WO2024067458A1 - 随钻vsp井驱地震成像方法及装置 - Google Patents

随钻vsp井驱地震成像方法及装置 Download PDF

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Publication number
WO2024067458A1
WO2024067458A1 PCT/CN2023/121000 CN2023121000W WO2024067458A1 WO 2024067458 A1 WO2024067458 A1 WO 2024067458A1 CN 2023121000 W CN2023121000 W CN 2023121000W WO 2024067458 A1 WO2024067458 A1 WO 2024067458A1
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velocity
migration
seismic
results
vsp
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English (en)
French (fr)
Inventor
孙甲庆
寇龙江
王靖
刘金涛
王小卫
苏勤
王孝
徐兴荣
金保中
凌越
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Petrochina Co Ltd
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Petrochina Co Ltd
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    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G01V1/30—Analysis
    • G01V1/303—Analysis for determining velocity profiles or travel times
    • G01V1/305—Travel times
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G01V1/30—Analysis
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/28—Processing seismic data, e.g. for interpretation or for event detection
    • G01V1/30—Analysis
    • G01V1/307—Analysis for determining seismic attributes, e.g. amplitude, instantaneous phase or frequency, reflection strength or polarity
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V1/00—Seismology; Seismic or acoustic prospecting or detecting
    • G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
    • G01V1/44—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging using generators and receivers in the same well
    • G01V1/46—Data acquisition
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/50—Corrections or adjustments related to wave propagation
    • G01V2210/51—Migration
    • G01V2210/512—Pre-stack
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/61—Analysis by combining or comparing a seismic data set with other data
    • G01V2210/616—Data from specific type of measurement
    • G01V2210/6169—Data from specific type of measurement using well-logging
    • G—PHYSICS
    • G01—MEASURING; TESTING
    • G01V—GEOPHYSICS; GRAVITATIONAL MEASUREMENTS; DETECTING MASSES OR OBJECTS; TAGS
    • G01V2210/00—Details of seismic processing or analysis
    • G01V2210/60—Analysis
    • G01V2210/62—Physical property of subsurface
    • G01V2210/622—Velocity, density or impedance
    • G01V2210/6222—Velocity; travel time

Definitions

  • the present invention relates to the field of seismic while drilling technology, and in particular to a VSP well driving while drilling seismic imaging method and device.
  • Oil drilling is a high-investment, high-risk underground project.
  • the understanding of underground conditions is vague, which brings great risks to the drilling operation. Therefore, exploration technology that detects various parameters of undrilled formations and reservoir and fracture locations is extremely important.
  • the earliest seismic while drilling technology was a method that used the drilling bit as the source signal and received artificial seismic information in real time during the drilling process to detect underground geological conditions.
  • This measurement method has not achieved the expected application effect due to its high requirements for drill bit technology.
  • the VSP (Vertical Seismic Profiling) technology while drilling is to move the source to the ground, and install a detector on the downhole drill bit to receive the energy released by the ground source.
  • This technology cleverly avoids the drill bit problem, but maintains the advantages of real-time measurement without losing drilling time.
  • this measurement method requires the use of professional downhole drilling tools, which is expensive, and has high requirements for instrument stability during the measurement process, which is not conducive to large-scale promotion and application.
  • VSP vertical seismic profiling
  • the single downhole data can only obtain information near the well point. From the current test, it can be found that combining the surface seismic data with downhole data to jointly predict the undrilled strata can obtain more accurate results. For a project that requires high timeliness, ground seismic imaging is often very time-consuming, which is equivalent to increasing exploration costs in disguise.
  • the embodiment of the present invention provides a VSP well driving seismic imaging method while drilling, which is used to realize VSP well driving seismic imaging while drilling, with strong timeliness and high precision.
  • the method includes:
  • the seismic velocity of the target well is updated with the VSP velocity as a constraint to obtain an updated anisotropic velocity volume
  • the seismic velocity field after VSP drive correction is iteratively optimized to obtain the iteratively optimized seismic velocity field and anisotropic parameter field.
  • prestack depth migration volume migration is performed to obtain migration results
  • the maximum probability imaging position of the target well in the target reservoir is determined.
  • the embodiment of the present invention further provides a VSP well driving seismic imaging device while drilling, which is used to realize VSP well driving seismic imaging while drilling, has strong timeliness and high precision, and the device includes:
  • the data acquisition module is used to obtain the seismic data processing results and well logging data within the processing area corresponding to the target well;
  • An optimization and adjustment module is used to optimize and adjust the seismic data processing results and logging data to obtain an anisotropic parameter body of prestack depth migration;
  • the VSP drive correction module is used to update the seismic velocity of the target well with the VSP velocity as a constraint to obtain an updated anisotropic velocity body;
  • Iterative optimization module used to iteratively optimize the seismic velocity field after VSP drive correction based on the anisotropic parameter body, and obtain the iteratively optimized seismic velocity field and anisotropic parameter field;
  • Migration module used to perform pre-stack depth migration volume migration using iteratively optimized seismic velocity field and anisotropic parameter field to obtain migration results
  • a post-stack frequency-boosting modification processing module is used to perform post-stack frequency-boosting modification processing on the migration result to obtain the migration result after the post-stack frequency-boosting modification processing;
  • the imaging position determination module is used to determine the maximum probability imaging position of the target well in the target reservoir according to the migration results after the post-stack frequency enhancement modification processing.
  • An embodiment of the present invention further provides a computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the above-mentioned while-drilling VSP well drive seismic imaging method when executing the computer program.
  • An embodiment of the present invention further provides a computer-readable storage medium, wherein the computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the above-mentioned VSP well driving seismic imaging method while drilling is implemented.
  • An embodiment of the present invention further provides a computer program product, which includes a computer program.
  • a computer program product which includes a computer program.
  • seismic data processing results and logging data within a processing area corresponding to a target well are obtained; the seismic data processing results and logging data are optimized and adjusted to obtain an anisotropic parameter body of pre-stack depth migration; the seismic velocity of the target well is updated with the VSP velocity as a constraint to obtain an updated anisotropic velocity body; based on the anisotropic parameter body, the seismic velocity field after VSP drive correction is iteratively optimized to obtain an iteratively optimized seismic velocity field and anisotropic parameter field; the iteratively optimized seismic velocity field and anisotropic parameter field are used to perform pre-stack depth migration body migration to obtain a migration result; the migration result is subjected to post-stack frequency-boosting modification processing to obtain a migration result after the post-stack frequency-boosting modification processing; and the maximum probability imaging position of the target well in the target reservoir is determined according to the migration result after the post-stack frequency-boosting modification processing.
  • the velocity after VSP drive correction is obtained by taking VSP velocity as a constraint, and the seismic velocity field after VSP drive correction is iteratively optimized based on the anisotropic parameter body to obtain the iteratively optimized seismic velocity field and anisotropic parameter field; the iteratively optimized seismic velocity field and anisotropic parameter field are used to perform pre-stack depth migration body migration to obtain migration results; the migration results are subjected to post-stack frequency enhancement modification to obtain the migration results after post-stack frequency enhancement modification; the maximum probability imaging position of the target well in the target reservoir is determined according to the migration results after post-stack frequency enhancement modification, which greatly improves the timeliness and accuracy of surface seismic imaging, reduces the implementation cost of downhole VSP seismic technology, and plays an important role in giving full play to the effectiveness of downhole VSP seismic technology in improving the drilling success rate and reducing costs and increasing efficiency.
  • FIG1 is a flow chart of a VSP well driving seismic imaging method while drilling according to an embodiment of the present invention
  • FIG2 is a schematic plan view of the data collection scope of the VSP well driving seismic imaging processing while drilling according to an embodiment of the present invention
  • FIG3 is a schematic diagram showing the principle of checking the results of seismic data processing according to an embodiment of the present invention.
  • FIG4 is a schematic diagram of imaging before and after optimizing and adjusting the seismic data processing results in an example of the present invention
  • FIG5 is a schematic diagram of seismic velocity before and after VSP driving in an example of the present invention.
  • FIG6 is a schematic diagram showing the comparison of the updated well point velocity before and after the lateral interpolation and extrapolation method is used in the example of the present invention.
  • FIG7 is a schematic diagram showing a comparison between the Delta value in the anisotropic parameter field established by the method of the present invention and the Delta value in the seismic data processing result in an example of the present invention
  • FIG8 is a schematic diagram showing a comparison of the anisotropic parameter Epsilon before and after updating using the grid tomography iteration method provided by the present invention in an example of the present invention
  • FIG9 is a schematic diagram showing a comparison of the velocity of igneous rocks before and after being updated using the special attribute body velocity update iteration method provided by the present invention in an example of the present invention
  • FIG10 is a schematic diagram showing the comparison of the prestack depth migration volume migration results before and after processing using the Kirchhoff integration method in an example of the present invention
  • FIG11 is a schematic diagram of analyzing the imaging position of a target reservoir using a target point position quantitative analysis method in an example of the present invention
  • FIG12 is a schematic diagram of a VSP well driving seismic imaging device while drilling according to an embodiment of the present invention.
  • FIG. 13 is a schematic diagram of a computer device in an embodiment of the present invention.
  • FIG1 is a flow chart of a method for seismic imaging while drilling VSP well driving according to an embodiment of the present invention, comprising:
  • Step 101 obtaining seismic data processing results and well logging data within the processing area corresponding to the target well;
  • Step 102 optimizing and adjusting the seismic data processing results and the logging data to obtain an anisotropic parameter volume of prestack depth migration
  • Step 103 updating the seismic velocity of the target well with the VSP velocity as a constraint to obtain an updated anisotropic velocity body
  • Step 104 based on the anisotropic parameter volume, iteratively optimize the seismic velocity field after VSP drive correction to obtain the iteratively optimized seismic velocity field and anisotropic parameter field;
  • Step 105 using the iteratively optimized seismic velocity field and anisotropic parameter field, perform prestack depth migration volume migration to obtain migration results;
  • Step 106 performing post-stack frequency boosting modification processing on the migration result to obtain a migration result after the post-stack frequency boosting modification processing
  • Step 107 determining the maximum probability imaging position of the target well in the target reservoir according to the migration result after the post-stack frequency enhancement modification processing.
  • the method proposed in the embodiment of the present invention obtains the velocity after VSP drive correction by taking VSP velocity as a constraint, and iteratively optimizes the seismic velocity field after VSP drive correction based on the anisotropic parameter body to obtain the iteratively optimized seismic velocity field and anisotropic parameter field; performs pre-stack depth migration body migration using the iteratively optimized seismic velocity field and anisotropic parameter field to obtain migration results; performs post-stack frequency enhancement modification on the migration results to obtain the migration results after post-stack frequency enhancement modification; determines the maximum probability imaging position of the target well in the target reservoir according to the migration results after post-stack frequency enhancement modification, thereby greatly improving the timeliness and accuracy of surface seismic imaging, reducing the implementation cost of downhole VSP seismic technology, and playing an important role in giving full play to the effectiveness of downhole VSP seismic technology in improving the drilling success rate and reducing costs and increasing efficiency.
  • VSP velocity acceleration depth and velocity information obtained from VSP (vertical seismic profile) while drilling
  • VSP vertical seismic profile
  • This method belongs to the field of oil and gas exploration, which processes and interprets seismic data in real time during the drilling process, thereby optimizing the drilling target, and is suitable for the target optimization and adjustment stage in the oil geophysical exploration drilling process.
  • the scope of VSP well-drive seismic imaging processing while drilling is determined according to the changes in the geological structure around the target well, and the scope of the processing area corresponding to the target well is determined; then, the seismic data processing results and logging data within the processing area corresponding to the target well are obtained.
  • the seismic data processing results include one or any combination of CMP gather processing results, prestack time migration results, prestack depth migration results, prestack depth migration velocity body, prestack depth migration anisotropic parameter body results, prestack depth migration isotropic parameter body results, and prestack depth migration structural parameter body results;
  • the logging data includes one or any combination of wellhead information, well trajectory information, and well layer information of the well being drilled and surrounding wells.
  • the logging data should be the latest one.
  • the method further includes:
  • the noise that affects profile imaging includes one or any combination of abnormal amplitude, multiple waves, offset arcing, and oblique interference.
  • the pre-stack depth migration velocity body is determined to be reliable.
  • the reliability of the anisotropic parameter body results of the prestack depth migration and the isotropic parameter body results of the prestack depth migration are checked to obtain the reliability check results, and based on the reliability check results, the anisotropic parameter body results of the prestack depth migration and the isotropic parameter body results of the prestack depth migration are optimized.
  • the anisotropic parameter volume result of prestack depth migration and the isotropic parameter volume result of prestack depth migration are optimized, including:
  • the anisotropic parameter volume results of pre-stack depth migration are reliable, the anisotropic parameter volume results of pre-stack depth migration are optimized;
  • the anisotropic parameter volume result of prestack depth migration is unreliable and the isotropic parameter volume result of prestack depth migration is reliable
  • the isotropic parameter volume result of prestack depth migration is optimized, the anisotropic field of prestack depth migration is re-established, and the anisotropic depth migration of prestack depth migration is performed;
  • step 102 the seismic data processing results and the logging data are optimized and adjusted to obtain an anisotropic parameter volume of prestack depth migration;
  • the previous surface seismic processing cannot provide an accurate velocity model, it can provide relatively accurate imaging velocity information. That is to say, the previous seismic velocity is an equivalent model of the true velocity. Therefore, the velocity update can save the time of re-stack depth migration.
  • the residual travel time tomography technology based on ray tracing is used to correct the velocity and anisotropic parameter model. Residual travel time tomography based on ray tracing, or time-preserving tomography, mainly solves a series of large overdetermined equations. These linear equations can be regarded as a set of linear constraints.
  • the steps of optimizing and adjusting the seismic data processing results and logging data include:
  • a first velocity model is obtained based on the seismic data processing results, and a second velocity model is obtained based on the seismic data processing results and current well logging data;
  • the optimized anisotropic parameter volume of prestack depth migration is obtained by solving the time-preserving tomographic linear equations.
  • the seismic velocity and anisotropic parameter fields are directly used for anisotropic prestack depth migration.
  • the convergence degree of target migration imaging is equivalent to that of the original anisotropic prestack depth migration results, but the imaging depth of each marker layer after optimization and adjustment corresponds better to the new logging information.
  • step 103 the seismic velocity of the target well is updated with the VSP velocity as a constraint to obtain an updated anisotropic velocity body.
  • the specific steps include:
  • the initial velocity of the vertical seismic velocity is smoothed to eliminate the influence of excessive changes in layer velocity on the offset, and the vertical seismic velocity above the target well bottom is obtained after correction.
  • the two vertical seismic velocities are calculated to obtain the proportional factor, and the proportional factor is applied to
  • the VSP logging acquisition depth is limited, and there is a velocity blind zone between the VSP bottom and the target point.
  • the VSP velocity or acoustic wave velocity of the surrounding wells should be used as the reference velocity to correct the velocity.
  • the updated seismic velocity below the bottom of the well is spliced with the updated anisotropic velocity volume to form an updated well point velocity.
  • the updated wellpoint velocity is laterally interpolated and extrapolated to obtain the seismic velocity field after VSP drive correction.
  • the vertical seismic velocity above the bottom of the target well is updated with the VSP velocity as a constraint
  • the seismic velocity below the bottom of the target well is updated with the VSP velocity of the surrounding wells of the target well as a constraint.
  • the scale factor at the well point is interpolated and extrapolated to form a scale factor data body
  • the present invention adopts seismic guided velocity interpolation technology for interpolation and extrapolation.
  • This technology does not require seismic horizons, but uses the coherent amplitude trend of seismic imaging data bodies for lateral constraints, which not only improves efficiency, but is also more applicable to data that is difficult to accurately obtain seismic horizons through interpretation, thereby avoiding errors caused by seismic horizon interpretation.
  • step 104 the seismic velocity field after VSP drive correction is iteratively optimized based on the anisotropic parameter body to obtain the iteratively optimized seismic velocity field and anisotropic parameter field; after remodeling the seismic velocity using the VSP velocity drive, the velocity error is reduced and is more consistent with the actual underground geological conditions, but the seismic velocity is a vertical seismic velocity and needs to be combined with the corresponding anisotropic parameter body to obtain the seismic imaging velocity.
  • the seismic velocity field after VSP drive correction is iteratively optimized to obtain the iteratively optimized seismic velocity field and anisotropic parameter field, including:
  • the anisotropic parameter volume has been obtained above, but when the signal-to-noise ratio of the gather is relatively low, the anisotropic parameter volume cannot be quickly updated through grid tomography to obtain relatively accurate seismic imaging.
  • the calculation formula is:
  • ⁇ old is the initial Delta parameter field
  • ⁇ new is the updated Delta parameter field
  • v old is the initial velocity field
  • v new is the velocity field updated in the previous step. is the VSP drive speed proportional factor.
  • the seismic velocity above the VSP bottom hole has been relatively accurate. Therefore, for the area above the VSP bottom hole, the seismic velocity is kept relatively unchanged during the iteration process, and each stronger event axis of each depth-migrated CRP gather is flattened by iterative anisotropy parameters to obtain more accurate pre-stack depth migration imaging.
  • the value range is generally between -0.2 and 0.2, and it is relatively stable in the same formation. Generally, one round of iteration can obtain relatively accurate shallow imaging, which meets the timeliness requirements of VSP-driven processing.
  • a small-scale grid model of the igneous rock section is established based on the initial anisotropic parameter field using high-resolution grid tomography to characterize the igneous rock velocity and perform iterative updates;
  • the preset type attribute body can be a special lithology body such as igneous rock.
  • Small grid iteration is performed on this special lithology body to eliminate the influence of igneous rock velocity on the underlying stratum structure and imaging.
  • VSP velocity has a good reflection of igneous rock velocity, but the igneous rock velocity changes rapidly laterally. Sparse well data cannot fully control the change of igneous rock velocity.
  • High-resolution grid tomography is required to establish a small-scale grid model of the igneous rock section to better characterize the igneous rock velocity.
  • the lateral velocity trend above the marker layer can be well controlled by using the surrounding wells and velocity model. At this time, it is only necessary to perform layer tomography along the marker layer to achieve iterative update of the velocity field. For the velocity below the marker layer, the velocity scanning method is used to ensure the imaging accuracy of the target.
  • the layer-by-layer tomography method to update the velocity above the VSP well bottom layer by layer from shallow to deep, to avoid the accumulation of errors in the geometry of the velocity and the reflection surface, and to improve the lateral velocity accuracy. Then, the velocity of the blind area below the VSP well bottom is scanned to ensure the imaging accuracy of the target point.
  • Anisotropic parameter fields include velocity, delta, epsilon, dip, azimuth, etc.
  • step 105 using the iteratively optimized seismic velocity field and anisotropic parameter field, prestack depth migration volume migration is performed to obtain migration results;
  • the migration method based on wave equation has made great progress.
  • Reverse time migration can image any direction of wave propagation, including reflection wave and multiple wave imaging, can handle multipath problems, and can image overturned structures. It is a typical method of two-way wave equation migration and the most accurate migration algorithm.
  • VSP drive processing must not only consider accuracy but also timeliness.
  • the Kirchhoff integral method is used for pre-stack depth migration volume migration.
  • the Kirchhoff integral method pre-stack depth migration is considered to be an efficient and practical pre-stack depth migration method. It has the characteristics of high migration angle, no dispersion, less resource occupation and high implementation efficiency, and the integral method can adapt to changing observation systems and undulating surfaces. Therefore, the Kirchhoff integral method is currently the most suitable migration method for VSP drive processing.
  • step 106 the migration results are processed by post-stack frequency-boosting modification to obtain the migration results after post-stack frequency-boosting modification.
  • post-stack frequency-boosting modification the migration results are processed by post-stack frequency-boosting modification to obtain the migration results after post-stack frequency-boosting modification.
  • most of the exploration targets have low imaging signal-to-noise ratios and generally have heavy accompanying phases, which makes reservoir imaging difficult to distinguish and requires appropriate post-stack processing.
  • Post-stack processing methods with good amplitude preservation are usually performed on pre-stack gathers, which is time-consuming and cannot meet the timeliness requirements of VSP drive processing. It is necessary to explore fast post-stack processing on post-stack sections.
  • a frequency-boosting modification method with good amplitude preservation are usually performed on pre-stack gathers, which is time-consuming and cannot meet the timeliness requirements of VSP drive processing. It is necessary to explore fast post-stack processing on post-stack sections.
  • the methods for improving the resolution of seismic data on the post-stack profile and compensating for the seismic wave energy loss caused by the attenuation of the underground medium mainly include the inverse Q filtering method, time-frequency analysis absorption compensation and other methods, but these methods have poor amplitude preservation.
  • the embodiment of the present invention proposes to use the amplitude factor preservation technology to perform post-stack frequency-boosting modification processing on the migration results.
  • the amplitude factor preservation technology is used to ensure data amplitude preservation.
  • methods such as inverse Q filtering are used to improve the signal-to-noise ratio and resolution of the target layer, thereby greatly improving target imaging.
  • step 107 the maximum probability imaging position of the target well in the target reservoir is determined based on the migration results after the post-stack frequency-boosting modification process.
  • This process is a target point quantitative analysis, and its principle is to perform a local velocity scan on the target reservoir, analyze the imaging positions of the target reservoir from different scanning results, and finally determine the maximum probability imaging position of the target reservoir.
  • determining the maximum probability imaging position of the target well in the target reservoir includes:
  • the lateral relative relationship of the peripheral velocity of the target body in the migration result is kept unchanged, and a percentage scan is performed (usually in the range of 90%-110%, with an interval of 1%), and imaging is performed respectively to obtain a second imaging result;
  • the current position of the target body's peripheral velocity in the migration result remains unchanged, and a horizontal relative relationship scan is performed, and imaging is performed respectively to obtain the third imaging result; in this step of scanning, there are usually four situations: the forward velocity in the main survey line direction increases, the reverse velocity in the main survey line direction increases, the forward velocity in the direction perpendicular to the main survey line increases, and the reverse velocity in the direction perpendicular to the main survey line increases, and then imaging is performed respectively;
  • the first imaging result, the second imaging result, and the third imaging result are plotted. There are usually four plotting modes: energy distribution, maximum energy position distribution, and maximum energy brightness distribution;
  • the maximum probability imaging position of the target reservoir is selected based on the mapping results.
  • the latest maximum probability imaging position of the target reservoir can be provided to the drilling personnel, so that the well trajectory can be adjusted in time to ensure that the drilling encounters the target reservoir and achieve the purpose of improving the drilling success rate.
  • the seismic data in the example comes from a certain oil field block A.
  • a risk well M1 was drilled in this area in a certain year.
  • the actual layer position differed from the predicted layer position by 100 meters. It was difficult to drill to the established target reservoir based on the original drilling trajectory. Therefore, when the fourth opening was completed, VSP logging was carried out on this well, and the drilling was stopped on site to wait for new seismic data processing results, and a new drilling trajectory adjustment plan was formulated.
  • the processing time is compressed to 68 hours, and the drilling stop time is compressed to 3 days, saving a lot of time and manpower and material costs. Finally, this well successfully drilled the reservoir and tested oil with high yield.
  • FIG2 is a plan view of the data collection range of the while-drilling VSP well drive seismic imaging processing in an embodiment of the present invention.
  • Figure 3 is a schematic diagram of the principle of checking the results of seismic data processing in an embodiment of the present invention.
  • the anisotropic depth migration results are reliable, the anisotropic depth migration results are directly optimized, including obtaining anisotropic velocity models through new understandings of geology and well logging, and then performing VSP drive processing after network tomography.
  • anisotropic depth migration results are unreliable
  • well seismic error statistics and time-preserving tomography are performed to obtain the initial anisotropic parameter body
  • network tomography is performed to obtain anisotropic depth migration.
  • the above steps are followed to determine whether the anisotropic depth migration results are valid.
  • the time domain results i.e., pre-stack time migration results
  • the isotropic depth migration results are determined to be reliable.
  • FIG4 is a schematic diagram of imaging before and after optimizing and adjusting the seismic data processing results in an example of the present invention (the left side is before optimization and adjustment, and the right side is after optimization and adjustment). It can be seen that after optimization and adjustment, the imaging effect is better.
  • FIG5 is a schematic diagram of the seismic velocity before and after VSP driving in the example of the present invention (the left side is before VSP driving, and the right side is after VSP driving). It can be seen that the seismic velocity after VSP driving is more accurate.
  • FIG6 is a schematic diagram showing the comparison before and after lateral interpolation and extrapolation of the updated wellpoint velocity using the lateral interpolation and extrapolation method in an example of the present invention (the left side is before lateral interpolation and extrapolation, and the right side is after lateral interpolation and extrapolation).
  • FIG7 is a schematic diagram showing a comparison between the Delta value in the anisotropic parameter field established by the method of the present invention and the Delta value in the seismic data processing result in an example of the present invention (the left side is the Delta value in the anisotropic parameter field established by the method of the present invention, and the right side is the Delta value in the seismic data processing result);
  • High-resolution grid tomography is used to establish a small-scale grid model of the igneous rock section to characterize the igneous rock velocity; in this case, the seismic velocity from the bottom of the VSP well to the target blind area is iterated by combining layer control and velocity scanning;
  • Figure 8 is a schematic diagram of the comparison of the anisotropic parameter Epsilon before and after the update using the grid tomography iteration method provided by the present invention in the example of the present invention (the left side is before the update, and the right side is after the update).
  • Figure 9 is a schematic diagram of the comparison of the igneous rock velocity before and after the update using the special attribute body velocity update iteration method provided by the present invention in the example of the present invention (the left side is before the update, and the right side is after the update).
  • FIG. 10 is a schematic diagram showing the comparison of the pre-stack depth migration volume migration results before and after processing using the Kirchhoff integration method in an example of the present invention (the left side is before processing, and the right side is after processing).
  • FIG. 11 is a schematic diagram of analyzing the imaging position of the target reservoir using the target point position quantitative analysis method in an example of the present invention.
  • While-drilling VSP well-drive seismic imaging methods greatly improves the timeliness and accuracy of ground seismic imaging and reduces the implementation cost of while-drilling VSP seismic technology. It plays an important role in giving full play to the effectiveness of while-drilling VSP seismic technology in improving drilling success rate, reducing costs and increasing efficiency.
  • an amplitude factor preservation technology was established to perform post-stack frequency-boosting modification processing, which can effectively improve the signal-to-noise ratio and resolution of the target layer.
  • VSP seismic technology while drilling is not only applicable to various lithologic oil and gas reservoirs such as carbonate and clastic rocks, but also to structural oil and gas reservoirs such as complex pasmont structural belts and complex fault zones. It is also applicable to key exploration wells and evaluation wells in the exploration stage, and development wells in the development stage. It has unique advantages in fine structural identification, improving exploration and development efficiency, and reducing exploration costs, and has very broad prospects and potential for promotion and application.
  • the present invention also provides a while-drilling VSP well-driving seismic imaging device, as described in the following embodiments. Since the principle of solving the problem by the device is similar to that of the while-drilling VSP well-driving seismic imaging method, the implementation of the device can refer to the implementation of the while-drilling VSP well-driving seismic imaging method, and the repeated parts will not be repeated.
  • FIG12 is a schematic diagram of a VSP well driving seismic imaging device while drilling according to an embodiment of the present invention, comprising:
  • the data acquisition module 1201 is used to obtain the seismic data processing results and well logging data within the processing area corresponding to the target well;
  • the optimization and adjustment module 1202 is used to optimize and adjust the seismic data processing results and the logging data to obtain an anisotropic parameter volume of pre-stack depth migration;
  • a VSP drive correction module 1203 is used to update the seismic velocity of the target well with the VSP velocity as a constraint to obtain an updated anisotropic velocity body;
  • Iterative optimization module 1204 for iteratively optimizing the seismic velocity field after VSP drive correction based on the anisotropic parameter volume, and obtaining the iteratively optimized seismic velocity field and anisotropic parameter field;
  • the post-stack frequency-boosting modification processing module 1206 is used to perform post-stack frequency-boosting modification processing on the migration result to obtain the migration result after the post-stack frequency-boosting modification processing;
  • the imaging position determination module 1207 is used to determine the maximum probability imaging position of the target well in the target reservoir according to the migration result after the post-stack frequency enhancement modification processing.
  • the apparatus further includes a processing work area range determination module 1208, which is used to:
  • the scope of the VSP well-driving seismic imaging processing while drilling is determined according to the changes in the geological structure around the target well, and the scope of the processing area corresponding to the target well is determined.
  • the seismic data processing results include one or any combination of CMP gather processing results, prestack time migration results, prestack depth migration results, prestack depth migration velocity body, prestack depth migration anisotropic parameter body results, prestack depth migration isotropic parameter body results, and prestack depth migration structural parameter body results;
  • the logging data includes one or any combination of wellhead information, well trajectory information, and well layer information of the well being drilled and surrounding wells.
  • the apparatus further includes a reliability analysis module 1209, which is used to:
  • the noise that affects profile imaging includes one or any combination of abnormal amplitude, multiple waves, offset arcing, and oblique interference.
  • the pre-stack depth migration velocity body is determined to be reliable.
  • the reliability analysis module is specifically used for:
  • the anisotropic parameter volume results of pre-stack depth migration are reliable, the anisotropic parameter volume results of pre-stack depth migration are optimized;
  • the anisotropic parameter volume result of prestack depth migration is unreliable and the isotropic parameter volume result of prestack depth migration is reliable
  • the isotropic parameter volume result of prestack depth migration is optimized, the anisotropic field of prestack depth migration is re-established, and the anisotropic depth migration of prestack depth migration is performed;
  • the optimization and adjustment module is specifically used to:
  • a first velocity model is obtained based on the seismic data processing results, and a second velocity model is obtained based on the seismic data processing results and current well logging data;
  • the VSP drive correction module is specifically used for:
  • the vertical seismic velocity above the bottom of the target well is updated with the VSP velocity as a constraint to obtain an updated anisotropic velocity body
  • the seismic velocity below the bottom of the target well is updated with the VSP velocity of the surrounding wells of the target well as a constraint, and the updated seismic velocity below the bottom of the well is spliced with the updated anisotropic velocity body to form an updated well point velocity;
  • the updated wellpoint velocity is laterally interpolated and extrapolated based on the geosteering constraint to obtain the seismic velocity field after VSP drive correction.
  • the VSP drive correction module is specifically used for:
  • a new anisotropic velocity volume is obtained by using the scale factor data volume.
  • the VSP drive correction module is specifically used for:
  • the VSP velocity of the surrounding wells of the target well is taken as the reference velocity
  • the blind zone length of the reference velocity is stretched or compressed to be consistent with the VSP velocity length of the target well;
  • the updated below-bottom-hole seismic velocity is spliced with the updated anisotropic velocity volume to form an updated wellpoint velocity.
  • the iterative optimization module is specifically used to:
  • an initial anisotropic parameter field is established
  • the seismic velocity field and the initial anisotropic parameter field after VSP drive correction are updated through grid tomography iteration to obtain iteratively optimized seismic velocity field and anisotropic parameter field;
  • the iterative optimization module is specifically used to:
  • a small-scale grid model of the igneous rock section is established based on the initial anisotropic parameter field using high-resolution grid tomography to characterize the igneous rock velocity and perform iterative updates;
  • the method combining layer control and velocity scanning is used to iteratively update the blind zone velocity from the VSP bottom to the target point in the seismic velocity field after VSP drive correction.
  • the post-stack frequency boosting modification processing module is specifically used for:
  • the amplitude factor preservation technique is used to perform post-stack frequency enhancement modification on the migration results.
  • the imaging position determination module is specifically used for:
  • the lateral relative relationship of the peripheral velocity of the target body in the migration result is kept unchanged, and percentage scanning is performed, and imaging is performed respectively to obtain a second imaging result;
  • the current position of the target body's peripheral velocity in the migration result remains unchanged, and a lateral relative relationship scan is performed, and imaging is performed respectively to obtain a third imaging result;
  • the maximum probability imaging position of the target reservoir is selected based on the mapping results.
  • the device proposed in the embodiment of the present invention achieves the following beneficial effects:
  • While-drilling VSP well-drive seismic imaging methods greatly improves the timeliness and accuracy of ground seismic imaging and reduces the implementation cost of while-drilling VSP seismic technology. It plays an important role in giving full play to the effectiveness of while-drilling VSP seismic technology in improving drilling success rate, reducing costs and increasing efficiency.
  • an amplitude factor preservation technology was established to perform post-stack frequency-boosting modification processing, which can effectively improve the signal-to-noise ratio and resolution of the target layer.
  • FIG13 is a schematic diagram of a computer device in an embodiment of the present invention.
  • the computer device 1300 includes a memory 1310, a processor 1320, and a computer program 1330 stored in the memory 1310 and executable on the processor 1320.
  • the processor 1320 executes the computer program 1330, the above-mentioned VSP well drive seismic imaging method while drilling is implemented.
  • An embodiment of the present invention further provides a computer-readable storage medium, wherein the computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, the above-mentioned VSP well driving seismic imaging method while drilling is implemented.
  • An embodiment of the present invention further provides a computer program product, which includes a computer program.
  • a computer program product which includes a computer program.
  • embodiments of the present invention may be provided as methods, systems, or computer program products. Therefore, the present invention may take the form of a complete hardware embodiment, a complete software embodiment, or an embodiment combining software and hardware. Moreover, the present invention may take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.
  • computer-usable storage media including but not limited to disk storage, CD-ROM, optical storage, etc.
  • each process and/or box in the flowchart and/or block diagram, as well as the combination of the process and/or box in the flowchart and/or block diagram can be implemented by computer program instructions.
  • These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device produce a device for implementing the functions specified in one or more processes in the flowchart and/or one or more boxes in the block diagram.
  • These computer program instructions may also be stored in a computer readable memory that can direct a computer or other programmable data processing device to work in a specific manner, so that the instructions stored in the computer readable memory produce instructions including An article of manufacture of a device, which instructs the device to implement the functions specified in one or more processes in the flowchart and/or one or more blocks in the block diagram.
  • These computer program instructions may also be loaded onto a computer or other programmable data processing device so that a series of operational steps are executed on the computer or other programmable device to produce a computer-implemented process, whereby the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one or more processes in the flowchart and/or one or more boxes in the block diagram.

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Abstract

一种随钻VSP井驱地震成像方法，包括：获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；对地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；以VSP速度为约束对目标井的地震速度进行更新；基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；进行叠前深度偏移体偏移，获得偏移成果；对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置，可以实现随钻VSP井驱地震成像，时效性强。还提供一种随钻VSP井驱地震成像装置、计算机设备、计算机可读存储介质和计算机程序产品。

Description

随钻VSP井驱地震成像方法及装置
本申请要求2022年9月30日递交的申请号为202211216892.X、发明名称为“随钻VSP井驱地震成像方法及装置”的中国专利申请的优先权，其全部内容通过引用结合在本申请中。
技术领域
本发明涉及地震随钻技术领域，尤其涉及一种随钻VSP井驱地震成像方法及装置。
背景技术
本部分旨在为权利要求书中陈述的本发明实施例提供背景或上下文。此处的描述不因为包括在本部分中就承认是现有技术。
石油钻井是一项高投入、高风险的地下工程，在钻井作业实施时对地下情况的认识是模糊的，这给钻井作业带来了极大的风险。因此，探测未钻地层的各种参数与储层、断裂位置的勘探技术是极为重要的。
随钻地震技术最早是一种用钻井钻头作为震源信号，在钻井过程中实时接收人工地震信息，以探测地下地质情况的方法。但是这种测量方法由于对钻头工艺要求很高，一直未能取得期望的应用效果。随钻VSP(Vertical Seismic Profiling，垂直地震剖面法)技术是将震源移到地面，井下钻具上安装检波器接收地面震源释放的能量。该技术巧妙地回避了钻头问题，但又保持了实时测量且不损失钻井时间等优点，但是这种测量方式需要用到专业的井下钻具，成本高昂，且在测量过程中对于仪器稳定性要求很高，不利于规模化推广应用。后续，开展了随钻VSP(垂直地震剖面法)地震技术先导试验，为了回避高昂的仪器成本，在钻进至目的层前采用常规零井源距VSP获取最新的地下地质信息，然后用常规地面地震资料预测未钻地层的各种参数与储层位置。这种方法一般被称为随钻VSP井驱地震技术，优点很好地利用了地面地震资料信息，实现了对目标体精确定位。另外，这种技术大幅度降低了采集成本，利于规模化应用。
单独的随钻资料仅能得到井点附近的信息，从目前的试验中可以发现，将地面地震资料与随钻资料相结合，共同预测未钻地层，可以得到更精确的结果。但是，钻井是一 项对时效性要求很高的工程，地面地震成像往往是很耗时的，这就相当于变相增加了勘探成本。
因此，目前缺乏一种高效的随钻VSP井驱地震成像方案。
发明内容
本发明实施例提供一种随钻VSP井驱地震成像方法，用以实现随钻VSP井驱地震成像，时效性强，精度高，该方法包括：
获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；
对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；
基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；
利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；
根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。
本发明实施例还提供一种随钻VSP井驱地震成像装置，用以实现随钻VSP井驱地震成像，时效性强，精度高，该装置包括：
资料获得模块，用于获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；
优化调整模块，用于对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
VSP驱动校正模块，用于以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；
迭代优化模块，用于基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；
偏移模块，用于利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
叠后提频修饰处理模块，用于对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；
成像位置确定模块，用于根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。
本发明实施例还提供一种计算机设备，包括存储器、处理器及存储在存储器上并可在处理器上运行的计算机程序，所述处理器执行所述计算机程序时实现上述随钻VSP井驱地震成像方法。
本发明实施例还提供一种计算机可读存储介质，所述计算机可读存储介质存储有计算机程序，所述计算机程序被处理器执行时实现上述随钻VSP井驱地震成像方法。
本发明实施例还提供一种计算机程序产品，所述计算机程序产品包括计算机程序，所述计算机程序被处理器执行时实现上述随钻VSP井驱地震成像方法。
本发明实施例中，获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。与现有技术中将地面地震资料与随钻资料相结合的技术方案相比，通过以VSP速度为约束，获得VSP驱动校正后的速度，基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置，大大提高了地面地震成像的时效和精度，降低了随钻VSP地震技术的实施成本，对于随钻VSP地震技术充分发挥提高钻井成功率，降本增效的效用具有重要的作用。
附图说明
为了更清楚地说明本发明实施例或现有技术中的技术方案，下面将对实施例或现有技术描述中所需要使用的附图作简单地介绍，显而易见地，下面描述中的附图仅仅是本 发明的一些实施例，对于本领域普通技术人员来讲，在不付出创造性劳动的前提下，还可以根据这些附图获得其他的附图。在附图中：
图1为本发明实施例中随钻VSP井驱地震成像方法的流程图；
图2为本发明实施例中随钻VSP井驱地震成像处理的资料收集范围平面示意图；
图3为本发明实施例中根据进行地震资料处理成果的检查的原理示意图；
图4为本发明实例中对地震资料处理成果进行优化调整前后成像示意图；
图5为本发明实例中VSP驱动前后的地震速度示意图；
图6为本发明实例中采用横向插值外推方法对更新的井点速度进行横向插值外推前后对比示意图；
图7为本发明实例中采用本发明方法建立的各向异性参数场中Delta值与地震资料处理成果中Delta值对比示意图；
图8为本发明实例中采用本发明提供的网格层析迭代方法对各向异性参数Epsilon更新前后对比示意图；
图9为本发明实例中采用本发明提供的特殊属性体速度更新迭代方法对火成岩速度进行更新前后对比示意图；
图10为本发明实例中采用Kirchhoff积分法对叠前深度偏移体偏成果进行处理前后对比示意图；
图11为本发明实例中采用靶点位置定量分析方法对目标储层成像位置进行分析示意图；
图12为本发明实施例中随钻VSP井驱地震成像装置的示意图；
图13为本发明实施例中计算机设备的示意图。
具体实施方式
为使本发明实施例的目的、技术方案和优点更加清楚明白，下面结合附图对本发明实施例做进一步详细说明。在此，本发明的示意性实施例及其说明用于解释本发明，但并不作为对本发明的限定。
图1为本发明实施例中随钻VSP井驱地震成像方法的流程图，包括：
步骤101，获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；
步骤102，对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
步骤103，以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；
步骤104，基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；
步骤105，利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
步骤106，对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；
步骤107，根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。
本发明实施例提出的方法与现有技术中将地面地震资料与随钻资料相结合的技术方案相比，通过以VSP速度为约束，获得VSP驱动校正后的速度，基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置，大大提高了地面地震成像的时效和精度，降低了随钻VSP地震技术的实施成本，对于随钻VSP地震技术充分发挥提高钻井成功率，降本增效的效用具有重要的作用。
也就是，本发明实施例中，利用VSP速度(随钻VSP(垂直地震剖面)获得的精确深度、速度信息)作为先验信息，驱动地震资料处理成果实现快速、精确成像，以确定目标井在目标储层最大概率成像位置，属于石油天然气勘探领域中在钻井过程中实时对地震资料进行处理解释，从而优化钻井靶点的方法，适用于石油地球物理勘探钻井过程中靶点优化调整阶段。
具体实施时，根据目标井周围地质构造变化确定随钻VSP井驱地震成像处理的范围，确定目标井对应的处理工区范围；然后，获得目标井对应的处理工区范围内的地震资料处理成果和测井资料。
在一实施例中，所述地震资料处理成果包括CMP道集处理成果、叠前时间偏移成果、叠前深度偏移成果、叠前深度偏移速度体、叠前深度偏移各向异性参数体成果、叠前深度偏移各向同性参数体成果、叠前深度偏移构造参数体成果中的其中之一或任意组合；
所述测井资料包括正钻井以及周边井的井头信息、井轨迹信息、井分层信息中的其中之一或任意组合。
需要指出的是，测井资料要获得当前最新的。
在一实施例中，在获得目标井对应的处理工区范围内的地震资料处理成果和测井资料之后，还包括：
检查CMP道集处理成果是否存在影响剖面成像的噪音，若否，确定CMP道集处理成果可靠，所述影响剖面成像的噪音包括异常振幅、多次波、偏移划弧、斜干扰中的其中一种或任意组合；
检查叠前深度偏移速度体，在叠前深度偏移速度体的速度拾取点合理、道集的动校拉平、速度剖面横向变化符合地质和地球物理学规律时，确定叠前深度偏移速度体可靠；
通过偏移剖面的频谱、振幅、相干切片、井周围目标线用收集到的CMP与偏移速度的验证性偏移(也就是，还原第一现场，对比偏移结果，判断收集资料的可靠性)，检查叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果的可靠性，获得可靠性检查结果，并根据可靠性检查结果，对叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果进行优化处理。
在上述步骤中，根据不同的资料检查结果，选择可靠的基础资料进行前期优化处理，以更加符合VSP驱动处理的资料要求。
在一实施例中，根据可靠性检查结果，对叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果进行优化处理，包括：
在叠前深度偏移各向异性参数体成果可靠时，对叠前深度偏移各向异性参数体成果进行优化处理；
在叠前深度偏移各向异性参数体成果不可靠，且叠前深度偏移各向同性参数体成果可靠时，对叠前深度偏移各向同性参数体成果进行优化处理，重新建立叠前深度偏移各向异性场，进行叠前深度偏移各向异性深度偏移；
若叠前深度偏移各向同性参数体成果仍然不可靠，评价叠前时间偏移成果，重新进行叠前深度偏移处理，重复执行以上步骤，直至获得可靠的叠前深度偏移各向同性参数体成果。
在步骤102中，对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
由于地震速度存在多解性，利用地震资料得到的速度模型并不是唯一的。在油田的滚动开发过程中，可以不断获得新的测井资料和地质认识，这些资料与认识可能与地震资料处理时有所差异，需要以新的地质认识为导向，综合参考地震层位与地质层位，建立与新钻井信息相符合的新速度模型。
前期地面地震处理虽然不能提供精确的速度模型，但可以提供相对准确的成像速度信息，也就是说前期地震速度是真实速度的等效模型，因此速度更新可以省去重新叠前深度偏移的时间，根据新的速度模型(第二速度模型)与前期地震处理的速度模型(第一速度模型)的差异，采用基于射线追踪的剩余走时层析技术修正速度以及各向异性参数模型。基于射线追踪的剩余走时层析成像，或者说保时层析成像，主要是求解一系列大型超定方程组，这些线性方程可以看作是一组线性约束。在保时层析成像中有两种类型的线性约束：(a)设定每一对追踪射线为零旅行时误差；(b)将模型误差设定为任一层深度和各向异性速度参数误差。解这个线性方程组可以得到一个同时满足两种类型的约束的各向异性参数模型，包含地震速度、Thomsen参数及每一层的深度。
综合上述过程，对所述地震资料处理成果和测井资料，进行优化调整的步骤包括：
基于地震资料处理成果获得第一速度模型，并基于地震资料处理成果和当前的测井资料获得第二速度模型；
获得第一速度模型与第二速度模型每一地层的深度误差；
基于每一地层的深度误差，建立保时层析线性方程组；
解保时层析线性方程组得到优化的叠前深度偏移的各向异性参数体。
上述优化调整后地震速度及各向异性参数场直接用来做各向异性叠前深度偏移，目标偏移成像收敛程度与原各向异性叠前深度偏移成果相当，但是优化调整后各标志层位的成像深度与新测井信息对应更好。
在步骤103中，以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体，具体步骤包括：
(1)以VSP速度为约束对目标井的井底以上垂向地震速度进行更新，获得更新的各向异性速度体；
首先对垂向地震速度的初始速度进行平滑，消除层速度间变化过大对偏移产生的影响，得到校正后的目标井底以上垂向地震速度，通过平滑前后垂向地震速度对比分析，发现还存在一定差异性，将两个垂向地震速度进行运算求取比例因子，并将比例因子应 用，产生新的VSP偏移地震速度场，即新的各向异性速度体，这种方法可以实现井旁地震速度与VSP速度的高效吻合，吻合率达到95％以上。
具体实现步骤如下：
A、求取校正后的目标井底以上垂向地震速度与井旁地震速度的比例因子；
B、用VSP速度为约束进行比例因子的插值与外推获得比例因子数据体；
C、通过比例因子数据体获得新的各向异性速度体。
(2)以目标井的周边井的VSP速度为约束对目标井的井底以下地震速度进行更新，将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新的井点速度；
VSP测井采集深度有限，VSP井底以下至目标靶点间存在速度盲区，为了提高VSP井底以下地震速度精度，减少深度误差，应参考周边井的VSP速度或声波速度作为参考速度对速度进行校正。
具体实现步骤如下：
A、将目标井的周边井的VSP速度或声波速度作为参考速度；
B、将参考速度的盲区长度拉伸或压缩至与目标井的VSP速度长度一致，也就是改变采样间隔；
C、将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新后的井点速度。
(3)以地质导向为约束对更新的井点速度进行横向插值外推，获得VSP驱动校正后的地震速度场。
以VSP速度为约束对目标井的井底以上垂向地震速度进行更新，以及以目标井的周边井的VSP速度为约束对目标井的井底以下地震速度进行更新，可以准确保证井点速度的纵向精度，井点速度横向变化可以通过地质层位约束的空间插值和外推，把VSP速度推展到速度建模的范围，提高整个工区速度精度。
具体实现步骤如下：
A、首先将井点处比例因子进行插值外推，形成比例因子数据体；
常规的插值方法都需要准确的地震层位进行约束，而地震层位的拾取是一项耗时费力的工作，为了提高插值效率，本发明采用地震导向速度插值技术进行插值外推，这种技术无需地震层位，采用地震成像数据体的相干振幅趋势进行横向约束，不仅提高了效率，而且对于难以用解释准确获得地震层位的数据更为适用，避免了地震层位解释带来的误差。
B、对收集到的原始地震速度进行平滑；
C、根据比例因子数据体应用于平滑后的地震速度，获得VSP驱动校正后的地震速度场。
在步骤104中，基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；利用VSP速度驱动对地震速度重新建模后，速度误差减小，更符合地下实际地质情况，但是该地震速度是垂向地震速度，需要和对应的各向异性参数体结合才能得到地震成像速度。
在一实施例中，基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场，包括：
(1)基于各向异性参数体，建立初始各向异性参数场；
前述已经得到了各向异性参数体，但是当道集信噪比比较低时，通过网格层析不能实现对各向异性参数体的快速更新，得到相对准确的地震成像，这里考虑对初始Delta参数场进行数学运算得到与VSP驱动速度更为匹配的各向异性参数，这样快速实现目标串珠的准确成像，降低网格层析及层控网格层析的迭代次数。运算公式为：
式中，δold为初始Delta参数场，δnew为更新后Delta参数场，vold为初始速度场，vnew为上一步骤更新后的速度场，为VSP驱动速度比例因子。
(2)对VSP驱动校正后的地震速度场与初始各向异性参数场，通过网格层析迭代进行更新，获得迭代优化的地震速度场和各向异性参数场，具体步骤包括：
A、对VSP驱动校正后的地震速度场中井底以上地震速度，保持不变；
这是因为经过了VSP驱动地震速度校正，VSP井底以上地震速度已经相对准确，因此对于VSP井底以上，在迭代过程中保持地震速度相对不变，通过迭代各向异性参数将每个深度偏移CRP道集的每个较强同相轴拉平，得到更准确的叠前深度偏移成像；根据弱各向异性的假设，取值范围一般在-0.2～0.2之间，且在同一地层中较为稳定，一般1轮迭代就能得到相对准确的浅层成像，满足VSP驱动处理对时效性的要求。
B、若工区处理范围内存在预设类型属性体，基于初始各向异性参数场，采用高分辨率网格层析，建立起火成岩段小尺度网格模型，对火成岩速度进行刻画，进行迭代更新；
在这种情况下，预设类型属性体可以是火成岩等特殊岩性体，对这种特殊岩性体进行小网格迭代，以消除火成岩速度对下伏地层构造和成像的影响。VSP速度对于火成岩速度有很好的反映，但是火成岩速度横向变化快，稀疏的井资料并不能完全控制火成岩速度的变化，需要进行高分辨率网格层析，建立起火成岩段小尺度网格模型，对火成岩速度进行更好的刻画；
C、对VSP驱动校正后的地震速度场中VSP井底至靶点盲区的地震速度开展层控与速度扫描结合的方法进行迭代更新。
VSP井底至靶点盲区通常存在一套横向连续性较好的标志层，利用周边井以及速度模型可以很好的控制标志层以上横向速度趋势，这时只需要对标志层进行沿层层析实现对速度场的迭代更新。对于标志层以下速度，采用速度扫描方法，确保目标靶点成像精度。
若VSP井底至靶点盲区不存在标志层，或周边井较少无法控制标志层以上横向速度趋势，则需要采用沿层层析方法自浅至深逐层更新VSP井底以上速度，避免曾速度和反射面几何形态误差累计，提高速度横向精度。然后对VSP井底以下的盲区速度进行速度扫描，确保目标靶点成像精度。
各向异性参数场包括速度、delta、epsilon、dip、azimuth等。
在步骤105中，利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
近几年，基于波动方程的偏移方法得到了长足的发展，逆时偏移可以对波传播的任何方向进行成像，包括回折波和多次波成像，能够处理多路径问题，能够对倾覆构造成像，是双程波动方程偏移的典型方法，也是精度最高的偏移算法。但是VSP驱动处理不仅要考虑精度还要考虑时效性，在本发明实施例中，采用Kirchhoff积分法进行叠前深度偏移体偏移。Kirchhoff积分法叠前深度偏移被认为是一种高效实用的叠前深度偏移方法，它具有高偏移角度、无频散、占用资源少和实现效率高的特点，并且积分法能够适应变化的观测系统和起伏的地表。因此，Kirchhoff积分法是目前最适合VSP驱动处理的偏移方法。
在步骤106中，对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果，目前勘探目标大多成像信噪比较低，一般存在较重的伴随相位，导致储层成像难以辨别，需要进行适当的叠后处理。保幅性好的叠后处理方法通常是在叠前道集上进行，耗时较久，不能满足VSP驱动处理对于时效性的要求，需要在叠后剖面上探索快速 且保幅性好的提频修饰方法。在叠后剖面上提高地震资料的分辨率，补偿地下介质衰减性造成的地震波能量损失的方法主要有反Q滤波方法、时频分析吸收补偿等方法，但是这些方法的保幅性较差。为了解决保真性和时效性的问题，本发明实施例提出采用振幅因子保持技术对偏移成果进行叠后提频修饰处理。
振幅因子保持技术的实现步骤为：
A、从偏移成果的直接偏移剖面上提取振幅因子，此振幅因子保留了剖面的相对振幅关系，保幅性较好；
B、对于叠后偏移数据进行反Q滤波等提频修饰处理，得到提频后的叠后数据体；
C、将振幅因子还原到前一步骤得到的提频后的叠后数据体上，以保障数据保留直接偏移剖面的相对振幅关系。
采用振幅因子保持技术确保数据保幅性，在此基础上利用反Q滤波等方法提高目的层信噪比与分辨率，使目标成像得到较大的改善。
在步骤107中，根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。这一过程为靶点定量分析，其原理是对目标储层进行局部速度扫描，分析不同扫描结果目标储层成像位置进行定量化分析，最终确定目标储层最大概率成像位置。
在一实施例中，根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置，包括：
对偏移成果中目标体周边速度进行常速填充，然后分别进行成像，获得第一成像结果；
对偏移成果中目标体周边速度保持横向相对关系不变，进行百分比扫描(通常范围为90％-110％，间隔为1％)，分别进行成像，获得第二成像结果；
对偏移成果中目标体周边速度当前位置不变，进行横向相对关系扫描，分别进行成像，获得第三成像结果；本步骤扫描中，通常分四种情况：主测线方向正向速度变大、主测线方向反向速度变大、垂直主测线方向正向速度变大、垂直主测线方向反向速度变大，然后分别进行成像；
对第一成像结果、第二成像结果、第三成像结果进行绘图，通常有四种绘图方式：能量分布、最大能量位置分布、最大能量亮度分布；
根据绘图结果选择目标储层最大概率成像位置。
最后，可将最新的目标储层最大概率成像位置提供给钻井人员，及时进行井轨迹的调整，确保钻井钻遇目标储层，达到提高钻井成功率的目的。
下面给出一个具体实施例。实例中的地震数据来自某油田区块A，依据前期完成的地面地震处理成果解释成果，某年在本区钻探风险井位一口M1，钻探过程中发现实际层位与预测层位相差达100米，依据原钻井轨迹很难钻探到既定目标储层，因此在四开中完时，对本井进行VSP测井，现场停钻等待新的地震资料处理成果，制定新的钻井轨迹调整方案。按照现有的处理技术，即使加急处理，地震资料处理成果的重新处理预估在十天以上，停钻时间预估超过半个月，将带来巨大的经济损失，但是应用本发明实施例提出的方法后，将处理时间压缩到68小时，停钻时间压缩到3天，节约了大量的时间与人力、物力成本，最终本井顺利钻遇储层，试油高产。
本实施例具体按照如下步骤实现：
1、本工区地处沙漠区，浅表地层横向变化较小，速度具有很强的相关性，在原工区中选择井周围256平方公里建立工区处理范围，图2为本发明实施例中随钻VSP井驱地震成像处理的资料收集范围平面示意图。
2、收集处理范围内的某年的地面地震资料及附近3口已钻井的测井资料；
3、采用本发明提供的方法进行地震资料处理成果的检查，最后选择叠前深度偏移速度体、叠前深度偏移各向异性参数体成果作为可靠的地震资料处理成果；图3为本发明实施例中根据进行地震资料处理成果的检查的原理示意图。其中，在各向异性深度偏移成果可靠时，直接对各向异性深度偏移成果进行优化处理，包括通过地质、测井新认识，获得各向异性速度模型，再通过网络层析后进行VSP驱动处理。在各向异性深度偏移成果不可靠时，进行井震误差统计，保时层析，获得初始各向异性参数体，然后进行网络层析，获得各向异性深度偏移，获得各向异性深度偏移成果后，再按照上述步骤判断各向异性深度偏移成果是否有效。在各向同性深度偏移成果不可靠时，将时间域成果(即叠前时间偏移成果)进行处理，直至得到各向同性深度偏移成果，再判断各向同性深度偏移成果是否可靠。图4为本发明实例中对地震资料处理成果进行优化调整前后成像示意图(左侧为优化调整前，右侧为优化调整后)，可见，经过优化调整后，成像效果更好。
4、建立第一速度模型和第二速度模型，建立保时层析线性方程组，并解析，得到叠前深度偏移的各向异性参数体；
5、以四开中完VSP测井资料处理得到的最新VSP速度、深度为约束对当前井点垂向地震速度进行更新，获得更新的各向异性速度体；图5为本发明实例中VSP驱动前后的地震速度示意图(左侧为VSP驱动前，右侧为VSP驱动后)，可见，VSP驱动后地震速度更加精确。
6、以3口已钻井VSP速度为约束对当前井的井底以下地震速度进行更新，将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新的井点速度；
7、以地质导向为约束对更新的井点速度进行横向插值外推，获得VSP驱动校正后的地震速度场，图6为本发明实例中采用横向插值外推方法对更新的井点速度进行横向插值外推前后对比示意图(左侧为横向插值外推前，右侧为横向插值外推后)。
8、基于各向异性参数体，建立初始各向异性参数场；图7为本发明实例中采用本发明方法建立的各向异性参数场中Delta值与地震资料处理成果中Delta值对比示意图(左侧为采用本发明方法建立的各向异性参数场中Delta值，右侧为地震资料处理成果中Delta值)；
9、对VSP驱动校正后的地震速度场与初始各向异性参数场，通过网格层析迭代进行更新，获得迭代优化的地震速度场和各向异性参数场，其中，本工区二叠系存在一套横向变化剧烈的火成岩，采用高分辨率网格层析，建立起火成岩段小尺度网格模型，对火成岩速度进行刻画；其中，VSP井底至靶点盲区的地震速度开展层控与速度扫描结合的方法进行迭代；图8为本发明实例中采用本发明提供的网格层析迭代方法对各向异性参数Epsilon更新前后对比示意图(左侧为更新前，右侧为更新后)。图9为本发明实例中采用本发明提供的特殊属性体速度更新迭代方法对火成岩速度进行更新前后对比示意图(左侧为更新前，右侧为更新后)。
10、利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；图10为本发明实例中采用Kirchhoff积分法对叠前深度偏移体偏成果进行处理前后对比示意图(左侧为处理前，右侧为处理后)。
11、采用振幅因子保持技术对偏移成果进行叠后提频修饰处理；
12、采用靶点位置定量分析方法确定目标井在目标储层最大概率成像位置；图11为本发明实例中采用靶点位置定量分析方法对目标储层成像位置进行分析示意图。
13、将最新的目标储层最大概率成像位置提供给钻井人员，及时进行井轨迹的调整，确保钻井钻遇目标储层，达到提高钻井成功率的目的。
综上所述，本发明实施例提出的方法达到了以下有益效果：
第一，提供了一套高效的随钻VSP井驱地震成像方法，大大提高了地面地震成像的时效和精度，降低了随钻VSP地震技术的实施成本，对于随钻VSP地震技术充分发挥提高钻井成功率，降本增效的效用具有重要的作用。
第二，建立了一套地震资料处理成果和测井资料的评价体系，对收集到的地震资料处理成果和测井资料进行评价，可以有效、快速选择可靠的地震资料处理成果和测井资料，随钻VSP地震成像处理做好数据准备；
第三，建立了一种高效的随钻VSP地震速度建模方法，利用新的测井信息及VSP速度可以快速校正地震速度误差；
第四，建立了一种高效各向异性参数场求取方法，快速实现目标串珠的准确成像，降低网格层析及层控网格层析的迭代次数。
第五，建立了一种振幅因子保持技术来进行叠后提频修饰处理，可以有效提高目的层信噪比与分辨率。
第六，建立了一种目标靶点定量分析方法，对目标储层进行局部速度扫描，分析不同扫描结果目标储层成像位置进行定量化分析，最终确定目标储层最大概率成像位置。
实际资料应用表明，本发明实施例提出的方法可以有效指导井轨迹优化调整，其中多口井轨迹调整超过50米，大大降低钻井工程风险，按照塔里木平均1.1亿元/万米进尺的成本计算，预计节约6亿元投资。
随钻VSP地震技术不仅适用于各类碳酸盐岩、碎屑岩等岩性油气藏，也适用于山前复杂构造带、复杂断裂带等构造类油气藏；同时适用于勘探阶段的重点探井、评价井，开发阶段的开发井；在构造精细识别、提高勘探开发效率、降低勘探成本等方面具有独特优势，具有非常广阔的推广应用前景和潜力。
本发明实施例中还提供了一种随钻VSP井驱地震成像装置，如下面的实施例所述。由于该装置解决问题的原理与随钻VSP井驱地震成像方法相似，因此该装置的实施可以参见随钻VSP井驱地震成像方法的实施，重复之处不再赘述。
图12为本发明实施例中随钻VSP井驱地震成像装置的示意图，包括：
资料获得模块1201，用于获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；
优化调整模块1202，用于对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
VSP驱动校正模块1203，用于以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；
迭代优化模块1204，用于基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；
偏移模块1205，用于利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
叠后提频修饰处理模块1206，用于对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；
成像位置确定模块1207，用于根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。
在一实施例中，所述装置还包括处理工区范围确定模块1208，用于：
根据目标井周围地质构造变化确定随钻VSP井驱地震成像处理的范围，确定目标井对应的处理工区范围。
在一实施例中，所述地震资料处理成果包括CMP道集处理成果、叠前时间偏移成果、叠前深度偏移成果、叠前深度偏移速度体、叠前深度偏移各向异性参数体成果、叠前深度偏移各向同性参数体成果、叠前深度偏移构造参数体成果中的其中之一或任意组合；
所述测井资料包括正钻井以及周边井的井头信息、井轨迹信息、井分层信息中的其中之一或任意组合。
在一实施例中，所述装置还包括可靠性分析模块1209，用于：
在获得目标井对应的处理工区范围内的地震资料处理成果和测井资料之后，检查CMP道集处理成果是否存在影响剖面成像的噪音，若否，确定CMP道集处理成果可靠，所述影响剖面成像的噪音包括异常振幅、多次波、偏移划弧、斜干扰中的其中一种或任意组合；
检查叠前深度偏移速度体，在叠前深度偏移速度体的速度拾取点合理、道集的动校拉平、速度剖面横向变化符合地质和地球物理学规律时，确定叠前深度偏移速度体可靠；
通过偏移剖面的频谱、振幅、相干切片、井周围目标线用收集到的CMP与偏移速度的验证性偏移，检查叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数 体成果的可靠性，获得可靠性检查结果，并根据可靠性检查结果，对叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果进行优化处理。
在一实施例中，可靠性分析模块具体用于：
在叠前深度偏移各向异性参数体成果可靠时，对叠前深度偏移各向异性参数体成果进行优化处理；
在叠前深度偏移各向异性参数体成果不可靠，且叠前深度偏移各向同性参数体成果可靠时，对叠前深度偏移各向同性参数体成果进行优化处理，重新建立叠前深度偏移各向异性场，进行叠前深度偏移各向异性深度偏移；
若叠前深度偏移各向同性参数体成果仍然不可靠，评价叠前时间偏移成果，重新进行叠前深度偏移处理，重复执行以上步骤，直至获得可靠的叠前深度偏移各向同性参数体成果。
在一实施例中，优化调整模块具体用于：
基于地震资料处理成果获得第一速度模型，并基于地震资料处理成果和当前的测井资料获得第二速度模型；
获得第一速度模型与第二速度模型每一地层的深度误差；
基于每一地层的深度误差，建立保时层析线性方程组；
解保时层析线性方程组，得到叠前深度偏移的各向异性参数体。
在一实施例中，VSP驱动校正模块具体用于：
以VSP速度为约束对目标井的井底以上垂向地震速度进行更新，获得更新的各向异性速度体；
以目标井的周边井的VSP速度为约束对目标井的井底以下地震速度进行更新，将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新的井点速度；
以地质导向为约束对更新的井点速度进行横向插值外推，获得VSP驱动校正后的地震速度场。
在一实施例中，VSP驱动校正模块具体用于：
求取校正后的目标井底以上垂向地震速度与井旁地震速度的比例因子；
用VSP速度为约束进行比例因子的插值与外推获得比例因子数据体；
通过比例因子数据体获得新的各向异性速度体。
在一实施例中，VSP驱动校正模块具体用于：
将目标井的周边井的VSP速度为参考速度；
将参考速度的盲区长度拉伸或压缩至与目标井的VSP速度长度一致；
将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新后的井点速度。
在一实施例中，迭代优化模块具体用于：
基于各向异性参数体，建立初始各向异性参数场；
对VSP驱动校正后的地震速度场与初始各向异性参数场，通过网格层析迭代进行更新，获得迭代优化的地震速度场和各向异性参数场；
在一实施例中，迭代优化模块具体用于：
若工区处理范围内存在预设类型属性体，基于初始各向异性参数场，采用高分辨率网格层析，建立起火成岩段小尺度网格模型，对火成岩速度进行刻画，进行迭代更新；
对VSP驱动校正后的地震速度场中VSP井底至靶点盲区速度开展层控与速度扫描结合的方法进行迭代更新。
在一实施例中，叠后提频修饰处理模块具体用于：
采用振幅因子保持技术对偏移成果进行叠后提频修饰处理。
在一实施例中，成像位置确定模块具体用于：
对偏移成果中目标体周边速度进行常速填充，然后分别进行成像，获得第一成像结果；
对偏移成果中目标体周边速度保持横向相对关系不变，进行百分比扫描，分别进行成像，获得第二成像结果；
对偏移成果中目标体周边速度当前位置不变，进行横向相对关系扫描，分别进行成像，获得第三成像结果；
对第一成像结果、第二成像结果、第三成像结果进行绘图；
根据绘图结果选择目标储层最大概率成像位置。
综上所述，本发明实施例提出的装置达到了以下有益效果：
第一，提供了一套高效的随钻VSP井驱地震成像方法，大大提高了地面地震成像的时效和精度，降低了随钻VSP地震技术的实施成本，对于随钻VSP地震技术充分发挥提高钻井成功率，降本增效的效用具有重要的作用。
第二，建立了一套地震资料处理成果和测井资料的评价体系，对收集到的地震资料处理成果和测井资料进行评价，可以有效、快速选择可靠的地震资料处理成果和测井资料，随钻VSP地震成像处理做好数据准备；
第三，建立了一种高效的随钻VSP地震速度建模方法，利用新的测井信息及VSP速度可以快速校正地震速度误差；
第四，建立了一种高效各向异性参数场求取方法，快速实现目标串珠的准确成像，降低网格层析及层控网格层析的迭代次数。
第五，建立了一种振幅因子保持技术来进行叠后提频修饰处理，可以有效提高目的层信噪比与分辨率。
第六，建立了一种目标靶点定量分析方法，对目标储层进行局部速度扫描，分析不同扫描结果目标储层成像位置进行定量化分析，最终确定目标储层最大概率成像位置。
本发明实施例还提供一种计算机设备，图13为本发明实施例中计算机设备的示意图，所述计算机设备1300包括存储器1310、处理器1320及存储在存储器1310上并可在处理器1320上运行的计算机程序1330，所述处理器1320执行所述计算机程序1330时实现上述随钻VSP井驱地震成像方法。
本发明实施例还提供一种计算机可读存储介质，所述计算机可读存储介质存储有计算机程序，所述计算机程序被处理器执行时实现上述随钻VSP井驱地震成像方法。
本发明实施例还提供一种计算机程序产品，所述计算机程序产品包括计算机程序，所述计算机程序被处理器执行时实现上述随钻VSP井驱地震成像方法。
本领域内的技术人员应明白，本发明的实施例可提供为方法、系统、或计算机程序产品。因此，本发明可采用完全硬件实施例、完全软件实施例、或结合软件和硬件方面的实施例的形式。而且，本发明可采用在一个或多个其中包含有计算机可用程序代码的计算机可用存储介质(包括但不限于磁盘存储器、CD-ROM、光学存储器等)上实施的计算机程序产品的形式。
本发明是参照根据本发明实施例的方法、设备(系统)、和计算机程序产品的流程图和/或方框图来描述的。应理解可由计算机程序指令实现流程图和/或方框图中的每一流程和/或方框、以及流程图和/或方框图中的流程和/或方框的结合。可提供这些计算机程序指令到通用计算机、专用计算机、嵌入式处理机或其他可编程数据处理设备的处理器以产生一个机器，使得通过计算机或其他可编程数据处理设备的处理器执行的指令产生用于实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能的装置。
这些计算机程序指令也可存储在能引导计算机或其他可编程数据处理设备以特定方式工作的计算机可读存储器中，使得存储在该计算机可读存储器中的指令产生包括指令 装置的制造品，该指令装置实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能。
这些计算机程序指令也可装载到计算机或其他可编程数据处理设备上，使得在计算机或其他可编程设备上执行一系列操作步骤以产生计算机实现的处理，从而在计算机或其他可编程设备上执行的指令提供用于实现在流程图一个流程或多个流程和/或方框图一个方框或多个方框中指定的功能的步骤。
以上所述的具体实施例，对本发明的目的、技术方案和有益效果进行了进一步详细说明，所应理解的是，以上所述仅为本发明的具体实施例而已，并不用于限定本发明的保护范围，凡在本发明的精神和原则之内，所做的任何修改、等同替换、改进等，均应包含在本发明的保护范围之内。

Claims (29)

  1. 一种随钻VSP井驱地震成像方法，其特征在于，包括：
    获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；
    对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
    以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；
    基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；
    利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
    对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；
    根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。
  2. 如权利要求1所述的方法，其特征在于，还包括：
    根据目标井周围地质构造变化确定随钻VSP井驱地震成像处理的范围，确定目标井对应的处理工区范围。
  3. 如权利要求1所述的方法，其特征在于，所述地震资料处理成果包括CMP道集处理成果、叠前时间偏移成果、叠前深度偏移成果、叠前深度偏移速度体、叠前深度偏移各向异性参数体成果、叠前深度偏移各向同性参数体成果、叠前深度偏移构造参数体成果中的其中之一或任意组合；
    所述测井资料包括正钻井以及周边井的井头信息、井轨迹信息、井分层信息中的其中之一或任意组合。
  4. 如权利要求3所述的方法，其特征在于，在获得目标井对应的处理工区范围内的地震资料处理成果和测井资料之后，还包括：
    检查CMP道集处理成果是否存在影响剖面成像的噪音，若否，确定CMP道集处理成果可靠，所述影响剖面成像的噪音包括异常振幅、多次波、偏移划弧、斜干扰中的其中一种或任意组合；
    检查叠前深度偏移速度体，在叠前深度偏移速度体的速度拾取点合理、道集的动校拉平、速度剖面横向变化符合地质和地球物理学规律时，确定叠前深度偏移速度体可靠；
    通过偏移剖面的频谱、振幅、相干切片、井周围目标线用收集到的CMP与偏移速度的验证性偏移，检查叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果的可靠性，获得可靠性检查结果，并根据可靠性检查结果，对叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果进行优化处理。
  5. 如权利要求4所述的方法，其特征在于，根据可靠性检查结果，对叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果进行优化处理，包括：
    在叠前深度偏移各向异性参数体成果可靠时，对叠前深度偏移各向异性参数体成果进行优化处理；
    在叠前深度偏移各向异性参数体成果不可靠，且叠前深度偏移各向同性参数体成果可靠时，对叠前深度偏移各向同性参数体成果进行优化处理，重新建立叠前深度偏移各向异性场，进行叠前深度偏移各向异性深度偏移；
    若叠前深度偏移各向同性参数体成果仍然不可靠，评价叠前时间偏移成果，重新进行叠前深度偏移处理，重复执行以上步骤，直至获得可靠的叠前深度偏移各向同性参数体成果。
  6. 如权利要求1所述的方法，其特征在于，对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体，包括：
    基于地震资料处理成果获得第一速度模型，并基于地震资料处理成果和当前的测井资料获得第二速度模型；
    获得第一速度模型与第二速度模型每一地层的深度误差；
    基于每一地层的深度误差，建立保时层析线性方程组；
    解保时层析线性方程组，得到叠前深度偏移的各向异性参数体。
  7. 如权利要求1所述的方法，其特征在于，以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体，包括：
    以VSP速度为约束对目标井的井底以上垂向地震速度进行更新，获得更新的各向异性速度体；
    以目标井的周边井的VSP速度为约束对目标井的井底以下地震速度进行更新，将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新的井点速度；
    以地质导向为约束对更新的井点速度进行横向插值外推，获得VSP驱动校正后的地震速度场。
  8. 如权利要求1所述的方法，其特征在于，以VSP速度为约束对目标井底以上垂向地震速度进行更新，获得更新的各向异性速度体，包括：
    求取校正后的目标井底以上垂向地震速度与井旁地震速度的比例因子；
    用VSP速度为约束进行比例因子的插值与外推获得比例因子数据体；
    通过比例因子数据体获得新的各向异性速度体。
  9. 如权利要求8所述的方法，其特征在于，以目标井的周边井的VSP速度为约束对目标井的井底以下地震速度进行更新，将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新后的井点速度，包括：
    将目标井的周边井的VSP速度或声波速度作为参考速度；
    将参考速度的盲区长度拉伸或压缩至与目标井的VSP速度长度一致；
    将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新后的井点速度。
  10. 如权利要求1所述的方法，其特征在于，基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场，包括：
    基于各向异性参数体，建立初始各向异性参数场；
    对VSP驱动校正后的地震速度场与初始各向异性参数场，通过网格层析迭代进行更新，获得迭代优化的地震速度场和各向异性参数场。
  11. 如权利要求10所述的方法，其特征在于，对VSP驱动校正后的地震速度场与初始各向异性参数场，通过网格层析迭代进行更新，包括：
    对VSP驱动校正后的地震速度场中井底以上地震速度，保持不变；
    若工区处理范围内存在预设类型属性体，基于初始各向异性参数场，采用高分辨率网格层析，建立起火成岩段小尺度网格模型，对火成岩速度进行刻画，进行迭代更新；
    对VSP驱动校正后的地震速度场中VSP井底至靶点盲区的地震速度开展层控与速度扫描结合的方法进行迭代更新。
  12. 如权利要求1所述的方法，其特征在于，对偏移成果进行叠后提频修饰处理，包括：
    采用振幅因子保持技术对偏移成果进行叠后提频修饰处理。
  13. 如权利要求1所述的方法，其特征在于，根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置，包括：
    对偏移成果中目标体周边速度进行常速填充，然后分别进行成像，获得第一成像结果；
    对偏移成果中目标体周边速度保持横向相对关系不变，进行百分比扫描，分别进行成像，获得第二成像结果；
    对偏移成果中目标体周边速度当前位置不变，进行横向相对关系扫描，分别进行成像，获得第三成像结果；
    对第一成像结果、第二成像结果、第三成像结果进行绘图；
    根据绘图结果选择目标储层最大概率成像位置。
  14. 一种随钻VSP井驱地震成像装置，其特征在于，包括：
    资料获得模块，用于获得目标井对应的处理工区范围内的地震资料处理成果和测井资料；
    优化调整模块，用于对所述地震资料处理成果和测井资料，进行优化调整，获得叠前深度偏移的各向异性参数体；
    VSP驱动校正模块，用于以VSP速度为约束对目标井的地震速度进行更新，获得更新的各向异性速度体；
    迭代优化模块，用于基于各向异性参数体，对VSP驱动校正后的地震速度场进行迭代优化，获得迭代优化后的地震速度场及各向异性参数场；
    偏移模块，用于利用迭代优化的地震速度场及各向异性参数场，进行叠前深度偏移体偏移，获得偏移成果；
    叠后提频修饰处理模块，用于对偏移成果进行叠后提频修饰处理，获得叠后提频修饰处理后的偏移成果；
    成像位置确定模块，用于根据叠后提频修饰处理后的偏移成果，确定目标井在目标储层最大概率成像位置。
  15. 如权利要求14所述的装置，其特征在于，还包括处理工区范围确定模块，用于：
    根据目标井周围地质构造变化确定随钻VSP井驱地震成像处理的范围，确定目标井对应的处理工区范围。
  16. 如权利要求14所述的装置，其特征在于，所述地震资料处理成果包括CMP道集处理成果、叠前时间偏移成果、叠前深度偏移成果、叠前深度偏移速度体、叠前深度 偏移各向异性参数体成果、叠前深度偏移各向同性参数体成果、叠前深度偏移构造参数体成果中的其中之一或任意组合；
    所述测井资料包括正钻井以及周边井的井头信息、井轨迹信息、井分层信息中的其中之一或任意组合。
  17. 如权利要求16所述的装置，其特征在于，还包括可靠性分析模块，用于：
    在获得目标井对应的处理工区范围内的地震资料处理成果和测井资料之后，检查CMP道集处理成果是否存在影响剖面成像的噪音，若否，确定CMP道集处理成果可靠，所述影响剖面成像的噪音包括异常振幅、多次波、偏移划弧、斜干扰中的其中一种或任意组合；
    检查叠前深度偏移速度体，在叠前深度偏移速度体的速度拾取点合理、道集的动校拉平、速度剖面横向变化符合地质和地球物理学规律时，确定叠前深度偏移速度体可靠；
    通过偏移剖面的频谱、振幅、相干切片、井周围目标线用收集到的CMP与偏移速度的验证性偏移，检查叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果的可靠性，获得可靠性检查结果，并根据可靠性检查结果，对叠前深度偏移各向异性参数体成果和叠前深度偏移各向同性参数体成果进行优化处理。
  18. 如权利要求17所述的装置，其特征在于，可靠性分析模块具体用于：
    在叠前深度偏移各向异性参数体成果可靠时，对叠前深度偏移各向异性参数体成果进行优化处理；
    在叠前深度偏移各向异性参数体成果不可靠，且叠前深度偏移各向同性参数体成果可靠时，对叠前深度偏移各向同性参数体成果进行优化处理，重新建立叠前深度偏移各向异性场，进行叠前深度偏移各向异性深度偏移；
    若叠前深度偏移各向同性参数体成果仍然不可靠，评价叠前时间偏移成果，重新进行叠前深度偏移处理，重复执行以上步骤，直至获得可靠的叠前深度偏移各向同性参数体成果。
  19. 如权利要求14所述的装置，其特征在于，优化调整模块具体用于：
    基于地震资料处理成果获得第一速度模型，并基于地震资料处理成果和当前的测井资料获得第二速度模型；
    获得第一速度模型与第二速度模型每一地层的深度误差；
    基于每一地层的深度误差，建立保时层析线性方程组；
    解保时层析线性方程组，得到叠前深度偏移的各向异性参数体。
  20. 如权利要求14所述的装置，其特征在于，VSP驱动校正模块具体用于：
    以VSP速度为约束对目标井的井底以上垂向地震速度进行更新，获得更新的各向异性速度体；
    以目标井的周边井的VSP速度为约束对目标井的井底以下地震速度进行更新，将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新的井点速度；
    以地质导向为约束对更新的井点速度进行横向插值外推，获得VSP驱动校正后的地震速度场。
  21. 如权利要求14所述的装置，其特征在于，VSP驱动校正模块具体用于：
    求取校正后的目标井底以上垂向地震速度与井旁地震速度的比例因子；
    用VSP速度为约束进行比例因子的插值与外推获得比例因子数据体；
    通过比例因子数据体获得新的各向异性速度体。
  22. 如权利要求21所述的装置，其特征在于，VSP驱动校正模块具体用于：
    将目标井的周边井的VSP速度为参考速度；
    将参考速度的盲区长度拉伸或压缩至与目标井的VSP速度长度一致；
    将更新的井底以下地震速度与更新的各向异性速度体拼接形成更新后的井点速度。
  23. 如权利要求14所述的装置，其特征在于，迭代优化模块具体用于：
    基于各向异性参数体，建立初始各向异性参数场；
    对VSP驱动校正后的地震速度场与初始各向异性参数场，通过网格层析迭代进行更新，获得迭代优化的地震速度场和各向异性参数场。
  24. 如权利要求23所述的装置，其特征在于，迭代优化模块具体用于：
    若工区处理范围内存在预设类型属性体，基于初始各向异性参数场，采用高分辨率网格层析，建立起火成岩段小尺度网格模型，对火成岩速度进行刻画，进行迭代更新；
    对VSP驱动校正后的地震速度场中VSP井底至靶点盲区速度开展层控与速度扫描结合的方法进行迭代更新。
  25. 如权利要求14所述的装置，其特征在于，叠后提频修饰处理模块具体用于：
    采用振幅因子保持技术对偏移成果进行叠后提频修饰处理。
  26. 如权利要求14所述的装置，其特征在于，成像位置确定模块具体用于：
    对偏移成果中目标体周边速度进行常速填充，然后分别进行成像，获得第一成像结果；
    对偏移成果中目标体周边速度保持横向相对关系不变，进行百分比扫描，分别进行成像，获得第二成像结果；
    对偏移成果中目标体周边速度当前位置不变，进行横向相对关系扫描，分别进行成像，获得第三成像结果；
    对第一成像结果、第二成像结果、第三成像结果进行绘图；
    根据绘图结果选择目标储层最大概率成像位置。
  27. 一种计算机设备，包括存储器、处理器及存储在存储器上并可在处理器上运行的计算机程序，其特征在于，所述处理器执行所述计算机程序时实现权利要求1至13任一所述方法。
  28. 一种计算机可读存储介质，其特征在于，所述计算机可读存储介质存储有计算机程序，所述计算机程序被处理器执行时实现权利要求1至13任一所述方法。
  29. 一种计算机程序产品，其特征在于，所述计算机程序产品包括计算机程序，所述计算机程序被处理器执行时实现权利要求1至13任一所述方法。
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