CN107422377B - Utilize the method and device of seismic data prediction hydrocarbon source rock total content of organic carbon - Google Patents
Utilize the method and device of seismic data prediction hydrocarbon source rock total content of organic carbon Download PDFInfo
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- OKTJSMMVPCPJKN-UHFFFAOYSA-N Carbon Chemical compound [C] OKTJSMMVPCPJKN-UHFFFAOYSA-N 0.000 title claims abstract description 95
- 229910052799 carbon Inorganic materials 0.000 title claims abstract description 95
- 239000011435 rock Substances 0.000 title claims abstract description 54
- 238000000034 method Methods 0.000 title claims abstract description 40
- 239000004215 Carbon black (E152) Substances 0.000 title claims abstract description 34
- 229930195733 hydrocarbon Natural products 0.000 title claims abstract description 34
- 150000002430 hydrocarbons Chemical class 0.000 title claims abstract description 34
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- 238000004519 manufacturing process Methods 0.000 description 1
- 230000005055 memory storage Effects 0.000 description 1
- 230000000750 progressive effect Effects 0.000 description 1
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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
- G01V1/306—Analysis for determining physical properties of the subsurface, e.g. impedance, porosity or attenuation profiles
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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
- G01V1/40—Seismology; Seismic or acoustic prospecting or detecting specially adapted for well-logging
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- 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
- G01V2210/6226—Impedance
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- 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
- G01V2210/624—Reservoir parameters
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Abstract
The embodiment of the present application provides a kind of method and device using seismic data prediction hydrocarbon source rock total content of organic carbon, this method comprises: according to specifying the interval transit time curve of well point to obtain wave impedance in work area, and pseudo- wave impedance is obtained according to the resistivity curve of specified well point；Determine the first wave impedance differences of wave impedance and pseudo- wave impedance；Determine the total content of organic carbon curve of specified well point；Determine the relation curve of first wave impedance differences Yu organic carbon content curve；It is utilized respectively wave impedance and pseudo- wave impedance, wave impedance inversion is carried out to the seismic data in work area, it is corresponding to obtain wave impedance inversion data volume and pseudo- wave impedance inversion data volume；Determine the second wave impedance difference of wave impedance inversion data volume and pseudo- wave impedance inversion data volume；According to the second wave impedance difference and relation curve, the hydrocarbon source rock total content of organic carbon data volume in work area is determined.The TOC content prediction precision in work area can be improved in the embodiment of the present application.
Description
Technical Field
The application relates to the technical field of Total Organic Carbon (TOC) prediction of source rock, in particular to a method and a device for predicting the TOC of the source rock by using seismic data.
Background
The oil field development enters the middle and later stages, more and more attention is paid to the reserve prediction of the residual oil, and the subsequent exploitation strategy of the oil field is often directly influenced by the residual recoverable reserve of the oil field. To obtain accurate remaining recoverable reserves of the oil field, the remaining total reserves of the oil field need to be accurately predicted, and to accurately predict the remaining total reserves of the oil field, the TOC content of the oil-producing formation is a key parameter.
Currently, the prediction of the TOC content is mostly performed by counting the TOC content information of each drilled well in a work area and then performing simulation prediction on the whole work area by using a variation mode. In the process of implementing the present application, the inventors of the present application found that: for the places near each well point in the work area, the prediction accuracy of the TOC content can be ensured due to the fact that the TOC content information of each drilled well exists. However, for places other than the vicinity of each well point in the work area, due to lack of appropriate constraint conditions for simulation and prediction of the whole work area, the accuracy of the predicted TOC content of the whole work area is difficult to guarantee, and thus the actual TOC content of the whole work area is difficult to objectively reflect.
Disclosure of Invention
The embodiment of the application aims to provide a method and a device for predicting the total organic carbon content of a hydrocarbon source rock by utilizing seismic data so as to improve the TOC content prediction precision of a work area.
In order to achieve the above object, in one aspect, the embodiments of the present application provide a method for predicting total organic carbon content of a source rock by using seismic data, including:
acquiring wave impedance according to an acoustic time difference curve of a specified well point in a work area, and acquiring pseudo wave impedance according to a resistivity curve of the specified well point;
determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance;
determining a total organic carbon content curve for the designated well point;
determining a relation curve of the first wave impedance difference value and the organic carbon content curve;
respectively utilizing the wave impedance and the pseudo wave impedance to carry out wave impedance inversion on the seismic data of the work area, and correspondingly obtaining a wave impedance inversion data body and a pseudo wave impedance inversion data body;
determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
and determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve.
The application discloses a method for predicting total organic carbon content of hydrocarbon source rock by utilizing seismic data, wave impedance is obtained according to an acoustic time difference curve of a specified well point in a work area, and the method comprises the following steps:
according to the formulaObtaining wave impedance;
wherein, CimpAnd the wave impedance of a designated well point in the work area is defined, rho is the density of the designated well point, and delta t is the acoustic wave time difference of the designated well point.
The method for predicting the total organic carbon content of the hydrocarbon source rock by using the seismic data comprises the following steps of:
converting the resistivity curve of the specified well point into a pseudo-acoustic wave time difference curve;
and acquiring pseudo wave impedance by using the pseudo sound wave time difference curve.
The method for predicting the total organic carbon content of the hydrocarbon source rock by using the seismic data converts the resistivity curve of the specified well point into a pseudo-acoustic wave time difference curve, and comprises the following steps:
according to the formula Δ t ═ KHCdRConverting the resistivity curve of the designated well point into a pseudo-acoustic wave time difference curve;
where Δ t' is the time difference of the pseudo-acoustic wave at the specified well point, K, d and C are constants, H is the depth of the specified well point, and R is the resistivity of the specified well point.
The application discloses a method for predicting total organic carbon content of hydrocarbon source rock by utilizing seismic data, utilize pseudo-acoustic time difference curve obtains pseudo-wave impedance, includes:
according to the formulaAcquiring pseudo wave impedance;
wherein, CimprAnd the pseudo wave impedance of a specified well point in the work area is defined, rho is the density of the specified well point, and delta t' is the pseudo sound wave time difference of the specified well point.
The method for predicting the total organic carbon content of the hydrocarbon source rock by using the seismic data determines the total organic carbon content curve of the specified well point according to the following formula:
TOC＝10×(2.297-0.1688R0)×ΔlogR；
wherein TOC specifies the total organic carbon content, R, of the well point0For the resistivity corresponding to the baseline, Δ logR is the distance between the sonic moveout curve and the resistivity curve at the same depth, and Δ logR is log (R/R)0)+0.02(Δt-Δt0) R is measured resistivity, delta t is measured acoustic time difference, delta t0The acoustic moveout corresponding to the baseline.
In another aspect, an embodiment of the present application further provides an apparatus for predicting total organic carbon content of a source rock by using seismic data, including:
the wave impedance obtaining module is used for obtaining wave impedance according to an acoustic time difference curve of a specified well point in a work area and obtaining pseudo wave impedance according to a resistivity curve of the specified well point;
a first wave impedance difference determination module for determining a first wave impedance difference between the wave impedance and the pseudo-wave impedance;
the single-point content determination module is used for determining a total organic carbon content curve of the specified well point;
the relation curve determining module is used for determining a relation curve of the first wave impedance difference value and the organic carbon content curve;
the wave impedance inversion module is used for performing wave impedance inversion on the seismic data of the work area by respectively utilizing the wave impedance and the pseudo wave impedance to correspondingly obtain a wave impedance inversion data body and a pseudo wave impedance inversion data body;
a second wave impedance difference determination module for determining a second wave impedance difference between the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
and the total content determining module is used for determining a hydrocarbon source rock total organic carbon content data body of the work area according to the second wave impedance difference value and the relation curve.
The device of utilizing seismic data to predict total organic carbon content of hydrocarbon source rock, obtain wave impedance according to the acoustic wave time difference curve of appointed well point in the work area, include:
according to the formulaObtaining wave impedance;
wherein, CimpAnd the wave impedance of a designated well point in the work area is defined, rho is the density of the designated well point, and delta t is the acoustic wave time difference of the designated well point.
The device for predicting the total organic carbon content of the hydrocarbon source rock by using the seismic data, which is provided by the embodiment of the application, obtains the pseudo-wave impedance according to the resistivity curve of the specified well point, and comprises the following steps:
converting the resistivity curve of the specified well point into a pseudo-acoustic wave time difference curve;
and acquiring pseudo wave impedance by using the pseudo sound wave time difference curve.
The device of utilizing seismic data to predict total organic carbon content of hydrocarbon source rock of this application embodiment, will the resistivity curve of appointed well point converts the time difference curve in pseudo-acoustic wave into, includes:
according to the formula Δ t ═ KHCdRConverting the resistivity curve of the designated well point into a pseudo-acoustic wave time difference curve;
where Δ t' is the time difference of the pseudo-acoustic wave at the specified well point, K, d and C are constants, H is the depth of the specified well point, and R is the resistivity of the specified well point.
The device of utilizing seismic data to predict total organic carbon content of hydrocarbon source rock of this application embodiment, utilize pseudo-acoustic time difference curve obtains pseudo-wave impedance, includes:
according to the formulaAcquiring pseudo wave impedance;
wherein, CimprAnd the pseudo wave impedance of a specified well point in the work area is defined, rho is the density of the specified well point, and delta t' is the pseudo sound wave time difference of the specified well point.
The device for predicting the total organic carbon content of the hydrocarbon source rock by using the seismic data determines the total organic carbon content curve of the specified well point according to the following formula:
TOC＝10×(2.297-0.1688R0)×ΔlogR；
wherein TOC specifies the total organic carbon content, R, of the well point0For the resistivity corresponding to the baseline, Δ logR is the distance between the sonic moveout curve and the resistivity curve at the same depth, and Δ logR is log (R/R)0)+0.02(Δt-Δt0) R is measured resistivity, delta t is measured acoustic time difference, delta t0The acoustic moveout corresponding to the baseline.
In yet another aspect, an embodiment of the present application further provides an apparatus for predicting total organic carbon content of a source rock using seismic data, including a memory, a processor, and a computer program stored on the memory, the computer program when executed by the processor performing the steps of:
acquiring wave impedance according to an acoustic time difference curve of a specified well point in a work area, and acquiring pseudo wave impedance according to a resistivity curve of the specified well point;
determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance;
determining a total organic carbon content curve for the designated well point;
determining a relation curve of the first wave impedance difference value and the organic carbon content curve;
respectively utilizing the wave impedance and the pseudo wave impedance to carry out wave impedance inversion on the seismic data of the work area, and correspondingly obtaining a wave impedance inversion data body and a pseudo wave impedance inversion data body;
determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
and determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve.
According to the technical scheme provided by the embodiment of the application, the corresponding relation between the TOC and the wave impedance difference is obtained by utilizing the logging data of the specified well point in the work area, then the difference between the wave impedance and the pseudo wave impedance of the whole work area is obtained through the seismic data of the work area, and the TOC content of the whole work area is obtained by taking the difference between the wave impedance and the pseudo wave impedance of the whole work area as constraint information according to the corresponding relation. Because the constraint information in the embodiment of the application is derived from the seismic data of the work area, and the seismic data of the work area is an objective reaction of the comprehensive information of the underground of the work area, including lithology, fluid and the like, the embodiment of the application improves the prediction precision of the TOC content of the whole work area.
Drawings
In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort. In the drawings:
FIG. 1 is a flow chart of a method for predicting total organic carbon content of a source rock using seismic data in an embodiment of the present application;
FIG. 2 is a schematic diagram of a TOC curve illustrating the interpretation of acoustic moveout (Δ t), resistivity (R), acoustic moveout and resistivity folding, and overbrimming in an embodiment of the present application;
FIG. 3 is a graph illustrating resistivity (R), a pseudo-acoustic time difference (Δ tR) to which the resistivity is converted, and a pseudo-acoustic impedance curve (impR) to which the pseudo-acoustic time difference is converted according to an embodiment of the present disclosure;
FIG. 4 is a graph of the wave impedance (imp), the pseudo-wave impedance (impR), the superposition of the wave impedance and the pseudo-wave impedance, and the difference between the pseudo-wave impedance and the wave impedance (impR-imp) according to an embodiment of the present application;
FIG. 5 is a schematic diagram of the TOC intersection analysis of the difference curve of FIG. 4 of the present application;
FIG. 6 is a schematic cross-sectional view of a seismic inversion result obtained by performing wave impedance and pseudo-wave impedance inversion on wave impedance and pseudo-wave impedance, respectively, in an embodiment of the present application;
FIG. 7 is a difference profile (top graph in FIG. 7) obtained by subtracting the two inversion results in FIG. 6 and a TOC profile (bottom graph in FIG. 7) obtained by subtracting the difference profile and the relationship shown in FIG. 5 according to an embodiment of the present invention;
FIG. 8 is a block diagram of an apparatus for predicting total organic carbon content of a source rock using seismic data according to an embodiment of the present application;
FIG. 9 is a block diagram of an apparatus for predicting total organic carbon content of a source rock using seismic data according to another embodiment of the present application.
Detailed Description
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
Referring to fig. 1, a method for predicting total organic carbon content of a source rock using seismic data according to an embodiment of the present application may include:
s101, acquiring wave impedance according to an acoustic time difference curve of a designated well point in a work area, and acquiring pseudo wave impedance according to a resistivity curve of the designated well point.
In the embodiment of the present application, the specified well point in the work area may have logging information such as a resistivity curve (e.g., R in fig. 2), a sonic time difference curve (e.g., Δ t in fig. 2), and the like, that is, there is both resistivity logging data and sonic logging data at the same position in the work area. The pseudo wave impedance is a wave impedance obtained through a resistivity curve, and is different from a wave impedance obtained through an acoustic wave time difference curve.
In an embodiment of the present application, the obtaining of the wave impedance according to the acoustic moveout curve of the specified well point in the work area may include: according to the formulaObtaining wave impedance; wherein, CimpThe wave impedance (imp in fig. 3) of a specified well point in the work area is obtained, ρ is the density of the specified well point, and Δ t is the acoustic wave time difference of the specified well point.
In one embodiment of the present application, the obtaining of the pseudo-wave impedance according to the resistivity curve of the specified well point may include: converting the resistivity curve (e.g., R in FIG. 3) for the specified well point to a pseudo-sonic moveout curve (e.g., Δ tR in FIG. 3); then, the pseudo wave impedance (impR in fig. 3) is obtained by using the pseudo wave time difference curve. Wherein:
converting the resistivity curve of the specified well point into a pseudo-acoustic time difference curve, which can be represented by the formula Δ t ═ KHCdRAnd (5) realizing. Where Δ t' is the time difference of the pseudo-acoustic wave at the specified well point, K, d and C are constants, H is the depth of the specified well point, and R is the resistivity of the specified well point. The pseudo wave impedance obtained by the pseudo sound wave time difference curve can be obtained according to a formulaAnd (5) realizing. Wherein, CimprAnd the pseudo wave impedance of a specified well point in the work area is defined, rho is the density of the specified well point, and delta t' is the pseudo sound wave time difference of the specified well point.
S102, determining a first wave impedance difference value of the wave impedance and the pseudo wave impedance.
In the embodiment of the present application, a first wave impedance difference between the wave impedance and the pseudo wave impedance may be determined by superimposing a wave impedance curve and a pseudo wave impedance curve (as shown in fig. 4, imp is a wave impedance curve and impR is a pseudo wave impedance curve).
S103, determining a total organic carbon content curve of the specified well point.
In the embodiment of the present application, a resistivity curve of a specified well point in a work area is superimposed on an acoustic time difference curve, so as to obtain a total organic carbon content curve (as shown in TOC in fig. 2) of the specified well point. After superposition, when the resistivity and the acoustic wave time difference are completely superposed for a certain depth, the total organic carbon content of the source rock at the position is zero (or the position does not contain TOC); for a certain depth, when the resistivity is misaligned with the acoustic wave time difference, the TOC is remained at the position, and the more the misalignment is serious, the more the reaction is corresponding to the remained TOC. Therefore, the resistivity curve and the acoustic wave time difference curve of the same designated well point in the work area are superposed, and whether TOC and the remaining situation remain at each depth of the designated well point can be judged.
Specifically, in one embodiment of the present application, the determining of the total of the specified well pointsThe organic carbon content curve can be determined according to the formula TOC 10 × (2.297-0.1688R)0) X Δ logR.
Wherein TOC specifies the total organic carbon content, R, of the well point0For the resistivity corresponding to the baseline, Δ logR is the distance between the sonic moveout curve and the resistivity curve at the same depth, and Δ logR is log (R/R)0)+0.02(Δt-Δt0) R is measured resistivity, delta t is measured acoustic time difference, delta t0The acoustic moveout corresponding to the baseline.
In other embodiments of the present application, the TOC is 10 × (2.297-0.1688R) as required0) X Δ logR can also be simplified to TOC ═ a Δ logR, where a is a coefficient.
S104, determining a relation curve of the first wave impedance difference value and the organic carbon content curve.
In this embodiment, by intersecting the first wave impedance difference with the TOC curve, a relationship curve TOC f (C) between the first wave impedance difference and the TOC curve can be fittedimpr-Cimp) (as shown by the curve in fig. 5). The relationship curve reflects the correspondence between TOC and the first wave impedance difference.
And S105, performing wave impedance inversion on the seismic data of the work area by respectively using the wave impedance and the pseudo wave impedance to correspondingly obtain a wave impedance inversion data body and a pseudo wave impedance inversion data body.
In the embodiment of the application, the seismic data of the work area are objective reactions of comprehensive information including lithology, fluid and the like in the underground work area, and form the constraint of the whole block surface. And respectively utilizing the wave impedance and the pseudo wave impedance to carry out wave impedance inversion on the seismic data of the work area, and correspondingly obtaining a wave impedance inversion data body and a pseudo wave impedance inversion data body (as shown in figure 6). Therefore, the difference value between the wave impedance inversion data body and the pseudo wave impedance inversion data body in the embodiment of the application reflects the situation of the whole work area, so that the subsequent calculation of the difference value between the wave impedance and the pseudo wave impedance of the whole block surface is facilitated.
S106, determining a second wave impedance difference value of the wave impedance inversion data body and the pseudo wave impedance inversion data body.
In an embodiment of the present application, a second wave impedance difference value between the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume may be determined by superimposing the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume (as shown in the upper diagram of fig. 7).
And S107, determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve.
In the embodiment of the present application, since there is a correspondence between TOC and the wave impedance difference as described above, the second wave impedance difference is used as an input, and TOC ═ f (C) is substituted into the second wave impedance differenceimpr-Cimp) And (4) obtaining the total organic carbon content of the hydrocarbon source rock of the whole work area according to the relation curve (shown in the lower graph in figure 7). Therefore, according to the method and the device, the corresponding relation between the TOC and the wave impedance difference is obtained by utilizing the logging data of the specified well point in the work area, then the difference between the wave impedance and the pseudo wave impedance of the whole work area is obtained through the seismic data of the work area, and the TOC content of the whole work area is obtained by taking the difference between the wave impedance and the pseudo wave impedance of the whole work area as constraint information according to the corresponding relation. Because the constraint information in the embodiment of the application is derived from the seismic data of the work area, and the seismic data of the work area is an objective reaction of the comprehensive information of the underground of the work area, including lithology, fluid and the like, the embodiment of the application improves the prediction precision of the TOC content of the whole work area.
While the process flows described above include operations that occur in a particular order, it should be appreciated that the processes may include more or less operations that are performed sequentially or in parallel (e.g., using parallel processors or a multi-threaded environment).
Referring to fig. 8, an apparatus for predicting total organic carbon content of a source rock using seismic data according to an embodiment of the present application may include:
the wave impedance obtaining module 81 may be configured to obtain wave impedance according to an acoustic time difference curve of a specified well point in a work area, and obtain pseudo-wave impedance according to a resistivity curve of the specified well point;
a first wave impedance difference determination module 82 operable to determine a first wave impedance difference of the wave impedance and the pseudo-wave impedance;
a single point content determination module 83 operable to determine a total organic carbon content curve for the specified well point;
a correlation determination module 84 operable to determine a correlation of the first wave impedance difference value with the organic carbon content curve;
the wave impedance inversion module 85 may be configured to perform wave impedance inversion on the seismic data of the work area by using the wave impedance and the pseudo wave impedance, respectively, so as to obtain a wave impedance inversion data volume and a pseudo wave impedance inversion data volume correspondingly;
a second wave impedance difference determination module 86, which may be configured to determine a second wave impedance difference between the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
and the total content determining module 87 may be configured to determine a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve.
The apparatus of the embodiment of the present application corresponds to the method of the embodiment, and therefore, for details of the apparatus of the present application, please refer to the method of the embodiment, which is not described herein again.
Referring to fig. 9, an apparatus for predicting total organic carbon content of a source rock using seismic data according to an embodiment of the present application may include a memory, a processor, and a computer program stored on the memory, the computer program when executed by the processor performing the steps of:
acquiring wave impedance according to an acoustic time difference curve of a specified well point in a work area, and acquiring pseudo wave impedance according to a resistivity curve of the specified well point;
determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance;
determining a total organic carbon content curve for the designated well point;
determining a relation curve of the first wave impedance difference value and the organic carbon content curve;
respectively utilizing the wave impedance and the pseudo wave impedance to carry out wave impedance inversion on the seismic data of the work area, and correspondingly obtaining a wave impedance inversion data body and a pseudo wave impedance inversion data body;
determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
and determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve.
The apparatus of the embodiment of the present application corresponds to the method of the embodiment, and therefore, for details of the apparatus of the present application, please refer to the method of the embodiment, which is not described herein again.
For convenience of description, the above devices are described as being divided into various units by function, and are described separately. Of course, the functionality of the units may be implemented in one or more software and/or hardware when implementing the present application.
The present invention is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
In a typical configuration, a computing device includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory.
The memory may include forms of volatile memory in a computer readable medium, Random Access Memory (RAM) and/or non-volatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). Memory is an example of a computer-readable medium.
Computer-readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), Static Random Access Memory (SRAM), Dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), Read Only Memory (ROM), Electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), Digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information that can be accessed by a computing device. As defined herein, a computer readable medium does not include a transitory computer readable medium such as a modulated data signal and a carrier wave.
It should also be noted that the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising an … …" does not exclude the presence of other like elements in a process, method, article, or apparatus that comprises the element.
As will be appreciated by one skilled in the art, embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, for the system embodiment, since it is substantially similar to the method embodiment, the description is simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The above description is only an example of the present application and is not intended to limit the present application. Various modifications and changes may occur to those skilled in the art. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application should be included in the scope of the claims of the present application.
Claims (11)
1. A method for predicting total organic carbon content of a source rock using seismic data, comprising:
acquiring wave impedance according to an acoustic time difference curve of a specified well point in a work area, and acquiring pseudo wave impedance according to a resistivity curve of the specified well point;
determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance;
determining a total organic carbon content curve for the designated well point;
determining a relation curve of the first wave impedance difference value and the total organic carbon content curve;
respectively utilizing the wave impedance and the pseudo wave impedance to carry out wave impedance inversion on the seismic data of the work area, and correspondingly obtaining a wave impedance inversion data body and a pseudo wave impedance inversion data body;
determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve; wherein,
the wave impedance is a wave impedance curve, and the pseudo wave impedance is a pseudo wave impedance curve;
the determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance comprises:
superposing the wave impedance curve and the pseudo wave impedance curve to obtain a superposed curve, wherein the superposed curve comprises a first wave impedance difference value;
the determining of the total organic carbon content curve for the specified well point comprises:
superposing a resistivity curve of a designated well point in a work area with an acoustic time difference curve to obtain a total organic carbon content curve of the designated well point;
the determining a relationship curve of the first wave impedance difference value and the total organic carbon content curve comprises:
intersecting the first wave impedance difference value with the total organic carbon content curve, and fitting a relation curve of the first wave impedance difference value and the total organic carbon content curve;
the determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume comprises:
superposing the wave impedance inversion data volume and the pseudo wave impedance inversion data volume to obtain a superposed data volume, wherein the superposed data volume comprises a second wave impedance difference value;
determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve, wherein the determination comprises the following steps:
and substituting the second wave impedance difference value into the relation curve to obtain a hydrocarbon source rock total organic carbon content data body of the work area.
2. The method for predicting total organic carbon content of a source rock using seismic data as claimed in claim 1 wherein said obtaining wave impedance from sonic moveout curves for a specified well point in a work area comprises:
according to the formulaObtaining wave impedance;
wherein, CimpAnd the wave impedance of a designated well point in the work area is defined, rho is the density of the designated well point, and delta t is the acoustic wave time difference of the designated well point.
3. The method for predicting total organic carbon content of a hydrocarbon source rock using seismic data as claimed in claim 1 wherein said obtaining pseudo wave impedance from said resistivity curve for said specified well point comprises:
converting the resistivity curve of the specified well point into a pseudo-acoustic wave time difference curve;
and acquiring pseudo wave impedance by using the pseudo sound wave time difference curve.
4. The method of predicting total organic carbon content of a source rock using seismic data as claimed in claim 3 wherein said converting the resistivity curve for said specified well point to a pseudo-acoustic time difference curve comprises:
according to the formula Δ t ═ KHCdRConverting the resistivity curve of the designated well point into a pseudo-acoustic wave time difference curve;
where Δ t' is the time difference of the pseudo-acoustic wave at the specified well point, K, d and C are constants, H is the depth of the specified well point, and R is the resistivity of the specified well point.
5. The method for predicting the total organic carbon content of a hydrocarbon source rock according to the seismic data, wherein the step of obtaining the pseudo wave impedance by using the pseudo acoustic moveout curve comprises the following steps:
according to the formulaAcquiring pseudo wave impedance;
wherein, CimprAnd the pseudo wave impedance of a specified well point in the work area is defined, rho is the density of the specified well point, and delta t' is the pseudo sound wave time difference of the specified well point.
6. An apparatus for predicting total organic carbon content of a source rock using seismic data, comprising:
the wave impedance obtaining module is used for obtaining wave impedance according to an acoustic time difference curve of a specified well point in a work area and obtaining pseudo wave impedance according to a resistivity curve of the specified well point;
a first wave impedance difference determination module for determining a first wave impedance difference between the wave impedance and the pseudo-wave impedance;
the single-point content determination module is used for determining a total organic carbon content curve of the specified well point;
a relation curve determining module for determining a relation curve of the first wave impedance difference value and the total organic carbon content curve;
the wave impedance inversion module is used for performing wave impedance inversion on the seismic data of the work area by respectively utilizing the wave impedance and the pseudo wave impedance to correspondingly obtain a wave impedance inversion data body and a pseudo wave impedance inversion data body;
a second wave impedance difference determination module for determining a second wave impedance difference between the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
the total content determining module is used for determining a hydrocarbon source rock total organic carbon content data body of the work area according to the second wave impedance difference value and the relation curve; wherein,
the wave impedance is a wave impedance curve, and the pseudo wave impedance is a pseudo wave impedance curve;
the determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance comprises:
superposing the wave impedance curve and the pseudo wave impedance curve to obtain a superposed curve, wherein the superposed curve comprises a first wave impedance difference value;
the determining of the total organic carbon content curve for the specified well point comprises:
superposing a resistivity curve of a designated well point in a work area with an acoustic time difference curve to obtain a total organic carbon content curve of the designated well point;
the determining a relationship curve of the first wave impedance difference value and the total organic carbon content curve comprises:
intersecting the first wave impedance difference value with the total organic carbon content curve, and fitting a relation curve of the first wave impedance difference value and the total organic carbon content curve;
the determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume comprises:
superposing the wave impedance inversion data volume and the pseudo wave impedance inversion data volume to obtain a superposed data volume, wherein the superposed data volume comprises a second wave impedance difference value;
determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve, wherein the determination comprises the following steps:
and substituting the second wave impedance difference value into the relation curve to obtain a hydrocarbon source rock total organic carbon content data body of the work area.
7. The apparatus for predicting total organic carbon content of a source rock using seismic data as claimed in claim 6 wherein said obtaining wave impedance from sonic moveout curves for a specified well point in the work area comprises:
according to the formulaObtaining wave impedance;
wherein, CimpWave resistance for designated well point in work areaAnd p is the density of the specified well point, and delta t is the acoustic wave time difference of the specified well point.
8. The apparatus for predicting total organic carbon content of a source rock using seismic data as claimed in claim 6 wherein said obtaining pseudo wave impedance from said resistivity curve for said specified well point comprises:
converting the resistivity curve of the specified well point into a pseudo-acoustic wave time difference curve;
and acquiring pseudo wave impedance by using the pseudo sound wave time difference curve.
9. The apparatus for predicting total organic carbon content of a source rock using seismic data as claimed in claim 8 wherein said converting said resistivity curve for said specified well point to a pseudo-sonic time difference curve comprises:
according to the formula Δ t ═ KHCdRConverting the resistivity curve of the designated well point into a pseudo-acoustic wave time difference curve;
where Δ t' is the time difference of the pseudo-acoustic wave at the specified well point, K, d and C are constants, H is the depth of the specified well point, and R is the resistivity of the specified well point.
10. The apparatus for predicting total organic carbon content of a hydrocarbon source rock using seismic data as claimed in claim 8 or 9, wherein said obtaining pseudo wave impedance using said pseudo acoustic moveout curve comprises:
according to the formulaAcquiring pseudo wave impedance;
wherein, CimprAnd the pseudo wave impedance of a specified well point in the work area is defined, rho is the density of the specified well point, and delta t' is the pseudo sound wave time difference of the specified well point.
11. An apparatus for predicting total organic carbon content of a source rock using seismic data, comprising a memory, a processor, and a computer program stored on the memory, wherein the computer program when executed by the processor performs the steps of:
acquiring wave impedance according to an acoustic time difference curve of a specified well point in a work area, and acquiring pseudo wave impedance according to a resistivity curve of the specified well point;
determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance;
determining a total organic carbon content curve for the designated well point;
determining a relation curve of the first wave impedance difference value and the total organic carbon content curve;
respectively utilizing the wave impedance and the pseudo wave impedance to carry out wave impedance inversion on the seismic data of the work area, and correspondingly obtaining a wave impedance inversion data body and a pseudo wave impedance inversion data body;
determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume;
determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve; wherein,
the wave impedance is a wave impedance curve, and the pseudo wave impedance is a pseudo wave impedance curve;
the determining a first wave impedance difference of the wave impedance and the pseudo-wave impedance comprises:
superposing the wave impedance curve and the pseudo wave impedance curve to obtain a superposed curve, wherein the superposed curve comprises a first wave impedance difference value;
the determining of the total organic carbon content curve for the specified well point comprises:
superposing a resistivity curve of a designated well point in a work area with an acoustic time difference curve to obtain a total organic carbon content curve of the designated well point;
the determining a relationship curve of the first wave impedance difference value and the total organic carbon content curve comprises:
intersecting the first wave impedance difference value with the total organic carbon content curve, and fitting a relation curve of the first wave impedance difference value and the total organic carbon content curve;
the determining a second wave impedance difference value of the wave impedance inversion data volume and the pseudo-wave impedance inversion data volume comprises:
superposing the wave impedance inversion data volume and the pseudo wave impedance inversion data volume to obtain a superposed data volume, wherein the superposed data volume comprises a second wave impedance difference value;
determining a hydrocarbon source rock total organic carbon content data volume of the work area according to the second wave impedance difference value and the relation curve, wherein the determination comprises the following steps:
and substituting the second wave impedance difference value into the relation curve to obtain a hydrocarbon source rock total organic carbon content data body of the work area.
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