CN114002743A - Method and device for calculating reservoir thickness of natural gas hydrate - Google Patents
Method and device for calculating reservoir thickness of natural gas hydrate Download PDFInfo
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- CN114002743A CN114002743A CN202111220103.5A CN202111220103A CN114002743A CN 114002743 A CN114002743 A CN 114002743A CN 202111220103 A CN202111220103 A CN 202111220103A CN 114002743 A CN114002743 A CN 114002743A
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- G01—MEASURING; TESTING
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- 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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Abstract
The invention discloses a method and a device for calculating the reservoir thickness of a natural gas hydrate, wherein the method comprises the following steps: carrying out three-dimensional seismic data acquisition in a natural gas hydrate reservoir area, carrying out amplitude preservation processing on the acquired seismic data and carrying out superposition to obtain a post-stack seismic data volume; performing structural interpretation on the post-stack seismic data volume, and determining a top layer position and a bottom layer position of a stratum where the natural gas hydrate reservoir is located; cutting out a seismic data volume according to the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located to obtain a target seismic data volume; and obtaining the natural gas hydrate reservoir thickness between the top layer position and the bottom layer position. The invention discloses a method and a device for calculating the thickness of a natural gas hydrate reservoir, which are used for estimating the thickness of the marine natural gas hydrate reservoir aiming at the condition that the stratum containing the natural gas hydrate and the mudstone stratum are alternated in the marine natural gas hydrate reservoir in the same thickness, and solve the problem that the thickness of a thin interbed cannot be estimated, which always troubles exploration workers.
Description
Technical Field
The invention relates to the field of natural gas hydrate exploration, in particular to a method and a device for calculating reservoir thickness of a natural gas hydrate.
Background
Currently, a more common technique for calculating subsurface hydrocarbon reservoir thickness is to estimate using tuned thickness. Neidell et al have studied and given a definition of tuning thickness, that is, when a stratum with a thickness of lambda/4 (lambda is the wavelength of seismic wavelet) is embedded in a certain medium, the reflected wave generated from the top and bottom of the thin layer has strong coherence and the amplitude is strongest, and the thickness is the tuning thickness. When the thickness of the formation is equal to λ/4, not only does the amplitude maxima appear on the corresponding seismic record, but the peak moveout is exactly equal to the thickness of the formation.
Formation thickness calculations using tuned thicknesses are limited to thickness calculations for individual reservoirs, and accurate calculations are difficult to obtain for thin interbed cases, where gas hydrates often appear as thin interbed. Research is carried out aiming at the characteristics of the natural gas hydrate reservoir, and a method capable of accurately calculating the thickness of the natural gas hydrate reservoir is urgently needed to be established.
Disclosure of Invention
The invention aims to provide a method for calculating the reservoir thickness of a natural gas hydrate, which is used for solving the problem of inaccurate calculation of the reservoir thickness of the natural gas hydrate.
The invention provides a method for calculating the reservoir thickness of a natural gas hydrate, which comprises the following steps:
carrying out three-dimensional seismic data acquisition in a natural gas hydrate reservoir area, carrying out amplitude preservation processing on the acquired seismic data and stacking to obtain a post-stack seismic data volume;
performing structural interpretation on the post-stack seismic data volume, and determining a top layer position and a bottom layer position of a stratum where the natural gas hydrate reservoir is located;
cutting out a seismic data volume according to the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located to obtain a target seismic data volume;
and establishing a calculation equation of the time thickness of the natural gas hydrate stratum, substituting the target seismic data volume into the calculation equation of the time thickness of the natural gas hydrate stratum, calculating the time thickness of the natural gas hydrate stratum, converting the time thickness of the natural gas hydrate stratum into the natural gas hydrate reservoir thickness, and obtaining the natural gas hydrate reservoir thickness between the top layer position and the bottom layer position.
Specifically, the calculation equation of the time thickness of the gas hydrate formation is:
wherein d istTime thickness of natural gas hydrate reservoir, f0The first peak of the spectrum corresponds to a frequency.
Specifically, the calculating the time thickness of the natural gas hydrate formation specifically includes the steps of:
converting the target seismic data volume into a time-frequency domain, and extracting the frequency f corresponding to the first peak of the frequency spectrum0The data volume of (2) is substituted into the calculation equation of the time thickness of the natural gas hydrate stratum to obtain the time thickness of the natural gas hydrate reservoir.
The invention also relates to a device for calculating the reservoir thickness of the natural gas hydrate, which comprises
The first processing unit is used for carrying out three-dimensional seismic data acquisition in a natural gas hydrate reservoir region, carrying out amplitude preservation processing on the acquired seismic data and carrying out superposition to obtain a post-stack seismic data volume;
the second processing unit is used for carrying out construction and interpretation on the stacked seismic data volume and determining the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located;
the third processing unit is used for cutting out a seismic data volume according to the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located to obtain a target seismic data volume;
and the fourth processing unit is used for establishing a calculation equation of the time thickness of the natural gas hydrate stratum, substituting the target seismic data volume into the calculation equation of the time thickness of the natural gas hydrate stratum, calculating the time thickness of the natural gas hydrate stratum, converting the time thickness of the natural gas hydrate stratum into the natural gas hydrate reservoir thickness, and obtaining the natural gas hydrate reservoir thickness between the top layer and the bottom layer.
The invention also relates to a computer-readable storage medium, on which a computer program is stored which, when being executed by a processor, carries out the steps of the above-mentioned method.
The invention also relates to a computer arrangement comprising a memory, a processor and a computer program stored on the memory and executable on the processor, the processor implementing the steps of the above method when executing the computer program.
Compared with the prior art, the invention has the beneficial effects that:
the invention discloses a method for calculating the reservoir thickness of a natural gas hydrate, which aims at the condition that a stratum containing the natural gas hydrate and a mudstone stratum are alternated in the same thickness frequently in a marine natural gas hydrate reservoir, can be applied to calculating the thickness of the marine natural gas hydrate reservoir and solves the problem that the thickness of a thin interbed cannot be accurately calculated, which always troubles exploration workers.
Drawings
Fig. 1 is a flowchart of a method for calculating a natural gas hydrate reservoir thickness according to embodiment 1 of the present invention.
Detailed Description
The following examples are intended to illustrate the invention but are not intended to limit the scope of the invention.
Example 1
Example 1 provides a method for calculating a natural gas hydrate reservoir thickness, and referring to fig. 1, the method includes the steps of:
step A: carrying out three-dimensional seismic data acquisition in a natural gas hydrate reservoir area, carrying out amplitude preservation processing on the acquired seismic data and carrying out superposition to obtain a post-stack seismic data volume;
and B: performing structural interpretation on the post-stack seismic data volume, and determining the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located;
and C: cutting out a seismic data volume according to the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located to obtain a target seismic data volume;
step D: and establishing a calculation equation of the time thickness of the natural gas hydrate stratum, substituting the target seismic data volume into the calculation equation of the time thickness of the natural gas hydrate stratum, calculating the time thickness of the natural gas hydrate stratum, converting the time thickness of the natural gas hydrate stratum into the natural gas hydrate reservoir thickness, and obtaining the natural gas hydrate reservoir thickness between the top layer position and the bottom layer position.
The method comprises the following steps:
step D1: establishing a calculation equation of the time thickness of the natural gas hydrate formation,
the calculation equation of the time thickness of the natural gas hydrate formation is as follows:
wherein d istTime thickness of natural gas hydrate reservoir, f0The first peak of the spectrum corresponds to a frequency.
Hypothetical conditions for the calculation equation for time thickness of a gas hydrate formation:
the frequency depression of the single lamina on the frequency spectrum of the seismic response has a functional relation with the lamina thickness, and the periodic frequency depression phenomenon also exists in the thin interbed. Therefore, the assumed conditions that the calculation formula of the time thickness of the natural gas hydrate formation should satisfy for the thin interbed are:
the absolute values of the reflection coefficients are considered to be the same under the assumption that the size of the interface reflection coefficient is not considered;
(II) assuming that the time thickness of each layer of double-pass travel between the top layer position and the bottom layer position is equal, and forming the equal time thickness of the target seismic data body;
(iii) assume that the sampling interval is equal to the temporal thickness.
(ii) interpretation of the equation for calculating time thickness of the gas hydrate formation:
a. when the reflection coefficients of two adjacent surfaces are opposite in positive and negative, calculating the thickness of the natural gas hydrate stratum between the top layer position and the bottom layer position, and setting a single seismic data in the target seismic data volume as x (nd)t) The spectrum x (f) is calculated by the formula:
in the formula (d)tThe time thickness of the natural gas hydrate stratum is shown, n represents the number of interfaces in the stratum, and f is the frequency corresponding to the frequency spectrum peak.
(equation 2) is a periodic function, and the difference Δ f between two extreme frequencies in the frequency spectrum is:
in the formula (f)n+1And fnRepresents twoThe extremal frequency of the adjacent interfaces;
dtexpressed as the time thickness of the natural gas hydrate formation;
n represents the number of interfaces in the formation.
b. Calculating the thickness of the natural gas hydrate reservoir between the top horizon and the bottom horizon when the stratum reflection coefficients are all homodromous, and calculating the expression of the frequency spectrum X (f) of the single-channel seismic data:
the (equation 4) is also a periodic function, and still satisfies the (equation 3).
Thus, the time thickness versus frequency of the gas hydrate formation may be calculated from (equation 1).
Step D2: calculating the time thickness of the natural gas hydrate formation, specifically comprising the steps of:
converting the target seismic data volume into a time-frequency domain, substituting the time-frequency domain into a calculation model of the time thickness of the natural gas hydrate stratum, and extracting the frequency f corresponding to the first peak value of the frequency spectrum0The time thickness of the gas hydrate formation is obtained.
Step D3: and converting the time thickness of the natural gas hydrate stratum into the natural gas hydrate reservoir thickness to obtain the natural gas hydrate reservoir thickness between the top layer position and the bottom layer position.
The method for calculating the natural gas hydrate reservoir thickness disclosed by the invention is applied to ocean oil gas, and can well solve the problem of natural gas hydrate reservoir thickness prediction.
Although the invention has been described in detail above with reference to a general description and specific examples, it will be apparent to one skilled in the art that modifications or improvements may be made thereto based on the invention. Accordingly, such modifications and improvements are intended to be within the scope of the invention as claimed.
Claims (6)
1. A method for calculating the reservoir thickness of a natural gas hydrate is characterized by comprising the following steps:
carrying out three-dimensional seismic data acquisition in a natural gas hydrate reservoir area, carrying out amplitude preservation processing on the acquired seismic data and carrying out superposition to obtain a post-stack seismic data volume;
performing structural interpretation on the post-stack seismic data volume, and determining a top layer position and a bottom layer position of a stratum where the natural gas hydrate reservoir is located;
cutting out a seismic data volume according to the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located to obtain a target seismic data volume;
and establishing a calculation equation of the time thickness of the natural gas hydrate stratum, substituting the target seismic data volume into the calculation equation of the time thickness of the natural gas hydrate stratum, calculating the time thickness of the natural gas hydrate stratum, converting the time thickness of the natural gas hydrate stratum into the natural gas hydrate reservoir thickness, and obtaining the natural gas hydrate reservoir thickness between the top layer position and the bottom layer position.
2. The method of calculating a natural gas hydrate reservoir thickness as claimed in claim 1,
the calculation equation of the time thickness of the natural gas hydrate formation is as follows:
wherein d istTime thickness of natural gas hydrate reservoir, f0The first peak of the spectrum corresponds to a frequency.
3. The method of calculating a natural gas hydrate reservoir thickness as claimed in claim 2,
the calculating the time thickness of the natural gas hydrate formation specifically includes the steps of:
converting the target seismic data volume into a time-frequency domain, and extracting the frequency f corresponding to the first peak of the frequency spectrum0Data volume of substituting said natural gasAnd obtaining the time thickness of the natural gas hydrate reservoir in the calculation equation of the time thickness of the hydrate stratum.
4. A device for calculating the reservoir thickness of natural gas hydrate is characterized by comprising
The first processing unit is used for carrying out three-dimensional seismic data acquisition in a natural gas hydrate reservoir region, carrying out amplitude preservation processing on the acquired seismic data and carrying out superposition to obtain a post-stack seismic data volume;
the second processing unit is used for performing structural interpretation on the stacked seismic data volume and determining a top layer position and a bottom layer position of a stratum where the natural gas hydrate reservoir is located;
the third processing unit is used for cutting out a seismic data volume according to the top layer position and the bottom layer position of the stratum where the natural gas hydrate reservoir is located to obtain a target seismic data volume;
and the fourth processing unit is used for establishing a calculation equation of the time thickness of the natural gas hydrate stratum, substituting the target seismic data volume into the calculation equation of the time thickness of the natural gas hydrate stratum, calculating the time thickness of the natural gas hydrate stratum, converting the time thickness of the natural gas hydrate stratum into the natural gas hydrate reservoir thickness and obtaining the natural gas hydrate reservoir thickness between the top layer position and the bottom layer position.
5. A computer-readable storage medium, on which a computer program is stored, which, when being executed by a processor, carries out the steps of the method according to any one of claims 1 to 3.
6. A computer device comprising a memory, a processor and a computer program stored on the memory and executable on the processor, characterized in that the steps of the method of any of claims 1-3 are implemented when the computer program is executed by the processor.
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