CN114137015B - Porosity correction method and device - Google Patents
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- 238000000034 method Methods 0.000 title claims abstract description 41
- 238000012937 correction Methods 0.000 title claims abstract description 39
- 238000001228 spectrum Methods 0.000 claims abstract description 93
- 239000012530 fluid Substances 0.000 claims abstract description 87
- 239000007789 gas Substances 0.000 claims abstract description 74
- 238000009826 distribution Methods 0.000 claims abstract description 68
- 238000005259 measurement Methods 0.000 claims abstract description 63
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract description 39
- 239000001257 hydrogen Substances 0.000 claims abstract description 39
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract description 39
- 230000003595 spectral effect Effects 0.000 claims abstract description 35
- 238000005481 NMR spectroscopy Methods 0.000 claims abstract description 18
- 238000004891 communication Methods 0.000 claims description 16
- 239000007788 liquid Substances 0.000 claims description 16
- 230000015572 biosynthetic process Effects 0.000 claims description 8
- 238000001514 detection method Methods 0.000 claims description 6
- 238000003860 storage Methods 0.000 claims description 4
- 238000009825 accumulation Methods 0.000 claims description 2
- 238000005755 formation reaction Methods 0.000 description 7
- 238000010586 diagram Methods 0.000 description 6
- 238000005516 engineering process Methods 0.000 description 5
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 238000004364 calculation method Methods 0.000 description 2
- 238000004590 computer program Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000003208 petroleum Substances 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 238000004458 analytical method Methods 0.000 description 1
- 230000009918 complex formation Effects 0.000 description 1
- 238000010276 construction Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development Methods 0.000 description 1
- 230000006870 function Effects 0.000 description 1
- 238000000655 nuclear magnetic resonance spectrum Methods 0.000 description 1
- 230000005311 nuclear magnetism Effects 0.000 description 1
- 239000003921 oil Substances 0.000 description 1
- 238000011022 operating instruction Methods 0.000 description 1
- 230000035699 permeability Effects 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000004451 qualitative analysis Methods 0.000 description 1
- 238000011084 recovery Methods 0.000 description 1
- 238000000926 separation method Methods 0.000 description 1
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- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N24/00—Investigating or analyzing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects
- G01N24/08—Investigating or analyzing materials by the use of nuclear magnetic resonance, electron paramagnetic resonance or other spin effects by using nuclear magnetic resonance
- G01N24/081—Making measurements of geologic samples, e.g. measurements of moisture, pH, porosity, permeability, tortuosity or viscosity
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- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02A—TECHNOLOGIES FOR ADAPTATION TO CLIMATE CHANGE
- Y02A90/00—Technologies having an indirect contribution to adaptation to climate change
- Y02A90/30—Assessment of water resources
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Abstract
The embodiment of the invention discloses a porosity correction method and a device, wherein the method comprises the following steps: detecting fluid information of a stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum; according to the multidimensional nuclear magnetic measurement spectrum, separating and determining each fluid signal, and performing horizontal axis projection to obtain the spectrum distribution of each fluid signal; carrying out hydrogen index correction on the spectral distribution of the gas serving as the fluid signal to obtain corrected spectral distribution of the gas; and accumulating the corrected spectral distribution of the gas and the spectral distribution of other fluid signals to obtain an integral sum which is used as the corrected porosity. The invention can assist in identifying fluid by utilizing the multidimensional nuclear magnetic measurement spectrum, is convenient for correcting the spectrum distribution of gas, and accurately obtains the corrected porosity.
Description
Technical Field
The embodiment of the invention relates to the field of petroleum exploration, in particular to a porosity correction method and device.
Background
Nuclear magnetic resonance logging technology is widely applied to the field of petroleum exploration, can be used for nondestructively intervening detection of the fluid information of a stratum, and calculates important stratum information such as porosity, permeability and the like based on a nuclear magnetic transverse relaxation time T2 spectrum of fluid of the measured stratum.
With the development of technology, one-dimensional nuclear magnetic logging technology has not satisfied the measurement needs of complex formations. The existing one-dimensional nuclear magnetic logging technology measures the T2 nuclear magnetic spectrum of the hydrogen-containing fluid, is used for identifying and analyzing the formation indiscriminate fluid, and has poor fluid auxiliary identification effect. The hydrogen indices of liquids and gases in actual formations are inconsistent, and so there is often a large difference in calculated porosity. As shown in fig. 1, the T2 nuclear magnetic spectrum of a hydrogen-containing gas such as methane overlaps with the T2 nuclear magnetic spectrum of a hydrogen-containing liquid such as water, oil, or the like, and qualitative analysis is possible by using a difference spectrum method, but the effect of the analysis does not truly reflect the formation porosity characteristics.
Disclosure of Invention
In view of the foregoing, embodiments of the present invention have been developed to provide a method and apparatus for correcting porosity that overcome, or at least partially solve, the foregoing problems.
According to an aspect of an embodiment of the present invention, there is provided a porosity correction method including:
Detecting fluid information of a stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum;
according to the multidimensional nuclear magnetic measurement spectrum, separating and determining each fluid signal, and performing horizontal axis projection to obtain the spectrum distribution of each fluid signal;
carrying out hydrogen index correction on the spectral distribution of the gas serving as the fluid signal to obtain corrected spectral distribution of the gas;
and accumulating the corrected spectral distribution of the gas and the spectral distribution of other fluid signals to obtain an integral sum which is used as the corrected porosity.
According to another aspect of an embodiment of the present invention, there is provided a porosity correction device including:
the detection module is suitable for detecting the fluid information of the stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum;
The projection module is suitable for separating and determining each fluid signal according to the multidimensional nuclear magnetic measurement spectrum, and performing horizontal axis projection to obtain the spectrum distribution of each fluid signal;
The correction module is suitable for carrying out hydrogen index correction on the spectral distribution of the gas serving as the fluid signal to obtain corrected spectral distribution of the gas;
And the accumulation module is suitable for accumulating the corrected spectral distribution of the gas and the spectral distribution of other fluid signals to obtain an integral sum which is used as the corrected porosity.
According to yet another aspect of an embodiment of the present invention, there is provided a computing device including: the device comprises a processor, a memory, a communication interface and a communication bus, wherein the processor, the memory and the communication interface complete communication with each other through the communication bus;
The memory is used for storing at least one executable instruction, and the executable instruction enables the processor to execute the operation corresponding to the porosity correction method.
According to still another aspect of the embodiments of the present invention, there is provided a computer storage medium having stored therein at least one executable instruction for causing a processor to perform operations corresponding to the porosity correction method described above.
According to the porosity correction method and device provided by the embodiment of the invention, the fluid can be identified in an auxiliary way by utilizing the multidimensional nuclear magnetic measurement spectrum, so that the spectrum distribution of the gas can be corrected conveniently, and the corrected porosity can be obtained accurately.
The foregoing description is only an overview of the technical solutions of the embodiments of the present invention, and may be implemented according to the content of the specification, so that the technical means of the embodiments of the present invention can be more clearly understood, and the following specific implementation of the embodiments of the present invention will be more apparent.
Drawings
Various other advantages and benefits will become apparent to those of ordinary skill in the art upon reading the following detailed description of the preferred embodiments. The drawings are only for purposes of illustrating the preferred embodiments and are not to be construed as limiting the invention. Also, like reference numerals are used to designate like parts throughout the figures. In the drawings:
FIG. 1 shows a schematic diagram of a one-dimensional nuclear magnetic log T2 spectrum hydrogen-containing liquid and hydrogen-containing gas distribution;
FIG. 2 shows a flow chart of a porosity correction method according to one embodiment of the invention;
FIG. 3 shows a schematic diagram of a T1-T2 multi-dimensional nuclear magnetic measurement spectrum;
FIG. 4 shows a schematic diagram of a T1/T2-T2 multi-dimensional nuclear magnetic measurement spectrum;
FIG. 5 shows a schematic view of a multi-dimensional nuclear magnetic measurement spectrum cross-axis projection;
FIG. 6 shows a schematic view of a horizontal axis projection after correction of the spectral distribution of the gas signal;
FIG. 7 shows a schematic structural view of a porosity correction device according to an embodiment of the present invention;
FIG. 8 illustrates a schematic diagram of a computing device, according to one embodiment of the invention.
Detailed Description
Exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. While exemplary embodiments of the present invention are shown in the drawings, it should be understood that the present invention may be embodied in various forms and should not be limited to the embodiments set forth herein. Rather, these embodiments are provided so that this disclosure will be thorough and complete, and will fully convey the scope of the invention to those skilled in the art.
FIG. 2 shows a flow chart of a porosity correction method according to one embodiment of the invention, as shown in FIG. 2, comprising the steps of:
Step S201, detecting fluid information of a stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum.
The nuclear magnetic logging technology can be used for nondestructively and intervally detecting formation fluid information, the embodiment utilizes a multi-polarization time measurement mode of nuclear magnetic resonance equipment to detect the fluid information of the formation with the gas layer to be detected, and specifically detects the content of hydrogen atoms, namely the hydrogen content of each fluid in the formation with the gas layer to be detected, so as to obtain a corresponding multidimensional nuclear magnetic measurement spectrum. The multi-dimensional nuclear magnetic measurement spectrum includes a longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum as shown in fig. 3, or a longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectrum as shown in fig. 4. The multi-dimensional nuclear magnetic measurement spectrum can effectively measure T1 and T2 through the hydrogen content of each fluid detected by a nuclear magnetic measurement mode with multi-polarization time, and based on the nuclear magnetic resonance principle, the T1-T2 nuclear magnetic measurement spectrum or the T1/T2-T2 nuclear magnetic measurement spectrum is obtained through calculation.
Step S202, according to the multidimensional nuclear magnetic measurement spectrum, separating and determining each fluid signal, and performing horizontal axis projection to obtain the spectrum distribution of each fluid signal.
The longitudinal relaxation time T1 of different fluids in the multidimensional nuclear magnetic measurement spectrum is different, and the T1-T2 nuclear magnetic measurement spectrum or the T1/T2-T2 nuclear magnetic measurement spectrum is utilized, so that the identification and separation of various fluid signals are facilitated. The fluid signal includes, for example, a gaseous fluid signal and a liquid fluid signal. As shown in fig. 3, the longitudinal relaxation time T1 of the hydrogen-containing gas, such as methane, is larger than the longitudinal relaxation time T1 of the hydrogen-containing liquid, and the fluid signal corresponding to the maximum longitudinal relaxation time T1 can be determined to be the gas signal by comparing the longitudinal relaxation times T1 of the fluid signals in the nuclear magnetic measurement spectra of T1-T2, that is, the hydrogen-containing gas signal is distributed at the upper left in fig. 3. For the T1/T2-T2 nuclear magnetic measurement spectrum of FIG. 4, the larger the T1/T2 value, the more hydrogen-containing gas signal is distributed over the T1/T2-T2 nuclear magnetic measurement spectrum.
The horizontal axis projection is performed on the different fluid signal distributions in fig. 3 and 4 to obtain the spectrum distribution of each fluid signal, as shown in fig. 5, the T2 spectrum distribution corresponding to the hydrogen-containing liquid and the T2 spectrum distribution corresponding to the hydrogen-containing gas are obtained, and the total nuclear magnetic resonance spectrum is the spectrum distribution obtained by accumulating the two.
Step S203, hydrogen index correction is performed on the spectral distribution of the gas, which is the fluid signal, to obtain corrected spectral distribution of the gas.
The nuclear magnetism is used for reflecting the pore size of the existence fluid, compared with the liquid and the gas with the same pore, the gas signal is much smaller, namely the existence volume of the gas signal content obtained by actual measurement is larger than the T2 spectrum distribution projection of the hydrogen-containing gas in fig. 5, the spectrum distribution of the fluid signal as the gas is required, and the hydrogen-containing index correction is carried out on the spectrum distribution of the gas at each depth point according to the hydrogen-containing index formula under different temperature/pressure conditions.
Specifically, according to the hydrogen index formula under different temperature/pressure conditions, for example, calPorosity = MeasurePorosity ×f (T, P) is adopted, where CalPorosity is a corrected gas spectrum distribution, measurePorosity is a gas spectrum distribution actually measured by using nuclear magnetic logging, and f (T, P) is a function relation with respect to temperature and pressure, an existing temperature and pressure empirical formula can be adopted, which is not limited herein. The volume of the gas signal corresponding to the spectrum distribution of the gas obtained by actual measurement is converted into the liquid with the same volume by adopting the formula aiming at each depth point, and the signal recovery is carried out according to the liquid with the same volume, so as to obtain the corrected spectrum distribution of the gas.
Step S204, the corrected spectral distribution of the gas is accumulated with the spectral distribution of other fluid signals to obtain an integral sum as the corrected porosity.
The Hydrogen Index (HI) is an inherent property of a hydrogen-containing fluid, and is the ratio of the number of hydrogen atoms per unit volume of fluid to the number of hydrogen atoms per unit volume of pure water under standard conditions. The hydrogen index determines the number of effective porosities in the formation. The corrected spectral distribution of the gas in fig. 6 is summed with the spectral distribution of the other fluid signal (hydrogen-containing liquid) to obtain an integrated sum as corrected porosity, i.e., the corrected nuclear magnetic resonance total spectrum of the hydrogen-containing index is the corrected porosity.
In the field of nuclear magnetic resonance multiphase fluid metering, the hydrogen index relates to the proportion calculation of each phase component of oil, water and gas mixed fluid, and the result is directly used for evaluating the influence on the oil production and gas production of an oil-gas well. The embodiment corrects the spectrum distribution of the gas and ensures the accuracy of the porosity finally obtained.
According to the porosity correction method provided by the embodiment of the invention, the fluid can be identified in an auxiliary way by utilizing the multidimensional nuclear magnetic measurement spectrum, so that the spectrum distribution of the gas can be corrected conveniently, and the corrected porosity can be obtained accurately.
Fig. 7 shows a schematic structural diagram of a porosity correction device according to an embodiment of the present invention. As shown in fig. 3, the apparatus includes:
the detection module 710 is adapted to detect fluid information of the stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum;
The projection module 720 is adapted to separate and determine each fluid signal according to the multidimensional nuclear magnetic measurement spectrum, and perform horizontal axis projection to obtain the spectrum distribution of each fluid signal;
the correction module 730 is adapted to perform hydrogen index correction on the spectral distribution of the gas as the fluid signal, so as to obtain a corrected spectral distribution of the gas;
The accumulating module 740 is adapted to accumulate the corrected spectral distribution of the gas with the spectral distribution of the other fluid signals to obtain an integrated sum as the corrected porosity.
Optionally, the detection module 710 is further adapted to:
Detecting fluid information of a stratum with a gas layer to be detected by using a multi-polarization time measurement mode of nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum; the multi-dimensional nuclear magnetic measurement spectrum comprises a longitudinal relaxation time T1-a transverse relaxation time T2 nuclear magnetic measurement spectrum; and/or, longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectra.
Optionally, the detection module 710 is further adapted to:
And measuring the hydrogen content of each fluid in the stratum of the gas bearing layer to be measured by using nuclear magnetic resonance equipment, and calculating to obtain a longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum and/or a longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectrum according to the longitudinal relaxation time T1 and the transverse relaxation time T2.
Optionally, the projection module 720 is further adapted to:
And identifying and determining gas fluid signals and liquid fluid signals according to the longitudinal relaxation time T1 in the multidimensional nuclear magnetic measurement spectrum so as to separate and extract each fluid signal.
Optionally, the projection module 720 is further adapted to:
And comparing the longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum and/or the longitudinal relaxation time T1 of each fluid signal in the longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectrum, and determining the fluid signal corresponding to the maximum longitudinal relaxation time T1 as a gas signal.
Optionally, the correction module 730 is further adapted to:
The fluid signal is the spectral distribution of the gas, and the hydrogen index correction is carried out on the spectral distribution of the gas at each depth point according to the hydrogen index formula under different temperature/pressure conditions.
Optionally, the correction module 730 is further adapted to:
the fluid signal is the spectrum distribution of the gas, the spectrum distribution of the gas is recovered according to the same volume of liquid aiming at each depth point according to the hydrogen index formula under different temperature/pressure conditions, and the corrected spectrum distribution of the gas is obtained.
The above descriptions of the modules refer to the corresponding descriptions in the method embodiments, and are not repeated herein.
The embodiment of the invention also provides a nonvolatile computer storage medium, and the computer storage medium stores at least one executable instruction, and the executable instruction can execute the porosity correction method in any of the method embodiments.
FIG. 8 illustrates a schematic diagram of a computing device, according to an embodiment of the invention, the particular embodiment of which is not limiting of the particular implementation of the computing device.
As shown in fig. 8, the computing device may include: a processor (processor) 802, a communication interface (Communications Interface) 804, a memory (memory) 806, and a communication bus 808.
The method is characterized in that:
Processor 802, communication interface 804, and memory 806 communicate with each other via a communication bus 808.
A communication interface 804 for communicating with network elements of other devices, such as clients or other servers.
The processor 802 is configured to execute the program 810, and may specifically perform relevant steps in the above-described embodiment of the porosity correction method.
In particular, program 810 may include program code including computer operating instructions.
The processor 802 may be a central processing unit CPU, or an Application-specific integrated Circuit ASIC (Application SPECIFIC INTEGRATED Circuit), or one or more integrated circuits configured to implement embodiments of the present invention. The one or more processors included by the computing device may be the same type of processor, such as one or more CPUs; but may also be different types of processors such as one or more CPUs and one or more ASICs.
Memory 806 for storing a program 810. The memory 806 may include high-speed RAM memory or may also include non-volatile memory (non-volatile memory), such as at least one disk memory.
The program 810 may be specifically configured to cause the processor 802 to perform the porosity correction method in any of the method embodiments described above. The specific implementation of each step in the procedure 810 may be referred to the corresponding step and corresponding description in the unit in the above-described porosity correction embodiment, and will not be repeated here. It will be clear to those skilled in the art that, for convenience and brevity of description, specific working procedures of the apparatus and modules described above may refer to corresponding procedure descriptions in the foregoing method embodiments, which are not repeated herein.
The algorithms or displays presented herein are not inherently related to any particular computer, virtual system, or other apparatus. Various general-purpose systems may also be used with the teachings herein. The required structure for a construction of such a system is apparent from the description above. In addition, embodiments of the present invention are not directed to any particular programming language. It should be appreciated that the teachings of embodiments of the present invention described herein may be implemented in a variety of programming languages, and the above description of specific languages is provided for disclosure of preferred embodiments of the present invention.
In the description provided herein, numerous specific details are set forth. However, it is understood that embodiments of the invention may be practiced without these specific details. In some instances, well-known methods, structures and techniques have not been shown in detail in order not to obscure an understanding of this description.
Similarly, it should be appreciated that in the above description of exemplary embodiments of the invention, various features of the embodiments of the invention are sometimes grouped together in a single embodiment, figure, or description thereof for the purpose of streamlining the disclosure and aiding in the understanding of one or more of the various inventive aspects. However, the disclosed method should not be construed as reflecting the intention that: i.e., an embodiment of the invention that is claimed, requires more features than are expressly recited in each claim. Rather, as the following claims reflect, inventive aspects lie in less than all features of a single foregoing disclosed embodiment. Thus, the claims following the detailed description are hereby expressly incorporated into this detailed description, with each claim standing on its own as a separate embodiment of this invention.
Those skilled in the art will appreciate that the modules in the apparatus of the embodiments may be adaptively changed and disposed in one or more apparatuses different from the embodiments. The modules or units or components of the embodiments may be combined into one module or unit or component and, furthermore, they may be divided into a plurality of sub-modules or sub-units or sub-components. Any combination of all features disclosed in this specification (including any accompanying claims, abstract and drawings), and all of the processes or units of any method or apparatus so disclosed, may be used in combination, except insofar as at least some of such features and/or processes or units are mutually exclusive. Each feature disclosed in this specification (including any accompanying claims, abstract and drawings), may be replaced by alternative features serving the same, equivalent or similar purpose, unless expressly stated otherwise.
Furthermore, those skilled in the art will appreciate that while some embodiments herein include some features but not others included in other embodiments, combinations of features of different embodiments are meant to be within the scope of the invention and form different embodiments. For example, in the following claims, any of the claimed embodiments can be used in any combination.
Various component embodiments of the invention may be implemented in hardware, or in software modules running on one or more processors, or in a combination thereof. Those skilled in the art will appreciate that some or all of the functionality of some or all of the components according to embodiments of the present invention may be implemented in practice using a microprocessor or Digital Signal Processor (DSP). Embodiments of the present invention may also be implemented as a device or apparatus program (e.g., a computer program and a computer program product) for performing a portion or all of the methods described herein. Such a program embodying the embodiments of the present invention may be stored on a computer readable medium, or may have the form of one or more signals. Such signals may be downloaded from an internet website, provided on a carrier signal, or provided in any other form.
It should be noted that the above-mentioned embodiments illustrate rather than limit the invention, and that those skilled in the art will be able to design alternative embodiments without departing from the scope of the appended claims. In the claims, any reference signs placed between parentheses shall not be construed as limiting the claim. The word "comprising" does not exclude the presence of elements or steps not listed in a claim. The word "a" or "an" preceding an element does not exclude the presence of a plurality of such elements. Embodiments of the invention may be implemented by means of hardware comprising several distinct elements, and by means of a suitably programmed computer. In the unit claims enumerating several means, several of these means may be embodied by one and the same item of hardware. The use of the words first, second, third, etc. do not denote any order. These words may be interpreted as names. The steps in the above embodiments should not be construed as limiting the order of execution unless specifically stated.
Claims (8)
1. A method of porosity correction, the method comprising:
Detecting fluid information of a stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum;
According to the multidimensional nuclear magnetic measurement spectrum, separating and determining each fluid signal, and performing horizontal axis projection to obtain the spectrum distribution of each fluid signal;
carrying out hydrogen index correction on the spectral distribution of the gas serving as the fluid signal to obtain corrected spectral distribution of the gas;
accumulating the corrected spectral distribution of the gas and the spectral distribution of other fluid signals to obtain an integral sum as corrected porosity;
The method comprises the steps of carrying out hydrogen index correction on the spectral distribution of the gas serving as the fluid signal, and obtaining corrected spectral distribution of the gas further comprises the following steps:
The fluid signal is the spectrum distribution of the gas, the spectrum distribution of the gas is recovered according to the liquid with the same volume aiming at each depth point according to the hydrogen index formula under different temperature and pressure conditions, and the corrected spectrum distribution of the gas is obtained.
2. The method of claim 1, wherein detecting fluid information of the formation to be measured using a nuclear magnetic resonance apparatus to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum further comprises:
Detecting fluid information of a stratum with a gas layer to be detected by using a multi-polarization time measurement mode of nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum; the multi-dimensional nuclear magnetic measurement spectrum comprises a longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum; and/or, longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectra.
3. The method according to claim 2, wherein the detecting the fluid information of the gas bearing layer to be detected by using the multi-polarization time measurement mode of the nuclear magnetic resonance apparatus, and the obtaining the corresponding multi-dimensional nuclear magnetic measurement spectrum specifically includes: and measuring the hydrogen content of each fluid in the stratum of the gas bearing layer to be measured by using nuclear magnetic resonance equipment, and calculating to obtain a longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum and/or a longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectrum according to the longitudinal relaxation time T1 and the transverse relaxation time T2.
4. The method of claim 2, wherein the separately determining each fluid signal from the multi-dimensional nuclear magnetic measurement spectrum further comprises:
and identifying and determining gas fluid signals and liquid fluid signals according to the longitudinal relaxation time T1 in the multi-dimensional nuclear magnetic measurement spectrum so as to separate and extract each fluid signal.
5. The method according to claim 4, wherein the identifying and determining the gas fluid signal and the liquid fluid signal according to the longitudinal relaxation time T1 in the multi-dimensional nuclear magnetic measurement spectrum is performed by:
And comparing the longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum and/or the longitudinal relaxation time T1 of each fluid signal in the longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectrum, and determining the fluid signal corresponding to the maximum longitudinal relaxation time T1 as a gas signal.
6. A porosity correction device, the device comprising:
the detection module is suitable for detecting the fluid information of the stratum to be detected by using nuclear magnetic resonance equipment to obtain a corresponding multidimensional nuclear magnetic measurement spectrum;
the projection module is suitable for separating and determining each fluid signal according to the multidimensional nuclear magnetic measurement spectrum, and performing horizontal axis projection to obtain the spectrum distribution of each fluid signal;
The correction module is suitable for carrying out hydrogen index correction on the spectral distribution of the gas serving as the fluid signal to obtain corrected spectral distribution of the gas;
The accumulation module is suitable for accumulating the corrected spectral distribution of the gas and the spectral distribution of other fluid signals to obtain an integral sum which is used as the corrected porosity;
The correction module is further adapted to: the fluid signal is the spectrum distribution of the gas, the spectrum distribution of the gas is recovered according to the liquid with the same volume aiming at each depth point according to the hydrogen index formula under different temperature and pressure conditions, and the corrected spectrum distribution of the gas is obtained.
7. A computing device, comprising: the device comprises a processor, a memory, a communication interface and a communication bus, wherein the processor, the memory and the communication interface complete communication with each other through the communication bus;
The memory is configured to store at least one executable instruction that causes the processor to perform operations corresponding to the porosity correction method according to any one of claims 1 to 5.
8. A computer storage medium having stored therein at least one executable instruction for causing a processor to perform operations corresponding to the porosity correction method according to any one of claims 1-5.
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| CN117805000B (en) * | 2024-03-01 | 2024-06-18 | 江苏龙城精锻集团有限公司 | Method for detecting internal micropores of material in hydrogenation environment |
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| CN111535796A (en) * | 2020-04-17 | 2020-08-14 | 中海油田服务股份有限公司 | Method and device for acquiring logging parameters |
| CN111980663A (en) * | 2020-07-21 | 2020-11-24 | 中海油田服务股份有限公司 | Multi-frequency multi-dimensional nuclear magnetic logging method and device |
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