CN114137015A - Porosity correction method and device - Google Patents
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- 238000012937 correction Methods 0.000 title claims abstract description 46
- 238000000034 method Methods 0.000 title claims abstract description 42
- 239000012530 fluid Substances 0.000 claims abstract description 85
- 238000001228 spectrum Methods 0.000 claims abstract description 78
- 239000007789 gas Substances 0.000 claims abstract description 70
- 238000009826 distribution Methods 0.000 claims abstract description 65
- 238000005259 measurement Methods 0.000 claims abstract description 57
- 230000003595 spectral effect Effects 0.000 claims abstract description 46
- UFHFLCQGNIYNRP-UHFFFAOYSA-N Hydrogen Chemical compound [H][H] UFHFLCQGNIYNRP-UHFFFAOYSA-N 0.000 claims abstract description 42
- 239000001257 hydrogen Substances 0.000 claims abstract description 42
- 229910052739 hydrogen Inorganic materials 0.000 claims abstract description 42
- 238000005481 NMR spectroscopy Methods 0.000 claims abstract description 15
- 238000004891 communication Methods 0.000 claims description 15
- 239000007788 liquid Substances 0.000 claims description 15
- 230000015572 biosynthetic process Effects 0.000 claims description 13
- 238000001514 detection method Methods 0.000 claims description 7
- 238000010995 multi-dimensional NMR spectroscopy Methods 0.000 claims description 4
- 238000003860 storage Methods 0.000 claims description 4
- 238000009825 accumulation Methods 0.000 claims description 3
- 238000011084 recovery Methods 0.000 claims description 3
- 238000010586 diagram Methods 0.000 description 8
- 238000005516 engineering process Methods 0.000 description 5
- VNWKTOKETHGBQD-UHFFFAOYSA-N methane Chemical compound C VNWKTOKETHGBQD-UHFFFAOYSA-N 0.000 description 4
- 238000004364 calculation method Methods 0.000 description 3
- 125000004435 hydrogen atom Chemical group [H]* 0.000 description 3
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 description 3
- 238000004590 computer program Methods 0.000 description 2
- 230000000694 effects Effects 0.000 description 2
- 238000004519 manufacturing process Methods 0.000 description 2
- 239000011148 porous material Substances 0.000 description 2
- 206010021703 Indifference Diseases 0.000 description 1
- 238000004458 analytical method Methods 0.000 description 1
- 238000013461 design Methods 0.000 description 1
- 238000011161 development 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
- 239000003208 petroleum Substances 0.000 description 1
- 238000012545 processing Methods 0.000 description 1
- 238000004451 qualitative analysis Methods 0.000 description 1
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- 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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Abstract
The embodiment of the invention discloses a porosity correction method and a porosity correction device, wherein the method comprises the following steps: detecting fluid information of a stratum to be detected by utilizing nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum; according to the multi-dimensional nuclear magnetic measurement spectrum, separating and determining each fluid signal, and performing cross-axis projection to obtain the spectral distribution of each fluid signal; carrying out hydrogen-containing index correction on the spectral distribution of the fluid signal which is gas to obtain the corrected spectral distribution of the gas; and accumulating the corrected spectral distribution of the gas and the spectral distributions of other fluid signals to obtain an integral sum as the corrected porosity. The invention can assist in identifying the fluid by utilizing the multi-dimensional nuclear magnetic measurement spectrum, is convenient to correct the spectral distribution of the gas and accurately obtains the corrected porosity.
Description
Technical Field
The embodiment of the invention relates to the field of oil exploration, in particular to a porosity correction method and a porosity correction device.
Background
The nuclear magnetic resonance logging technology is widely applied to the field of petroleum exploration, and can be used for nondestructive intervention detection of formation fluid information and calculation of important formation information such as porosity, permeability and the like based on a nuclear magnetic transverse relaxation time T2 spectrum of formation fluid.
With the development of the technology, the one-dimensional nuclear magnetic logging technology no longer meets the measurement requirement of the complex stratum. The existing one-dimensional nuclear magnetic logging technology measures the T2 nuclear magnetic spectrum of hydrogen-containing fluid, is used for identifying and analyzing formation indifference fluid, and has poor fluid auxiliary identification effect. The hydrogen indices of the liquid and gas in a practical formation are not consistent and therefore there is often a large difference in the calculated porosity. As shown in fig. 1, the T2 nuclear magnetic spectrum of hydrogen-containing gas such as methane overlaps with the T2 nuclear magnetic spectrum of hydrogen-containing liquid such as water or oil, and qualitative analysis can be performed by means of difference spectrum, but the effect of analysis does not truly reflect the formation porosity characteristics.
Disclosure of Invention
In view of the above, embodiments of the present invention are proposed in order to provide a porosity correction method and apparatus that overcomes or at least partially solves the above-mentioned 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 utilizing nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum;
according to the multi-dimensional nuclear magnetic measurement spectrum, separating and determining each fluid signal, and performing cross-axis projection to obtain the spectral distribution of each fluid signal;
carrying out hydrogen-containing index correction on the spectral distribution of the fluid signal which is gas to obtain the corrected spectral distribution of the gas;
and accumulating the corrected spectral distribution of the gas and the spectral distributions of other fluid signals to obtain an integral sum as the corrected porosity.
According to another aspect of embodiments 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 utilizing the nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional 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 projecting a transverse axis to obtain the spectral distribution of each fluid signal;
the correction module is suitable for performing hydrogen-containing index correction on the spectral distribution of the fluid signal which is gas to obtain the corrected spectral distribution of the gas;
and the accumulation module is suitable for accumulating the corrected spectrum distribution of the gas and the spectrum distribution of other fluid signals to obtain an integral sum as the corrected porosity.
According to still another aspect of an embodiment of the present invention, there is provided a computing device including: the system comprises a processor, a memory, a communication interface and a communication bus, wherein the processor, the memory and the communication interface complete mutual communication 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 a further aspect of the embodiments of the present invention, there is provided a computer storage medium having at least one executable instruction stored therein, the executable instruction causing a processor to perform operations corresponding to the porosity correction method.
According to the porosity correction method and device provided by the embodiment of the invention, the multidimensional nuclear magnetic measurement spectrum can be used for assisting in identifying the fluid, so that the spectral distribution of the gas can be conveniently corrected, and the corrected porosity can be accurately obtained.
The foregoing description is only an overview of the technical solutions of the embodiments of the present invention, and the embodiments of the present invention can be implemented according to the content of the description in order to make the technical means of the embodiments of the present invention more clearly understood, and the detailed description of the embodiments of the present invention is provided below in order to make the foregoing and other objects, features, and advantages of the embodiments of the present invention more clearly understandable.
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 embodiments of the invention. Also, like reference numerals are used to refer to like parts throughout the drawings. In the drawings:
FIG. 1 shows a distribution diagram of hydrogen-containing liquid and hydrogen-containing gas in a one-dimensional nuclear magnetic logging T2 spectrum;
FIG. 2 shows a flow diagram of a porosity correction method according to an embodiment of the invention;
FIG. 3 shows a schematic representation of a multi-dimensional NMR spectrum from T1 to T2;
FIG. 4 shows a schematic representation of a multi-dimensional NMR spectrum of T1/T2-T2;
FIG. 5 shows a schematic projection of the transverse axis of a multi-dimensional nuclear magnetic measurement spectrum;
FIG. 6 shows a schematic diagram of a horizontal axis projection corrected for the spectral distribution of the gas signal;
FIG. 7 shows a schematic structural diagram of a porosity correction device according to an embodiment of the invention;
FIG. 8 illustrates a schematic structural diagram of a computing device in accordance with one embodiment of the present 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 invention are shown in the drawings, it should be understood that the invention can 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 diagram of a porosity correction method according to one embodiment of the invention, as shown in FIG. 2, comprising the steps of:
step S201, 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 nuclear magnetic logging technology can be used for nondestructive intervention detection of formation fluid information, in this embodiment, fluid information of a gas-bearing formation to be detected is detected by using a multi-polarization time measurement mode of a nuclear magnetic resonance device, and specifically, the content of hydrogen atoms, namely the hydrogen content, of each fluid in the gas-bearing formation to be detected is detected, so as to obtain a corresponding multidimensional nuclear magnetic measurement spectrum. The multidimensional 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 multi-polarization time nuclear magnetic measurement mode, and a T1-T2 nuclear magnetic measurement spectrum or a T1/T2-T2 nuclear magnetic measurement spectrum is obtained through calculation based on the nuclear magnetic resonance principle.
And step S202, separating and determining each fluid signal according to the multi-dimensional nuclear magnetic measurement spectrum, and performing horizontal axis projection to obtain the spectral distribution of each fluid signal.
The longitudinal relaxation time T1 of different fluids in the multi-dimensional nuclear magnetic measurement spectrum is different, and the nuclear magnetic measurement spectrum of T1-T2 or T1/T2-T2 is used for identifying and separating signals of the fluids. Fluid signals include, for example, gas fluid signals and liquid fluid signals. 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 a gas signal by comparing the longitudinal relaxation times T1 of the respective fluid signals in the nuclear magnetic measurement spectra of T1 to T2, that is, the hydrogen-containing gas signal is distributed at the upper left in fig. 3. For the nuclear magnetic measurement spectrum T1/T2-T2 of FIG. 4, the larger the T1, the larger the T1/T2 value, and the hydrogen-containing gas signal is distributed above the nuclear magnetic measurement spectrum T1/T2-T2.
The cross-axis projection of the different fluid signal distributions in fig. 3 and 4 is performed to obtain the spectral distributions of the respective fluid signals, and as shown in fig. 5, the T2 spectral distribution corresponding to the hydrogen-containing liquid and the T2 spectral distribution corresponding to the hydrogen-containing gas are obtained, and the total nuclear magnetic spectrum is the spectral distribution obtained by adding the two.
Step S203, the hydrogen-containing index correction is carried out on the spectral distribution of the fluid signal which is gas, and the corrected spectral distribution of the gas is obtained.
The nuclear magnetism is used for reflecting the pore size of the existing fluid, and compared with the liquid and the gas with the same pore, the gas signal is much smaller, namely the volume of the existing gas signal content obtained by actual measurement is larger than the T2 spectrum distribution projection of the hydrogen-containing gas in figure 5, and the hydrogen-containing index correction is needed to be 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, calpority is measured spectrum distribution, measurepority is actually measured spectrum distribution by nuclear magnetic logging, and f (T, P) is a functional relationship with respect to temperature and pressure, an existing empirical formula of temperature and pressure may be used, which is not limited herein. And (3) converting the volume of the gas signal corresponding to the gas spectral distribution obtained by actual measurement into liquid with the same volume aiming at each depth point by adopting the formula, and performing signal recovery according to the liquid with the same volume to obtain the gas correction spectral distribution.
And step S204, accumulating the corrected spectrum distribution of the gas and the spectrum distributions of other fluid signals to obtain an integral sum as the corrected porosity.
Hydrogen Index (HI) is an inherent property of a hydrogen-containing fluid and is the ratio of the number of hydrogen atoms per volume of fluid to the number of hydrogen atoms per volume of pure water under standard conditions. The hydrogen index determines the value of the effective porosity of the formation. The corrected spectral distribution of the gas in fig. 6 is added up with the spectral distribution of other fluid signals (hydrogen-containing liquid), and the integral sum is obtained as the corrected porosity, i.e. the nuclear magnetic total spectrum after hydrogen-containing index correction is the corrected porosity.
In the field of nuclear magnetic resonance multiphase fluid measurement, 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 oil production and the gas production of an oil-gas well. The embodiment corrects the gas spectrum distribution, and guarantees the accuracy of the finally obtained porosity.
According to the porosity correction method provided by the embodiment of the invention, the multidimensional nuclear magnetic measurement spectrum can be used for assisting in identifying the fluid, so that the spectral distribution of the gas can be conveniently corrected, and the corrected porosity can be accurately obtained.
Fig. 7 is a schematic structural diagram of a porosity correction device provided in 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 formation to be detected by using a nuclear magnetic resonance device to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum;
the projection module 720 is adapted to determine each fluid signal separately according to the multidimensional nuclear magnetic measurement spectrum, and perform a cross-axis projection to obtain a spectral distribution of each fluid signal;
the correction module 730 is suitable for performing hydrogen-containing index correction on the gas spectrum distribution of the fluid signal to obtain the gas correction spectrum distribution;
the accumulation module 740 is adapted to accumulate the corrected spectral distribution of the gas and the spectral distributions 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 gas-bearing stratum to be detected by utilizing a multi-polarization time measuring mode of nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum; the multidimensional nuclear magnetic measurement spectrum comprises 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 spectrum.
Optionally, the detection module 710 is further adapted to:
the method comprises the steps of measuring the hydrogen content of each fluid in the gas-bearing stratum to be measured by utilizing 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:
according to the longitudinal relaxation time T1 in the multi-dimensional nuclear magnetic measurement spectrum, the gas fluid signal and the liquid fluid signal are identified and determined 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-the transverse relaxation time T2 nuclear magnetic measurement spectrum, and/or comparing the longitudinal relaxation time T1/the transverse relaxation time T2-the transverse relaxation time T2 nuclear magnetic measurement spectrum of each fluid signal with the longitudinal relaxation time T1, and determining that the fluid signal corresponding to the maximum longitudinal relaxation time T1 is a gas signal.
Optionally, the correction module 730 is further adapted to:
and (3) performing hydrogen-containing index correction on the gas spectral distribution of each depth point according to a hydrogen-containing index formula under different temperature/pressure conditions when the fluid signal is the gas spectral distribution.
Optionally, the correction module 730 is further adapted to:
and (3) performing signal recovery on the gas spectrum distribution according to the same volume of liquid at each depth point according to a hydrogen-containing index formula under different temperature/pressure conditions to obtain the gas correction spectrum distribution.
The 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, wherein the computer storage medium stores at least one executable instruction, and the executable instruction can execute the porosity correction method in any method embodiment.
Fig. 8 is a schematic structural diagram of a computing device according to an embodiment of the present invention, and a specific embodiment of the present invention does not limit a specific implementation of the computing device.
As shown in fig. 8, the computing device may include: a processor (processor)802, a Communications Interface 804, a memory 806, and a communication bus 808.
The method is characterized in that:
the processor 802, communication interface 804, and memory 806 communicate with one another 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, configured to execute the program 810, may specifically perform relevant steps in the porosity correction method embodiments described above.
In particular, the program 810 may include program code comprising computer operating instructions.
The processor 802 may be a central processing unit CPU, or an Application Specific Integrated Circuit (ASIC), or one or more Integrated circuits configured to implement embodiments of the present invention. The computing device includes one or more processors, which may be the same type of processor, such as one or more CPUs; or may be different types of processors such as one or more CPUs and one or more ASICs.
The memory 806 stores a program 810. The memory 806 may comprise high-speed RAM memory, and 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. For specific implementation of each step in the program 810, reference may be made to corresponding steps and corresponding descriptions in units in the porosity correction embodiments, which are not described herein again. It can be clearly understood by those skilled in the art that, for convenience and brevity of description, the specific working processes of the above-described devices and modules may refer to the corresponding process descriptions in the foregoing method embodiments, and are not described herein again.
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 constructing such a system will be apparent from the description above. In addition, embodiments of the present invention are not directed to any particular programming language. It is appreciated that a variety of programming languages may be used to implement the teachings of embodiments of the present invention as described herein, and any descriptions of specific languages are provided above to disclose preferred embodiments of the invention.
In the description provided herein, numerous specific details are set forth. It is understood, however, 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 foregoing 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 interpreted as reflecting an intention that: that is, the claimed embodiments of the invention require 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 device in an embodiment may be adaptively changed and disposed in one or more devices different from the embodiment. 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. All of the features disclosed in this specification (including any accompanying claims, abstract and drawings), and all of the processes or elements of any method or apparatus so disclosed, may be combined in any combination, except combinations where at least some of such features and/or processes or elements 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 included in other embodiments, rather than other features, 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 may be used in any combination.
The 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 a microprocessor or Digital Signal Processor (DSP) may be used in practice to implement some or all of the functionality of some or all of the components according to embodiments of the present invention. Embodiments of the invention may also be implemented as apparatus or device programs (e.g., computer programs and computer program products) for performing a portion or all of the methods described herein. Such programs implementing embodiments of the present invention may be stored on computer-readable media or may be in the form of one or more signals. Such a signal may be downloaded from an internet website or provided on a carrier signal or 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 usage of the words first, second and third, etcetera do not indicate any ordering. These words may be interpreted as names. The steps in the above embodiments should not be construed as limiting the order of execution unless specified otherwise.
Claims (10)
1. A method of porosity correction, the method comprising:
detecting fluid information of a stratum to be detected by utilizing nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional nuclear magnetic measurement spectrum;
separating and determining each fluid signal according to the multi-dimensional nuclear magnetic measurement spectrum, and performing cross-axis projection to obtain the spectral distribution of each fluid signal;
carrying out hydrogen-containing index correction on the spectral distribution of the fluid signal which is gas to obtain the corrected spectral distribution of the gas;
and accumulating the corrected spectral distribution of the gas and the spectral distributions of other fluid signals to obtain an integral sum as the corrected porosity.
2. The method of claim 1, wherein the detecting fluid information of the formation to be tested with the nmr to obtain a corresponding multi-dimensional nmr spectrum further comprises:
detecting fluid information of a gas-bearing stratum to be detected by utilizing a multi-polarization time measuring 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 spectrum.
3. The method according to claim 2, wherein the detecting of the fluid information of the gas-bearing formation to be measured by means of multi-polarization time measurement of the nmr apparatus to obtain the corresponding multi-dimensional nmr spectrum comprises: the method comprises the steps of measuring the hydrogen content of each fluid in the gas-bearing stratum to be measured by utilizing 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 separating each fluid signal from the multi-dimensional nuclear magnetic measurements further comprises:
according to the longitudinal relaxation time T1 in the multi-dimensional nuclear magnetic measurement spectrum, identifying and determining a gas fluid signal and a liquid fluid signal so as to separate and extract each fluid signal.
5. The method according to claim 4, wherein the identification and determination of the gas fluid signal and the liquid fluid signal according to the longitudinal relaxation time T1 in the multi-dimensional nuclear magnetic measurement spectrum, so as to separate and extract each fluid signal, is specifically as follows:
and comparing the longitudinal relaxation time T1-transverse relaxation time T2 nuclear magnetic measurement spectrum, and/or comparing the longitudinal relaxation time T1/transverse relaxation time T2-transverse relaxation time T2 nuclear magnetic measurement spectrum of each fluid signal in the longitudinal relaxation time T1, and determining that the fluid signal corresponding to the maximum longitudinal relaxation time T1 is a gas signal.
6. The method of any one of claims 1-5, wherein the hydrogen-containing index correcting the spectral distribution of the fluid signal as a gas, and obtaining a corrected spectral distribution of the gas further comprises:
and performing hydrogen-containing index correction on the gas spectral distribution of each depth point according to a hydrogen-containing index formula under different temperature/pressure conditions.
7. The method of claim 1, wherein the fluid signal is a spectral distribution of a gas, and wherein performing a hydrogen-containing index correction on the spectral distribution of the gas for each depth point according to a hydrogen-containing index formula under different temperature/pressure conditions further comprises:
and (3) performing signal recovery on the gas spectrum distribution according to the same volume of liquid at each depth point according to a hydrogen-containing index formula under different temperature/pressure conditions to obtain the gas correction spectrum distribution.
8. A porosity correction device, characterized in that the device comprises:
the detection module is suitable for detecting the fluid information of the stratum to be detected by utilizing the nuclear magnetic resonance equipment to obtain a corresponding multi-dimensional 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 projecting a transverse axis to obtain the spectral distribution of each fluid signal;
the correction module is suitable for performing hydrogen-containing index correction on the spectral distribution of the fluid signal which is gas to obtain the corrected spectral distribution of the gas;
and the accumulation module is suitable for accumulating the corrected spectrum distribution of the gas and the spectrum distribution of other fluid signals to obtain an integral sum as the corrected porosity.
9. A computing device, comprising: the system comprises a processor, a memory, a communication interface and a communication bus, wherein the processor, the memory and the communication interface complete mutual communication 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 of any one of claims 1-7.
10. A computer storage medium having stored therein at least one executable instruction that causes a processor to perform operations corresponding to the porosity correction method of any one of claims 1-7.
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| CN116500694A (en) * | 2023-06-28 | 2023-07-28 | 中海油田服务股份有限公司 | Post-sleeve physical quantity inversion method, post-sleeve physical quantity inversion device, computing equipment and storage medium |
| CN117805000A (en) * | 2024-03-01 | 2024-04-02 | 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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| CN117805000A (en) * | 2024-03-01 | 2024-04-02 | 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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