using small bins lattice on execution of arranging electrodes, each acquisition station (Ex, Ey) gathering and recording natural electromagnetic field time series data with the same acquisition parameter simultaneously, processing the data recorded to remove the interference first, and obtaining observation data that have no interference, for border points and center point, using the recording point as center, adding the same component from adjacent two points to total points respectively to obtain the average values on time domain electric field data of all observation points; for angular points, calculating the average values of the same electric field component from adjacent two points to total observation points toward bin direction; serving the electric field components obtained in maximum space as the new observation field values respectively; obtaining new time series data in which the noise and the static displacement effect having been suppressed, and obtaining apparent resistivity and phase curves of each point after processing by conventional method.

IPC Classes  ?

• G01V 3/08 - Electric or magnetic prospecting or detectingMeasuring magnetic field characteristics of the earth, e.g. declination or deviation operating with magnetic or electric fields produced or modified by objects or geological structures or by detecting devices
• G06F 17/40 - Data acquisition and logging

Abstract

A method of pre-stack two-dimension-like transformation of three-dimensional seismic record is accomplished by the following steps: acquiring 3D seismic data, and arranging them according to a shot gather; calculating the offsets of all the wave detection points from the first detection line of the first shot; making a straight line((L2')which connects the shot point (S) and the wave detection point (R1) of the smallest offset as the transformed coordinate axis, and making the shot point (S) as the center, drawing circles whose radii are the offsets (offseti) of each wave detection point, then rotating each wave detection point to the straight line (L2'), thereby accomplishing the two-dimension-like transformation of all the detection lines of the shot, and getting three-dimensional seismic data graph with high precision; and then making the processing of the noise elimination and static correction on the three-dimensional seismic record using conventional technique.

IPC Classes  ?

• G01V 1/28 - Processing seismic data, e.g. for interpretation or for event detection
• G01V 1/36 - Effecting static or dynamic corrections on records, e.g. correcting spreadCorrelating seismic signalsEliminating effects of unwanted energy
• G06T 15/00 - 3D [Three Dimensional] image rendering