CN114488305B - Fine calibration method for seismic data geological horizon in new exploratory area without well - Google Patents
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Abstract
The invention discloses a method for finely calibrating seismic data geological horizon in a new exploratory area without a well, which realizes the fine calibration work of the seismic geological horizon. The method comprises the following steps: s01: selecting field standard profile reconnaissance points and sequencing the points; s02: selecting seismic geologic horizon comparison channels of a seismic section; s03: obtaining seismic frequency spectrum and dominant frequency of the seismic section; s04: calculating the thickness of the earthquake detectable stratum and the thickness of the distinguishable stratum; s05: obtaining field outcrop standard section measurement data; s06: measuring rock acoustic velocity and density data; s07: obtaining the thickness of the seismic stratum; s08: calculating a reflection coefficient series of the standard layer; s09: solving seismic wavelets; s10: calculating a synthetic seismic record; s11: and (5) calibrating a geological interface.
Description
Technical Field
The invention relates to the technical field of conventional and unconventional oil and gas exploration, in particular to a method for finely calibrating a geological horizon of seismic data of a new exploratory area without a well, which is particularly suitable for the oil and gas exploration field of new energy resources such as unconventional oil and gas, natural gas hydrate, deep pot gas, shale oil and gas and the like which are lacked or even have no drilling and logging data at the initial stage of exploration, or deep strata and deep water areas.
Background
In the conventional and unconventional oil and gas exploration and development processes, the geological horizon calibration on seismic data is the basic work of seismic interpretation, but the accuracy of the geological horizon calibration determines the reliability of the seismic interpretation work and directly influences the subsequent work of resource evaluation, drilling deployment and the like, so the horizon calibration of the seismic data is also the core work.
At present, geological horizon calibration has two modes of a capping method and a well-to-seismic contrast method on seismic data. The cap wearing method is to establish a structural geological pattern, collect ground geological data, mainly comprise structural characteristics and lithological characteristics of exposed strata, draw lithological profiles with the same scale as seismic profiles, and integrate the lithological profiles with the seismic profiles, so that interpreters can understand and know the structural geological pattern conveniently. The well-seismic comparison method is characterized in that the synthetic seismic record is calculated and calibrated on the actual seismic record through well drilling data convolution, the comparison markers of the well-seismic record and the synthetic seismic record are seismic records and are compared in the same dimensional range, the comparison process is more intuitive, and the conclusion reliability is higher.
The two methods have respective application ranges and have certain defects. The method is mainly applied to the unconventional initial exploration of new energy resources such as natural gas hydrate, deep basin gas, shale oil and the like, the complete stratum sequence of a research area cannot be provided because drilling is not carried out or is rare in drilling in a exploration area, the application effect is limited by the seismic data interpretation level and the working experience of interpreters, and the subjectivity is high. The later conclusion is reliable, but the requirements on the type and the precision of the data are high, the method is widely applied to mature blocks with rich data such as well drilling, well logging and the like in the conventional oil and gas exploration, but for the seismic data interpretation work of a new exploration area without well drilling, due to the lack of well drilling data, synthetic records cannot be made by utilizing the sound wave and density data of well logging, and the method has no strong place.
How to realize accurate seismic geologic horizon calibration in the new drilling-free exploration area is oil and gas exploration, and is particularly a technical problem in the unconventional oil and gas exploration process, and if outcrop data and field data are adopted to simulate seismic synthetic records to calibrate seismic horizons, the method is a good choice, but only one article is provided for research in the aspect. Authors guokui, lisai, and musician moutain published a paper entitled "calibrating seismic horizon by simulating synthetic seismic records according to outcrop data-exemplified by Garmsar block Kuh-e-Gugird anticline" in a journal published as "geophysical prospecting chemical exploration computing technology", with publication time of 3 months and 15 days in 2009. The journal literature mainly discloses: under the condition that no logging information exists in a research area, a geological profile measured in the field is utilized, the speed and density information of an adjacent area is referred, the seismic synthetic record is simulated, and the seismic horizon calibration is carried out on the seismic information passing through a Garmsar block Kuh-e-Gugidd anticline. However, this method still has three problems or drawbacks:
(1) the data is dependent on the neighbor well data. In the method, speed and density data adopted by well-free calibration are derived from drilling data of adjacent work areas, and if no drilling is carried out in the adjacent area of a new exploration area, key information such as thickness and density of a deep buried underground stratum cannot be obtained, so that the method cannot be directly used for seismic data calibration.
(2) Whether the referenced data points are in the same depositional facies band as the seismic data to be calibrated is not considered. In the method, the speed and density adopted for making the artificial synthetic seismic record come from the drilling data of the adjacent region and are influenced by various aspects such as the change of sedimentary facies belt, burial depth compaction and the like, when the geological backgrounds of the adjacent region and the research region are completely matched, the neighborhood data can be directly used, but when the deposition backgrounds of the two are not matched, because the two deposition backgrounds are different at the same time, the stratum in the same period is caused by different rock types and different components, the velocities of the seismic waves propagated by the rock-type seismic wave is different, sometimes, even if the same rock-type seismic wave-type seismic wave-type seismic wave-seismic wave is different, the wave velocity of the seismic geological horizon calibration method can also change within a certain range, so that the velocity and density change greatly, and the method can be directly used for making a synthetic seismic record without undoubtedly having a large error in comparison with seismic data, and even more, if no drilling data exists in the adjacent region, the method can not be applied to the seismic geological horizon calibration work;
(3) the effect of lateral variations in formation thickness on synthetic seismic recordings is not considered. The method does not consider the transverse change of the stratum, but is actually influenced by factors such as water depth, buried depth, structure position (like the transverse change of the stratum thickness caused by a sedimentary structure) and the like during sedimentation, even if the same facies zone is in the same set of stratum, the transverse change of the stratum also exists, and the problem that the outcrop thickness is directly used for replacing the underground thickness also exists.
If the problems of lack of logging speed and accuracy can be solved, and the influence caused by stratum thickness is fully considered and solved, the difficult problem of seismic horizon calibration of a new exploration area which has no drilling data in a neighboring area and can be referred to can be realized, meanwhile, the problem of multiresolution of seismic geologic horizon calibration can be eliminated to the greatest extent, and the accuracy of geologic horizon calibration is improved.
Disclosure of Invention
The invention aims to overcome the defects of the prior art, provides a method for finely calibrating seismic data geological horizon in a well-free new exploration area, and realizes fine calibration work of the seismic geological horizon.
The purpose of the invention is realized as follows:
a method for finely calibrating seismic data geological horizon in a well-free new exploration area comprises the following steps:
s01: selecting field standard profile reconnaissance points and sequencing the points;
s02: selecting seismic geological layer comparison channels of a seismic section;
s03: obtaining seismic frequency spectrum and dominant frequency of the seismic section;
s04: obtaining the thickness of the earthquake detectable stratum and the thickness of the distinguishable stratum;
s05: obtaining field outcrop standard profile measurement data;
s06: measuring rock acoustic velocity and density data;
s07: obtaining the thickness of the seismic stratum;
s08: calculating a reflection coefficient series of the standard layer;
s09: solving seismic wavelets;
s10: calculating a synthetic seismic record;
s11: and (5) calibrating a geological interface.
Further, the step S01 includes:
s011: superposing the plane position of the seismic section survey line and the field outcrop section position on a related basic geological map through a geodetic coordinate system to form a superposed map;
s012: on a superimposed graph, selecting a dew point of a target stratum (namely a stratum sequence needing to be calibrated on a seismic section) on a geological map according to the principle of 'approaching to a measuring line, consistent phase zone and consistent lithology', and selecting a plurality of dew points according to the principle by taking a group or even a section as a unit, thereby forming a field stratum point set corresponding to a seismic section calibration timing window;
s013: and sequencing the selected outcrop points from new to old, and combining the outcrop points with lines to form a field standard profile survey point with complete stratum.
Further, the step S02 includes:
tracking and comparing the homophase axes with strong amplitude energy and good continuity by utilizing the longitudinal strength relationship and the contact relationship of the homophase axes of the seismic section, including upper-exceeding, lower-exceeding and truncation, and obtaining a seismic stratum frame interface;
and respectively making the same facies zone translation connecting line from the selected outcrop point to the seismic section according to the regional sedimentary facies zone, wherein the line is intersected with the plane projection line of the seismic section, making a connecting line middle point of the vertical intersection point of the seismic section, extending from the middle point to two sides, and selecting 1000 lines with stable seismic stratum frame thickness as seismic contrast lines of the seismic section, so that the rock stratum at the seismic contrast lines and the rock stratum of the field section have the consistency of sedimentary sequences, the rock stratum thicknesses of the two points have a linear relation, and the speed and density parameters of the rock have the contrastability.
Further, the step S03 includes:
respectively selecting seismic waves of which the time windows at the top, the middle and the bottom of the seismic profile contrast channel are more than two periods to carry out fast Fourier transform, calculating the top, the middle and the bottom seismic time domain match spectrums, and if the match spectrums have jumping waves, reselecting and expanding the time windows until the wave spectrum is stable to obtain the seismic frequency spectrum;
on the seismic complex spectrum, a horizontal straight line is drawn with the-20 DB signal as a boundary, and the line has two intersections with the seismic spectrum curve: maximum frequency f max Minimum frequency f min Major frequency f of earthquake avg Comprises the following steps:
the step S04 includes:
picking up a final velocity spectrum by using the seismic processing process, and picking up velocities v at the top, the middle and the bottom;
respectively calculating the thickness of the earthquake detectable strata at the top, the middle and the bottom, and then taking the average value as the thickness of the earthquake data;
respectively calculating the thicknesses of the seismic distinguishable strata at the top, the middle and the bottom, and then taking the average value as the thickness of the seismic distinguishable strata of the seismic data;
the step S05 includes:
sequentially surveying the field profiles according to the sequence;
in the process of the exploration, the thickness of each lithologic stratum is recorded while the lithology and the layering are observed, the thickness recording range is not more than the detectable stratum thickness of the earthquake, and lithology sampling is carried out within the range from the detectable stratum thickness to the distinguishable stratum thickness.
Further, the step S06 includes:
compiling a lithology comprehensive histogram by using data measured in the field;
measuring the density data of the sample, and calculating the longitudinal wave velocity data V of the sample by the following formula Sample (A) ：
V Sample (A) ＝(ρ Sample (A) ×3.2051) 4.10257 ；
Adding a hollow channel beside a lithologic column of the lithologic comprehensive histogram, and recording density data and longitudinal wave velocity data of a sample in the hollow channel;
and respectively combining the density data and the longitudinal wave velocity data scatter point connecting lines into a velocity data broken line.
Further, the step S07 includes:
performing lithology grouping according to the speed difference, wherein the minimum grouping unit is a lithology group;
respectively picking up the thickness of the stratum frame, and calculating the thickness of the stratum frame by using the velocity data processed by the seismic data;
roughly determining the era of the seismic frame stratum by utilizing a capping method and a lithology group seismic facies analysis method and combining a lithology comprehensive histogram;
extending according to seismic stratigraphic frame layer contact relationTo the outcrop point, adopting a deposition trend comparison method and utilizing the thickness h of the frame layer k Lithology group h measured in the field z Comparing, and obtaining a lithology group thickness contrast coefficient K;
calculating the average value k of the thickness contrast coefficient of the lithology group a ；
Using the formula:
h z ＝h k *k a
and (4) calculating the thickness of the lithology group as the thickness of the true stratum of the lithology group, wherein the thickness is equivalent to the lithology combination of the seismic profile comparison point, and the thickness of the stratum is consistent.
Further, the step S08 includes:
according to the lithology group data, the reflection coefficient sequence of the interface between the lithology groups is obtained by the following formula:
in the formula, R i Reflection coefficient, ρ, for the interface formed by lithology group i and lithology group i +1 i 、v i And ρ i+1 、v i+1 Density and sound wave velocity of i and i +1, respectively.
Further, the step S09 includes:
using Rake wavelets with seismic dominant frequency f avg Computing to obtain seismic wavelets
Wherein A (t) is the amplitude of the Rake wavelet at the reflection interface, f avg And t is the time of the relative convolution center point in the time window, wherein t is the seismic dominant frequency.
Further, the step S10 includes:
according to the speed and thickness data of lithological grouping, time-depth conversion is carried out, the corresponding relation of time, depth, lithological and geological stratification needs to be recorded at the same time in the conversion process, a basic data comparison reference table is established, the accumulated value of the converted time is compared with a time window value selected by an earthquake, and the maximum value is selected as a calculation time window;
utilizing convolution of lithology group reflection sequences and seismic wavelets in a corresponding time domain range, accumulating in a calculation time window, and calculating to obtain synthetic seismic record data S (t);
S(t)＝R i (t)*A(t)
wherein S (t) is synthetic seismic record data, i is lithology group number, R i (t) is the reflection coefficient of the interface formed by the lithology group i and the lithology group i +1, A (t) is the amplitude energy of the Rake wavelet of the reflection interface, and t is the time of the relative convolution center point in the time window.
Further, the step S11 includes:
drawing a waveform diagram of the synthetic seismic record data in a coordinate system, wherein the waveform diagram is a synthetic seismic record trace and needs to satisfy the following conditions: the horizontal direction is an amplitude value, the longitudinal direction is time, and the time sequence is sequentially reduced from the longitudinal direction to the upper direction;
adjusting the longitudinal time proportion of the synthetic seismic trace to be consistent with the seismic profile, adjusting the maximum value of the transverse amplitude to be consistent with the seismic, superposing the synthetic seismic trace on the seismic profile, roughly comparing and calibrating a maximum reflection energy axis by a capping method, moving the synthetic seismic trace up and down to enable the synthetic seismic trace to be consistent with the energy relation of the longitudinal wave group of the actual seismic trace, and enabling the correlation to be maximum, wherein the seismic trace obtained by field data is matched with the actual profile;
and calibrating the geological stratification interface on the seismic section by using the corresponding relation of time, lithology and geological stratification in the basic data comparison reference table, thereby realizing the final seismic geological interface calibration.
Due to the adoption of the technical scheme, the method is applied to seismic interpretation work of a new exploration area lacking well drilling data in the oil-gas exploration process, and can realize fine calibration work of the seismic geological formation through methods such as outcrop point selection, seismic contrast channel deposition translation selection, sampling, experiments, comparison and the like.
The advantages of the invention include:
(1) the seismic contrast channels in the seismic section are selected in a sedimentary facies belt translation mode, so that the field actual measurement section and the seismic contrast channels have contrastability, the stratum thickness and the seismic contrast channels have a linear relation, and the thickness of seismic detection can be accurately calculated through field outcrop lithology group thickness data;
(2) the method has the advantages that the rock sample is obtained by actually measuring the profile in the field, the rock speed and density data are actually measured in a laboratory, the thickness can be distinguished and detected through earthquake, the number of sampling points is reduced, in addition, the longitudinal wave speed data are inversely calculated by using the density data, so that the method is simplified, the operation difficulty can be reduced, the actually measured cost is greatly reduced, and the obtained data is more accurate than well logging curves adopting other blocks;
drawings
FIG. 1 is a flow chart of a method of the present invention;
FIG. 2 is a schematic view of seismic profile survey lines and field geological outcrop location;
FIG. 3 is a schematic view of a survey line seismic section (white border in the figure is selected for contrasting seismic traces);
FIG. 4 is a schematic diagram of synthetic seismic records and seismic profile seismic geological horizon vs. trace folding.
Detailed Description
The method of the invention is realized by a flow chart 1, mainly comprising 11 steps which are respectively as follows:
s01: selecting a field standard profile surveying point;
s02: selecting seismic profile seismic geological layer contrast channels;
s03: obtaining seismic frequency spectrum and dominant frequency of the seismic section;
s04: calculating the thickness of the earth layer which can be detected and distinguished by earthquake;
s05: acquiring field outcrop standard profile measurement data;
s06: measuring rock acoustic velocity and density data in a laboratory;
s07: obtaining the thickness of the seismic stratum;
s08: calculating a reflection coefficient series of the standard layer;
s09: solving seismic wavelets;
s10: calculating a synthetic seismic record;
s11: and (5) calibrating a geological interface.
The specific implementation process is as follows:
step S01 (selecting a standard field profile survey point) includes:
(1) superposing the plane position of the seismic section survey line and the field outcrop section position on a related basic geological map through a geodetic coordinate system to form a superposed map;
(2) on a superimposed graph, selecting a dew point of a target stratum (namely a stratum sequence needing to be calibrated on a seismic section) on a geological map according to the principle of 'approaching to a measuring line, consistent phase zone and consistent lithology', and selecting a plurality of dew points according to the principle by taking a group or even a section as a unit, thereby forming a field stratum point set corresponding to a seismic section calibration timing window;
(3) arranging the selected outcrop points in the order from new to old, and combining the outcrop points with a connecting line to form a field standard profile surveying point with complete stratum;
step S02 (selecting seismic profile seismic geologic contrast traces) includes:
(1) tracking and comparing the homophase axes with strong amplitude energy and good continuity by utilizing the longitudinal strength relationship and the contact relationship of the homophase axes of the seismic section, including upper-exceeding, lower-exceeding and truncation, and obtaining a seismic stratum frame interface;
(2) and respectively making the same facies zone translation connecting line from the selected outcrop point to the seismic section according to the regional sedimentary facies zone, intersecting the line with the plane projection line of the seismic section, making a connecting line midpoint of the intersection point of the vertical lines of the seismic section, extending from the midpoint to two sides, and selecting 1000 channels with stable thickness of the seismic stratum frame as seismic contrast channels of the seismic section.
The method is one of the core steps of the method and is characterized in that a sedimentary facies belt translation mode is utilized to search for a contrast channel of the seismic section, and therefore consistency of a rock stratum at the seismic contrast channel and a rock stratum of a field section with a sedimentary sequence can be guaranteed, so that the rock stratum thicknesses of two points have a linear relation, and the speed and density parameters of the rock have comparability.
Step S03 (finding the seismic profile seismic spectrum and dominant frequency) includes:
(1) respectively selecting seismic waves of which the time windows at the top, the middle and the bottom of a seismic section contrast channel are more than two periods to carry out fast Fourier transform, solving the seismic time domain complex spectra of three parts, and if the complex spectra have wave hopping, reselecting and expanding the time windows until the wave spectrum is stable to obtain the seismic frequency spectrum;
(2) on the seismic complex spectrum, a horizontal straight line is drawn by taking the-20 DB signal as a boundary, the line and a seismic spectrum curve have two intersection points, and the maximum of the two intersection points is called the highest frequency f max The smallest is called the minimum frequency f min Major frequency f of earthquake avg The average value of the two is obtained;
step S04 (finding the seismic detectable and distinguishable formation thickness) includes:
(1) picking up a final velocity spectrum by using the seismic processing process, and picking up velocities v at the top, the middle and the bottom;
(2) respectively solving the thickness h of the earthquake detectable stratum as v/32f according to a calculation formula avg Acquiring the thickness of the detectable strata at the top, the middle and the bottom, and calculating the average value of the thickness of the detectable strata at the top, the middle and the bottom as the thickness of the detectable strata of the seismic data;
(3) respectively solving the thickness h of the earthquake-distinguishable stratum according to a calculation formula avg Obtaining the thicknesses of the distinguishable stratums at the top, the middle and the bottom, and calculating the average value of the thicknesses of the distinguishable stratums as the thickness of the seismic data;
step S05 (field outcrop standard profile measurement data) includes:
(1) sequentially surveying the field profiles according to the serial number sequence of standard profile surveying points;
(2) in the process of surveying, when lithology and layering are observed, the thickness of each lithology stratum is recorded, the thickness recording range is not more than the detectable thickness of earthquake, the lithology is sampled, at least one sample is required to be sampled within the range from the detectable thickness of the stratum to the distinguishable thickness according to the sampling principle, and the edges of a sample cube are not less than 10 cm.
Step S06 (laboratory measured rock acoustic velocity and density data) includes:
(1) firstly, aiming at field measured data, a lithology comprehensive histogram is compiled by a conventional method;
(2) by measuring the density data and the longitudinal wave velocity data of the sample, if the experiment cost is saved, the density data of the sample can be measured, and then the longitudinal wave velocity data V of the sample can be inversely calculated Sample (A) In the laboratory process, the rock sample needs to be dried firstly and then measured;
V sample (A) ＝(ρ Sample (A) ×3.2051) 4.10257
(3) Adding a path beside the lithologic pillar of the synthetic histogram, and recording speed and density data in the path;
(4) respectively combining the scattered point connecting lines of the speed data and the density data into a speed data broken line;
the step is also one of the core steps of the invention, and the error caused by randomly selecting other data can be reduced through actual measurement.
Step S07 (finding the seismic formation thickness) includes:
(1) the parts with large speed difference are grouped, the parts with lithology speed difference smaller than 3% are used as a group, the group is called lithology group, and the minimum grouping unit is called lithology group;
(2) respectively picking up the thickness of the stratum frame, and calculating the thickness of the stratum frame by using the velocity data processed by the seismic data;
(3) roughly determining the era of the seismic frame stratum by utilizing a method of cap wearing and lithology group seismic facies analysis and combining a lithology comprehensive histogram;
(4) extending to the outcrop point according to the contact relation of the seismic stratum frame layer, adopting a deposition trend comparison method and utilizing the thickness h of the frame layer k Lithology group h measured in the field z Comparing, and solving a lithology group thickness contrast coefficient K;
(5) calculating the average value k of the thickness contrast coefficient of the lithology group a ；
(6) By using h z ＝h k *k a The thickness of the lithology group is obtained and used as the thickness of the real stratum of the lithology group, the thickness is equivalent to the lithology combination of the seismic section comparison point, and the thickness of the stratum is basically consistent;
this step is also one of the core steps of the present invention, correcting the thickness of the outcrop section point to the thickness of the seismic section, reducing the possible deviation of the synthetic seismic traces.
Step S08 (finding the standard layer reflection coefficient series) includes:
(1) according to the lithology group data, the reflection coefficient sequence of the interface between the lithology groups is obtained by a formula:
in the formula, R i Reflection coefficient, ρ, for the interface formed by lithology group i and lithology group i +1 i 、v i And ρ i+1 、v i+1 Density and acoustic velocity of i and i +1, respectively;
step S09 (finding the seismic wavelet) includes:
(1) using Rake wavelets with average frequency f avg Computing to obtain seismic wavelets
Wherein A (t) is the amplitude of the Rake wavelet of the reflective interface, f avg And t is the time of the relative convolution center point in the time window, wherein t is the seismic dominant frequency.
Step S10 (calculating a synthetic seismic record) includes:
(1) firstly, performing time-depth conversion according to speed and thickness data of lithological grouping, simultaneously recording corresponding relations of time, depth, lithological and geological stratification in the conversion process, establishing a basic data comparison reference table, comparing an accumulated value of conversion time with a time window value selected by an earthquake, and selecting a maximum value as a calculation time window;
(2) and utilizing convolution of the lithology group reflection sequence and the seismic wavelets in a corresponding time domain range, accumulating in a calculation time window, and calculating to obtain synthetic seismic record data S (t).
S(t)＝R i (t)*A(t)
Wherein S (t) is synthetic seismic record data, i is lithology group number, R i (t) is the reflection coefficient of the interface formed by the lithology group i and the lithology group i +1, A (t) is the amplitude energy of the Rake wavelet of the reflection interface, and t is the time of the relative convolution center point in the time window.
Step S11 (geological interface calibration) includes:
(1) drawing a waveform diagram of the synthetic seismic record data in a coordinate system, wherein the diagram is called a synthetic seismic record trace and needs to satisfy the following conditions: the horizontal direction is an amplitude value, the longitudinal direction is time, and the time sequence is sequentially reduced from the longitudinal direction to the upper direction;
(2) adjusting the longitudinal time proportion of the synthetic seismic trace to be consistent with the seismic profile, adjusting the maximum value of the transverse amplitude to be consistent with the seismic, superposing the synthetic seismic trace on the seismic profile, roughly comparing and calibrating a maximum reflected energy axis by a capping method, moving the synthetic seismic trace up and down to ensure that the energy relationship between the synthetic seismic trace and the longitudinal wave group of the actual seismic trace is consistent and the correlation degree is maximum, and matching the seismic trace obtained by field data with the actual profile;
(3) and calibrating the geological stratification interface on the seismic section by using the time, lithology and geological stratification corresponding relation in the basic data comparison reference table, thereby realizing the final seismic geological interface calibration.
In the explanation work of the earthquake of a certain fault in a new exploration area, because the southwest part of the earthquake area does not uncover the deep well of the Olympic system of the Hanwu system at present, the earthquake area lacks effective drilling data support, and the internal stratum of the Olympic system (O) cannot be calibrated and distinguished, but the northwest ridge area of the earthquake areaThe earth layer exposed heads (No. 1-No. 4) are exposed (figure 2), and because the seismic section is close to the exposed heads and is in the same table edge slope environment, the deposition environment and the earth structure have similarity, the seismic section seismic geological layer comparison channel (figure 3) can be accurately selected. By the method, according to data such as stratum thickness, lithology and the like measured in the field, the field profile is sampled, the indoor measured profile is subjected to velocity data acquisition, a velocity data broken line (figure 4) is formed, the reflection coefficient of each interface is calculated, and the superposition of the Rake wavelets is carried out, so that the simulation of outcrop geological profile simulation seismic record in the non-well area is finally realized. The seismic record traces are repeatedly compared with the reflection characteristics of the seismic section position after translation, the fact that the correlation degree of the synthetic seismic record and the seismic section seismic geological layer is the highest compared with the traces is found, the correlation degree of the two contrasts on the left side is low, the manufacturing of the synthetic seismic record traces and the position of the seismic section seismic geological layer are accurate, and at the moment, the main layer position can basically correspond to the upper layer, especially the middle-upper Ordovician stratum. Thus, an outcrop geology stratification of the Otto System Bay Trench group (O) is achieved 2 d) Shanao Tuotussal group (O) 3 s), Shanao clay kengling group (O) 3 k) Odoo ceramic Tongqilang group (O) 3 q) and Shanao ceramic imprinting dry group (O) 3 y) accurately calibrating to the seismic section (A-line).
Finally, it is particularly pointed out that the above preferred examples are intended to illustrate the technical solution of the invention, without limiting it, and that, although the invention has been described in detail by means of the above preferred examples, it will be understood by those skilled in the art that reasonable variations in form and detail may be made therein depending on the actual geological conditions, without departing from the scope of the invention as defined by the claims.
Claims (10)
1. A method for finely calibrating seismic data geological horizon in a well-free new exploration area is characterized by comprising the following steps:
s01: selecting field standard profile reconnaissance points and sequencing the points;
s02: selecting seismic profile seismic geological horizon contrast channels by means of sedimentary facies belt translation;
s03: obtaining the seismic frequency spectrum and the dominant frequency of the seismic section;
s04: obtaining the thickness of the earthquake detectable stratum and the thickness of the distinguishable stratum;
s05: acquiring field outcrop standard profile measurement data and collecting a rock sample;
s06: measuring rock acoustic velocity and density data in a laboratory;
s07: calculating the thickness of the seismic stratum, and correcting the thickness of the outcrop section point to the thickness of the seismic section;
s08: calculating a reflection coefficient series of the standard layer;
s09: solving seismic wavelets;
s10: calculating a synthetic seismic record;
s11: and (5) calibrating a geological interface.
2. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 1, characterized by comprising the following steps: the step S01 includes:
s011: superposing the plane position of the seismic section survey line and the field outcrop section position on a related basic geological map through a geodetic coordinate system to form a superposed map;
s012: on a superimposed graph, selecting a target stratum dew point on a geological map according to the principle of 'approaching to a measuring line, consistent facies zone and consistent lithology', and selecting a plurality of outcrop points according to the principle by taking a 'group' or a 'section' as a unit, so as to form a field stratum point set corresponding to a seismic section calibration-simulating timing window;
s013: and sequencing the selected outcrop points from new to old, and combining the outcrop points with lines to form a field standard profile survey point with complete stratum.
3. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 2, characterized by comprising the following steps: the step S02 includes:
tracking the homophase axes with strong contrast amplitude energy and good continuity according to the longitudinal and transverse strength change, the frequency, the homophase axis contact relation and the integral seismic reflection characteristics of the homophase axes of the seismic section based on the knowledge of the integral geological characteristics of the newly explored area and the geological research of the outcrop section to obtain a seismic stratum frame interface;
and (2) respectively making the selected outcrop points translate and connect the same phase zone into the seismic section by utilizing a new exploration area sedimentary facies zone division result, wherein the line is intersected with a plane projection line of the seismic section, a middle point of a connection line of a vertical line intersection point of the seismic section is made, the middle point extends to two sides, and 1000 channels with stable seismic stratum frame thickness are selected as seismic contrast channels of the seismic section, so that the consistency of sedimentary sequences of rock layers at the seismic contrast channels and rock layers of a field section is ensured, the rock layer thicknesses of two points are ensured to have a linear relation, and the speed and density parameters of rocks have contrastability.
4. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 3, characterized by comprising the following steps: the step S03 includes:
respectively selecting seismic waves with a time window larger than two periods from the top, the middle and the bottom of the seismic section contrast channel selected from the frame to carry out fast Fourier transform, solving seismic time domain complex spectrum of the top, the middle and the bottom, and if the solved complex spectrum has jumping waves, reselecting and expanding the time window until the wave spectrum is stable to obtain a seismic frequency spectrum;
on the seismic complex spectrum, a horizontal straight line is drawn with the-20 DB signal as a boundary, and the line has two intersections with the seismic spectrum curve: i.e. the highest frequency f max Minimum frequency f min From this, the seismic dominant frequency f can be obtained avg Comprises the following steps:
the step S04 includes:
picking up a final velocity spectrum by using the seismic processing process, and picking up velocities v at the top, the middle and the bottom;
respectively taking the thicknesses of the earthquake detectable strata at the top, the middle and the bottom, and then taking the average value as the thickness of the earthquake data;
respectively calculating the thicknesses of the seismic distinguishable strata at the top, the middle and the bottom, and then taking the average value as the thickness of the seismic distinguishable strata of the seismic data;
the step S05 includes:
sequentially surveying the field profiles according to the sequence;
in the process of surveying, the lithology and layering are observed, meanwhile, the thickness of different lithology strata is measured and recorded, the thickness recording range is not larger than the detectable thickness of the earthquake, and lithology sampling is carried out within the range from the detectable thickness of the strata to the distinguishable thickness of the strata.
5. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 4, characterized by comprising the following steps: the step S06 includes:
compiling a lithology comprehensive histogram by using data measured in the field;
measuring the density data of the sample, and calculating the longitudinal wave velocity data V of the sample by the following formula Sample (A) ：
V Sample (A) ＝(ρ Sample (A) ×3.2051) 4.10257 ；
Adding a hollow channel beside a lithologic column of the lithologic comprehensive histogram, and recording density data and longitudinal wave velocity data of a sample in the hollow channel;
and respectively combining the density data and the longitudinal wave velocity data scatter point connecting lines into a velocity data broken line.
6. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 5, characterized by comprising the following steps: the step S07 includes:
performing lithology grouping according to the speed difference, wherein the minimum grouping unit is a lithology group;
respectively picking up the thickness of the stratum frame, and calculating the thickness of the stratum frame by using the velocity data processed by the seismic data;
roughly determining the era of the seismic frame stratum by utilizing a capping method and a lithology group seismic facies analysis method and combining a lithology comprehensive histogram;
extending to the outcrop point according to the contact relation of the seismic stratum frame layer, adopting a deposition trend comparison method and utilizing the thickness h of the frame layer k Lithology group h with field measurement z Comparing, and solving a lithology group thickness contrast coefficient K;
calculating the average value k of the thickness contrast coefficient of the lithology group a ；
Using the formula:
h z ＝h k *k a
and (4) calculating the thickness of the lithology group as the thickness of the true stratum of the lithology group, wherein the thickness is equivalent to the lithology combination of the seismic profile comparison point, and the thickness of the stratum is consistent.
7. The method for fine calibration of seismic data geological horizon of a well-free new exploration area as claimed in claim 6, wherein: the step S08 includes:
according to the lithology group data, the reflection coefficient sequence of the interface between the lithology groups is obtained by the following formula:
in the formula, R i The reflection coefficient, rho, for the interface formed by lithology group i and lithology group i +1 i 、v i And ρ i+1 、v i+1 Density and sound wave velocity of i and i +1, respectively.
8. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 7, characterized by comprising the following steps: the step S09 includes:
using Rake wavelets and seismic dominant frequency f avg Computing to obtain seismic wavelets
Wherein A (t) is the amplitude of the Rake wavelet of the reflective interface, f avg And t is the time of the relative convolution center point in the time window, wherein t is the seismic dominant frequency.
9. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 8, characterized by comprising the following steps: the step S10 includes:
according to the speed and thickness data of lithological grouping, time-depth conversion is carried out, the corresponding relation among time, depth, lithological character and geological stratification needs to be recorded at the same time in the conversion process, a basic data comparison reference table is established, the accumulated value of conversion time is compared with a time window value selected by an earthquake, and the maximum value is selected as a calculation time window;
utilizing convolution of lithology group reflection sequences and seismic wavelets in a corresponding time domain range, accumulating in a calculation time window, and calculating to obtain synthetic seismic record data S (t);
S(t)＝R i (t)*A(t)
wherein S (t) is synthetic seismic record data, i is lithology group number, R i (t) is the reflection coefficient of the interface formed by the lithology group i and the lithology group i +1, A (t) is the amplitude energy of the Rake wavelet of the reflection interface, and t is the time of the relative convolution center point in the time window.
10. The method for fine calibration of seismic data geological horizon in a well-free new exploration area according to claim 9, characterized by comprising the following steps: the step S11 includes:
drawing a waveform diagram of the synthetic seismic record data in a coordinate system, wherein the diagram is a synthetic seismic record trace and needs to satisfy the following conditions: the horizontal direction is an amplitude value, the longitudinal direction is time, and the time sequence is sequentially reduced from the longitudinal direction to the upper direction;
adjusting the longitudinal time proportion of the synthetic seismic trace to be consistent with the longitudinal scale of the seismic section, adjusting the maximum value of the transverse amplitude to be consistent with the seismic section, superposing the synthetic seismic trace on the seismic section, roughly comparing and calibrating a maximum reflection energy axis by using a capping method, moving the synthetic seismic trace up and down to ensure that the energy relationship between the synthetic seismic trace and the longitudinal wave group of the actual seismic trace is consistent, and the correlation degree is maximized, wherein the seismic trace obtained by field data is matched with the actual section;
and calibrating the geological stratification interface on the seismic section by using the time, lithology and geological stratification corresponding relation in the basic data comparison reference table, thereby realizing the final seismic geological interface calibration.
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