CN112267870B - Method and device for detecting corrosion probability of well pipe column - Google Patents
Method and device for detecting corrosion probability of well pipe column Download PDFInfo
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- 230000007797 corrosion Effects 0.000 title claims abstract description 189
- 238000005260 corrosion Methods 0.000 title claims abstract description 189
- 238000000034 method Methods 0.000 title claims abstract description 51
- 239000011159 matrix material Substances 0.000 claims abstract description 164
- 238000011161 development Methods 0.000 claims abstract description 43
- 239000004927 clay Substances 0.000 claims abstract description 18
- 208000010392 Bone Fractures Diseases 0.000 claims description 53
- 206010017076 Fracture Diseases 0.000 claims description 53
- 238000009792 diffusion process Methods 0.000 claims description 32
- 238000012937 correction Methods 0.000 claims description 31
- XLYOFNOQVPJJNP-UHFFFAOYSA-N water Substances O XLYOFNOQVPJJNP-UHFFFAOYSA-N 0.000 claims description 29
- 230000035699 permeability Effects 0.000 claims description 27
- 238000012545 processing Methods 0.000 claims description 12
- 238000004590 computer program Methods 0.000 claims description 9
- 238000001514 detection method Methods 0.000 claims description 6
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Classifications
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B47/00—Survey of boreholes or wells
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- G—PHYSICS
- G01—MEASURING; TESTING
- G01N—INVESTIGATING OR ANALYSING MATERIALS BY DETERMINING THEIR CHEMICAL OR PHYSICAL PROPERTIES
- G01N17/00—Investigating resistance of materials to the weather, to corrosion, or to light
Abstract
The embodiment of the application provides a method and a device for detecting corrosion probability of a well pipe column, wherein when the corrosion probability of the well pipe column is detected, lithologic density data, matrix clay content data and longitudinal crack development data of a well reservoir to be detected, in which the well pipe column to be detected is positioned, are detected respectively; determining phase section information of the reservoir to be logged according to lithologic density data and longitudinal crack development data of the reservoir to be logged; determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and matrix argillaceous content data; according to the corrosion probability of the well pipe column to be detected, corresponding prompt information is output, so that a worker can acquire the corrosion probability of the well pipe column according to the prompt information, and the pipe material of the well pipe column is selected in a targeted manner according to the corrosion probability of the well pipe column, and the accuracy of well pipe column selection is improved.
Description
Technical Field
The invention relates to the technical field of oil and gas exploitation, in particular to a method and a device for detecting corrosion probability of a well bore pipe column.
Background
Oil gas plays an extremely important role in national economy, and in the process of producing oil gas, a well shaft pipe column of the gas well is corroded, so that the corrosion phenomenon not only affects the service life of the well shaft pipe column, but also causes economic loss, and the problems of environmental pollution, ecological damage and the like occur.
In order to avoid the corrosion of the well pipe, in the prior art, a material with strong corrosion resistance is usually selected as the pipe of the well pipe. However, because the corrosion capacities of different positions of the oil and gas well are different, if all the pipes with complex process and high cost and strong corrosion resistance are selected, the resource waste is inevitably caused. In order to avoid resource waste, the corrosion probability of the well pipe column can be detected first, so that the pipe material of the well pipe column can be selected in a targeted manner according to the corrosion probability of the well pipe column.
Therefore, how to detect the probability of corrosion of a wellbore string is a highly desirable problem for those skilled in the art.
Disclosure of Invention
The embodiment of the invention provides a method and a device for detecting corrosion probability of a well pipe column, which can detect the corrosion probability of the well pipe column, so that the pipe material of the well pipe column can be selected in a targeted manner according to the corrosion probability of the well pipe column, and the accuracy of the well pipe column selection is improved.
In a first aspect, an embodiment of the present application provides a method for detecting a corrosion probability of a wellbore tubular string, where the method for detecting a corrosion probability of a wellbore tubular string includes:
and respectively detecting lithologic density data, matrix argillaceous content data and longitudinal crack development data of a reservoir of the well to be detected, in which the well pipe column to be detected is located.
And determining phase section information of the reservoir of the well to be tested according to the lithologic density data of the reservoir of the well to be tested and the longitudinal fracture development data.
And determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir of the well to be detected and the matrix argillaceous content data.
And outputting corresponding prompt information according to the corrosion probability of the well pipe column to be detected.
In one possible implementation manner, the outputting, according to the corrosion probability of the wellbore tubular column to be detected, a corresponding prompt message includes:
outputting first prompt information if the corrosion probability of the well pipe column to be detected is smaller than a preset threshold value; the first prompt message is used for indicating that the to-be-detected well pipe column has low corrosion probability.
Outputting second prompt information if the corrosion probability of the well bore pipe column to be detected is greater than or equal to a preset threshold value; and the second prompt information is used for indicating that the to-be-detected well pipe column has higher corrosion probability.
In one possible implementation, the phase section information includes thickness information of a fracture system permeable phase section, thickness information of a matrix reservoir diffusion phase section; correspondingly, the matrix shale content data comprises average shale content information of a permeable phase section of the fracture system, average shale content information of a permeable phase section of the matrix reservoir and average shale content information of a diffusion phase section of the matrix reservoir.
In one possible implementation manner, the determining the corrosion probability of the well pipe string to be detected according to the phase section information of the well reservoir to be detected and the matrix argillaceous content data includes:
according toDetermining the corrosion probability of the well pipe column to be detected,
wherein F represents the corrosion probability of the well pipe column to be detected, h 1 Thickness information representing a permeable phase section of a fracture system，h 2 Information indicating thickness of the permeable phase section of the matrix reservoir, h 3 Thickness information representing the diffusion phase section of the matrix reservoir,information indicating the average clay content of the permeable phase section of the fracture system>Information indicating the average argillaceous content of the permeable phase section of the matrix reservoir,/for>Average shale content information representing the diffusion phase section of the matrix reservoir.
In one possible implementation, if the zone where the well reservoir to be measured is currently located is a side water zone, the method further includes:
and determining a risk correction coefficient of water from the bottom water and gas reservoir in the side water section.
And correcting the corrosion probability of the well pipe column to be detected according to the risk correction coefficient to obtain the target probability of corrosion of the well pipe column to be detected.
In a possible implementation manner, the correcting the corrosion probability of the well pipe string to be detected according to the risk correction coefficient to obtain a target corrosion probability of the well pipe string to be detected includes:
and calculating the ratio of the corrosion probability of the well pipe column to be detected to the risk correction coefficient.
And determining the ratio as the target probability of corrosion of the well pipe column to be detected.
In one possible implementation manner, the determining phase section information of the reservoir of the well to be tested according to lithology density data of the reservoir of the well to be tested and the longitudinal fracture development data includes:
and determining matrix porosity data of the reservoir of the well to be tested according to the lithologic density data of the reservoir of the well to be tested.
And determining matrix permeability data corresponding to the matrix porosity data of the reservoir of the well to be tested according to the matrix porosity data of the reservoir of the well to be tested and the corresponding relation between the matrix porosity data and the permeability data.
And determining phase section information of the reservoir of the well to be tested according to matrix permeability data corresponding to the matrix porosity data of the reservoir of the well to be tested and the longitudinal fracture development data.
In a second aspect, embodiments of the present application further provide a device for detecting a corrosion probability of a wellbore tubular string, where the device for detecting a corrosion probability of a wellbore tubular string includes:
the detection unit is used for respectively detecting lithologic density data, matrix argillaceous content data and longitudinal crack development data of a reservoir of the well to be detected, in which the well pipe column to be detected is located.
The processing unit is used for determining phase section information of the reservoir of the well to be tested according to lithology density data of the reservoir of the well to be tested and the longitudinal crack development data; and determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir of the well to be detected and the matrix argillaceous content data.
And the prompting unit is used for outputting corresponding prompting information according to the corrosion probability of the well pipe column to be detected.
In one possible implementation manner, the prompting unit is specifically configured to output a first prompting message if the corrosion probability of the wellbore tubular column to be detected is less than a preset threshold; the first prompt message is used for indicating that the to-be-detected well pipe column has low corrosion probability.
The prompting unit is specifically configured to output a second prompting message if the corrosion probability of the wellbore tubular column to be detected is greater than or equal to a preset threshold value; and the second prompt information is used for indicating that the to-be-detected well pipe column has higher corrosion probability.
In one possible implementation, the phase section information includes thickness information of a fracture system permeable phase section, thickness information of a matrix reservoir diffusion phase section; correspondingly, the matrix shale content data comprises average shale content information of a permeable phase section of the fracture system, average shale content information of a permeable phase section of the matrix reservoir and average shale content information of a diffusion phase section of the matrix reservoir.
In a possible implementation manner, the processing unit is specifically configured to, according to And determining the corrosion probability of the well pipe column to be detected.
Wherein F represents the corrosion probability of the well pipe column to be detected, h 1 Thickness information indicating a permeable phase section of a fracture system, h 2 Information indicating thickness of the permeable phase section of the matrix reservoir, h 3 Thickness information representing the diffusion phase section of the matrix reservoir,information indicating the average clay content of the permeable phase section of the fracture system >Information indicating the average argillaceous content of the permeable phase section of the matrix reservoir,/for>Average shale content information representing the diffusion phase section of the matrix reservoir.
In one possible implementation manner, if the area where the reservoir of the well to be measured is currently located is a side water area, the apparatus further includes a correction unit:
the correcting unit is used for determining a risk correction coefficient of bottom water gas reservoir water in the side water section, correcting the corrosion probability of the well pipe column to be detected according to the risk correction coefficient, and obtaining the target probability of corrosion of the well pipe column to be detected.
In one possible implementation manner, the correction unit is specifically configured to calculate a ratio of the corrosion probability of the wellbore tubular string to be detected to the risk correction coefficient, and determine the ratio as the target probability of corrosion of the wellbore tubular string to be detected.
In a possible implementation manner, the processing unit is specifically configured to determine matrix porosity data of the well reservoir to be tested according to lithology density data of the well reservoir to be tested; determining matrix permeability data corresponding to the matrix porosity data of the well reservoir to be tested according to the matrix porosity data of the well reservoir to be tested and the corresponding relation between the matrix porosity data and the permeability data; and determining phase section information of the reservoir of the well to be tested according to matrix permeability data corresponding to the matrix porosity data of the reservoir of the well to be tested and the longitudinal fracture development data.
In a third aspect, embodiments of the present application further provide a device for detecting a corrosion probability of a wellbore string, where the device for detecting a corrosion probability of a wellbore string includes a memory and a processor; wherein,
the memory is used for storing a computer program;
the processor is configured to read the computer program stored in the memory, and execute the method for detecting the corrosion probability of the wellbore tubular string according to any one of the possible implementation manners of the first aspect according to the computer program in the memory.
In a fourth aspect, an embodiment of the present application further provides a computer readable storage medium, where computer executable instructions are stored, and when a processor executes the computer executable instructions, the method for detecting a corrosion probability of a wellbore string in any one of the possible implementation manners of the first aspect is implemented.
Therefore, the method and the device for detecting the corrosion probability of the well pipe column can detect lithologic density data, matrix argillaceous content data and longitudinal crack development data of the well reservoir to be detected, where the well pipe column to be detected is located, respectively; determining phase section information of the reservoir to be logged according to lithologic density data and longitudinal crack development data of the reservoir to be logged; determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and matrix argillaceous content data; according to the corrosion probability of the well pipe column to be detected, corresponding prompt information is output, so that a worker can acquire the corrosion probability of the well pipe column according to the prompt information, and the pipe material of the well pipe column is selected in a targeted manner according to the corrosion probability of the well pipe column, and the accuracy of well pipe column selection is improved.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this specification, illustrate embodiments consistent with the disclosure and together with the description, serve to explain the principles of the disclosure.
Fig. 1 is a schematic flow chart of a method for detecting corrosion probability of a wellbore tubular column according to an embodiment of the present disclosure;
FIG. 2 is a schematic diagram of a plan view of a certain basin and a certain reservoir of water and gas in the western China according to an embodiment of the present application;
FIG. 3 is a schematic structural diagram of a device for detecting corrosion probability of a wellbore tubular string according to an embodiment of the present disclosure;
fig. 4 is a schematic structural diagram of another apparatus for detecting corrosion probability of a wellbore tubular string according to an embodiment of the present disclosure.
Specific embodiments of the present disclosure have been shown by way of the above drawings and will be described in more detail below. These drawings and the written description are not intended to limit the scope of the disclosed concepts in any way, but rather to illustrate the disclosed concepts to those skilled in the art by reference to specific embodiments.
Detailed Description
Reference will now be made in detail to exemplary embodiments, examples of which are illustrated in the accompanying drawings. When the following description refers to the accompanying drawings, the same numbers in different drawings refer to the same or similar elements, unless otherwise indicated. The implementations described in the following exemplary examples are not representative of all implementations consistent with the present disclosure. Rather, they are merely examples of apparatus and methods consistent with some aspects of the present disclosure as detailed in the accompanying claims.
In embodiments of the present invention, "at least one" means one or more, and "a plurality" means two or more. "and/or", describes an association relationship of an association object, and indicates that there may be three relationships, for example, a and/or B, and may indicate: there are three cases, a alone, a and B together, and B alone, wherein a, B may be singular or plural. In the text description of the present invention, the character "/" generally indicates that the front-rear associated object is an or relationship.
The method for detecting the corrosion probability of the well pipe column can be applied to the scenes of ultra-deep and ultra-high pressure gas well drilling and completion. In the process of producing oil and gas, the well shaft pipe column of the gas well is corroded, the corrosion phenomenon not only affects the service life of the well shaft pipe column, but also causes economic loss, and the problems of environmental pollution, ecological damage and the like occur. In order to avoid the corrosion of the well pipe, in the prior art, a material with strong corrosion resistance is usually selected as the pipe of the well pipe. In order to avoid resource waste, the corrosion probability of the well pipe column can be detected first, so that the pipe material of the well pipe column can be selected in a targeted manner according to the corrosion probability of the well pipe column. Therefore, how to detect the probability of corrosion of a wellbore string is a highly desirable problem for those skilled in the art.
In order to detect the corrosion probability of a wellbore string, the technical solution that is easy to think is: through experimental research, the relevance of the corrosion rates of different depths in the pit and the corrosion rates of the wellhead are determined, a wellhead underground corrosion rate relevance model algorithm is established, and then the corrosion rates of different depths in the pit are calculated by utilizing the wellhead corrosion rates, and a new compensation method is researched to solve the problem that the actual measured value of the thick-wall columnar inductance probe test piece deviates from the linear relation with the mathematical model curve of the original inductance probe, so that the wellhead corrosion rate is detected online. However, due to the fact that the substrates with different depths in the well are different and are unevenly distributed, the well head underground corrosion rate correlation model established through experiments cannot specifically reflect the corrosion probability of different positions with different depths in the well, and the problem of waste of shaft column material selection still can be caused.
Through long-term creative labor, the applicant finds that lithology density data, matrix clay content data and longitudinal crack development data of a well reservoir where a well pipe column is located affect corrosion conditions of the well pipe column, so that the corrosion probability of the well pipe column can be predicted according to the lithology density data, matrix clay content data and longitudinal crack development data of the well reservoir where the well pipe column is located by acquiring the lithology density data, matrix clay content data and longitudinal crack development data of the well reservoir where the well pipe column is located. Based on the technical conception, the embodiment of the application provides a method for detecting the corrosion probability of a well pipe column, which can detect lithologic density data, matrix argillaceous content data and longitudinal crack development data of a well reservoir to be detected, in which the well pipe column to be detected is positioned, when the corrosion probability of the well pipe column is determined; determining phase section information of the reservoir to be logged according to lithologic density data and longitudinal crack development data of the reservoir to be logged; determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and matrix argillaceous content data; and outputting corresponding prompt information according to the corrosion probability of the well pipe column to be detected. Therefore, a worker can acquire the corrosion probability of the well pipe column according to the prompt information, and can pertinently select the pipe material of the well pipe column according to the corrosion probability of the well pipe column, so that the accuracy of well pipe column selection is improved.
The method for detecting the corrosion probability of the well pipe column provided by the application will be described in detail through specific embodiments. It is to be understood that the following embodiments may be combined with each other and that some embodiments may not be repeated for the same or similar concepts or processes.
Fig. 1 is a schematic flow chart of a method for detecting corrosion probability of a wellbore string according to an embodiment of the present application, where the method for detecting corrosion probability of a wellbore string may be performed by software and/or hardware devices, for example, the hardware device may be a device for detecting corrosion probability of a wellbore string, and the device for detecting corrosion probability of a wellbore string may be integrated in a detection apparatus. For example, referring to fig. 1, the method for detecting the corrosion probability of a wellbore string may include:
s101, lithologic density data, matrix shale content data and longitudinal crack development data of a reservoir of a well to be detected, in which a well pipe column to be detected is located, are detected respectively.
For example, when lithologic density data of a reservoir to be logged is detected, lithologic density data of the reservoir to be logged may be determined by using an acoustic detection technique according to an acoustic time difference of a fed back acoustic signal, and of course, lithologic density data of the reservoir to be logged may also be obtained by other manners.
For example, when detecting matrix muddy content data of a reservoir to be logged, a gamma ray energy spectrum of the reservoir to be logged can be obtained through natural gamma energy spectrum logging, and the matrix muddy content data of the reservoir to be logged can be determined.
For example, when longitudinal fracture development data of a reservoir to be logged is detected, the longitudinal fracture development data of the reservoir to be logged can be determined by a formation micro-resistivity scanning imaging technology, and of course, the longitudinal fracture development data of the reservoir to be logged can also be obtained by other imaging modes.
After the lithologic density data, matrix shale content data, and longitudinal fracture development data of the reservoir of the well to be tested, in which the wellbore string to be tested is located, are detected, respectively, the following S102 may be executed:
S102, determining phase section information of the reservoir to be logged according to lithologic density data and longitudinal crack development data of the reservoir to be logged.
For example, when determining phase information of the reservoir to be logged according to lithology density data and longitudinal fracture development data of the reservoir to be logged, matrix permeability data corresponding to matrix porosity data of the reservoir to be logged may be determined according to lithology density data of the reservoir to be logged; and determining phase section information of the reservoir to be logged according to matrix permeability data corresponding to the matrix porosity data of the reservoir to be logged and longitudinal crack development data.
For example, when determining matrix permeability data corresponding to matrix porosity data of a reservoir to be logged according to lithology density data of the reservoir to be logged, the matrix porosity data of the reservoir to be logged may be determined according to lithology density data of the reservoir to be logged, and the matrix porosity data of the reservoir to be logged and the correspondence between the matrix porosity data and the permeability data may be determined according to the matrix porosity data of the reservoir to be logged, for example, the correspondence between the matrix porosity data and the permeability data may be k=0.0229 xe 0.2092Ф Wherein K represents matrix permeability data, phi represents matrix porosity data, and matrix permeability data corresponding to the matrix porosity data of the reservoir to be logged is determined.
After matrix permeability data corresponding to the matrix porosity data of the reservoir to be logged are determined, phase section information of the reservoir to be logged can be determined according to the matrix permeability data corresponding to the matrix porosity data of the reservoir to be logged and longitudinal fracture development data. By way of example, the phase to which the reservoir to be logged belongs may include a fracture system permeable phase, a matrix reservoir permeable phase, and a matrix reservoir diffusion phase. Wherein the fracture system permeable phase is a concentrated development phase of the fracture and the matrix reservoir permeable phase and the matrix reservoir diffusion phase are non-development phases of the fracture, but the matrix permeabilities of the matrix reservoir permeable phase and the matrix reservoir diffusion phase are not the same. Based on the description of the phase sections, the corresponding phase section information of the reservoir to be logged can comprise thickness information of the permeable phase section of the fracture system, thickness information of the permeable phase section of the matrix reservoir and thickness information of the diffusion phase section of the matrix reservoir.
And S103, determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and the matrix argillaceous content data.
It should be noted that, based on the description about the phase section information to which the reservoir to be logged belongs in S102, the matrix clay content data may include average clay content information of the permeable phase section of the fracture system, average clay content information of the permeable phase section of the matrix reservoir, and average clay content information of the diffusion phase section of the matrix reservoir.
For example, when determining the corrosion probability of a well pipe column to be detected according to phase section information of a reservoir to be detected and matrix shale content data, firstly, taking a weighted average value of matrix shale information of different well sections of different phases to obtain average shale content information corresponding to the different phases; and then according to the formulaCalculating the corrosion probability of the well pipe column to be detected, wherein F represents the corrosion probability of the well pipe column to be detected, and h 1 Thickness information indicating a permeable phase section of a fracture system, h 2 Information indicating thickness of the permeable phase section of the matrix reservoir, h 3 Thickness information representing diffusion phase section of matrix reservoir, < >>Information indicating the average clay content of the permeable phase section of the fracture system>Information indicating the average argillaceous content of the permeable phase section of the matrix reservoir,/for>Average shale content information representing the diffusion phase section of the matrix reservoir.
It should be noted that, when determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and the matrix clay content data, if the zone where the reservoir to be detected is a side water zone, the water outlet risk correction is further required to be performed on the determined corrosion probability of the well pipe column to be detected. The method comprises the following steps: the risk correction coefficient of the water outlet of the bottom water and gas reservoir in the side water section can be determined first, and the ratio of the corrosion probability of the well bore pipe column to be detected to the risk correction coefficient is calculated; and determining the ratio as the target probability of corrosion of the well pipe column to be detected, wherein the target probability is the predicted corrosion probability of the well pipe column to be detected. If the section where the reservoir to be measured is located is not a side water section, the water outlet risk correction is not needed for the determined corrosion probability of the well pipe column to be measured, and the calculated probability according to the phase section information of the reservoir to be measured and the matrix argillaceous content data is the corrosion probability of the well pipe column to be measured.
S104, outputting corresponding prompt information according to the corrosion probability of the well pipe column to be detected.
The prompting information may be, for example, a voice prompting information or a text prompting information, or may, of course, be an image prompting information, or may specifically be set according to actual needs, where the output form of the prompting information is not limited further.
Outputting corresponding prompt information according to the corrosion probability of the well pipe column to be detected, and outputting first prompt information if the corrosion probability of the well pipe column to be detected is smaller than a preset threshold value; the first prompt information is used for indicating that the corrosion probability of the well pipe column to be detected is low; outputting second prompt information if the corrosion probability of the well bore pipe column to be detected is greater than or equal to a preset threshold value; the second prompt information is used for indicating that the corrosion probability of the well pipe column to be detected is higher. The preset threshold value may be set according to actual needs, where the value of the preset threshold value is not limited further.
Therefore, according to the method for detecting the corrosion probability of the well pipe column, when the corrosion probability of the well pipe column is detected, lithologic density data, matrix clay content data and longitudinal crack development data of a well reservoir to be detected, in which the well pipe column to be detected is located, are detected respectively; determining phase section information of the reservoir to be logged according to lithologic density data and longitudinal crack development data of the reservoir to be logged; determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and matrix argillaceous content data; according to the corrosion probability of the well pipe column to be detected, corresponding prompt information is output, so that a worker can acquire the corrosion probability of the well pipe column according to the prompt information, and the pipe material of the well pipe column is selected in a targeted manner according to the corrosion probability of the well pipe column, and the accuracy of well pipe column selection is improved.
In order to facilitate understanding of the method for detecting corrosion probability of a wellbore tubular column provided in the embodiment of the present application, a deep ultra-high pressure bottom water-gas reservoir of a basin in the western China is configured as a east-west short axis anticline, and a major axis A, B, C3 well is configured as an example, and fig. 2 is an exemplary schematic diagram of planing surface of a water-gas reservoir of a basin in the western China. The lithologic density data, matrix argillaceous content data and longitudinal crack development data of a reservoir of a well to be detected, where a A, B, C well shaft pipe column is located, are respectively detected by utilizing a sound wave detection technology, a natural gamma energy spectrum and a scanning imaging technology, the matrix porosity data of the reservoir to be detected is obtained according to the lithologic density data of the reservoir to be detected, and the corresponding relation K=0.0229×e between the matrix porosity data and the matrix permeability data is adopted 0.2092Ф Determining matrix permeability data; longitudinal fracture development data are fracture density data, and are exemplified by table 1, table 2, and table 3, table 1, table 2, and table 3 showing matrix porosity data and longitudinal fracture development data for a reservoir of a test well in which A, B, C well bore strings are located.
TABLE 1
TABLE 2
TABLE 3 Table 3
The matrix porosity data and the longitudinal fracture development data of the reservoir of the well to be tested, in which the well wellbore tubular columns of A, B, C wells are located, given in table 1, table 2 and table 3 are combined, and the phase section information corresponding to the reservoir of A, B, C wells can be correspondingly determined, and specifically, see table 4, table 5 and table 6.
TABLE 4 Table 4
| Well number (m) | Well section (m) | Thickness (m) | Phase section type |
| A | 6090-6095 | 5 | Matrix reservoir diffusion phase section |
| A | 6095-6110 | 15 | Seepage phase section of fracture system |
| A | 6110-6130 | 20 | Matrix reservoir diffusion phase section |
| A | 6130-6135 | 5 | Matrix reservoir permeable phase section |
| A | 6135-6140 | 5 | Matrix reservoir diffusion phase section |
TABLE 5
| Well number (m) | Well section (m) | Thickness (m) | Phase section type |
| B | 6000-6015 | 15 | Seepage phase section of fracture system |
| B | 6015-6020 | 5 | Matrix reservoir permeable phase section |
| B | 6020-6035 | 15 | Seepage phase section of fracture system |
| B | 6035-6040 | 5 | Matrix reservoir diffusion phase section |
| B | 6040-6050 | 10 | Matrix reservoir permeable phase section |
TABLE 6
| Well number (m) | Well section (m) | Thickness (m) | Phase section type |
| C | 6050-6060 | 10 | Matrix reservoir permeable phase section |
| C | 6060-6070 | 10 | Seepage phase section of fracture system |
| C | 6070-6085 | 10 | Matrix reservoir permeable phase section |
| C | 6085-6090 | 15 | Matrix reservoir diffusion phase section |
| C | 6090-6100 | 5 | Seepage phase section of fracture system |
It can be understood that the reservoir phase sections corresponding to different well sections are different, and the average shale content information of each phase section can be correspondingly determined A, B, C by combining the matrix shale content data of the reservoir to be measured of the well where the A, B, C well shaft pipe column is located given in table 1, table 2 and table 3, wherein the average shale content information of each phase section is obtained by taking a weighted average of the differential matrix shale content data information of the well section. According to the thickness information of each phase section of A, B, C well and the average clay content data, the method passes through the formula The probability of corrosion of the well bore string of A, B, C well was calculated and determined and is shown in table 7.
TABLE 7
It can be understood that, since A, B, C wells are all side reservoirs, the determined corrosion probability of the well bore needs to be corrected for water outlet risk, specifically: and determining A, B, C a risk correction coefficient of the well according to the gas reservoir gas column height and the water-avoiding height of the well A, B, C, and determining A, B, C a corrected well pipe corrosion probability according to the risk correction coefficient and the well pipe corrosion probability, wherein the result can be seen in table 8.
TABLE 8
From the corrected wellbore string corrosion probabilities obtained in table 8, the risk of A, B, C well wellbore string corrosion can be determined, specifically: the corrosion probability of the well A after correction is larger than a preset threshold value, which indicates that the well pipe column of the well A is corroded, and the pipe of the well A needs to be optimized; the corrosion probability of the corrected well B is smaller than a preset threshold value, and the fact that the risk of determining that the well pipe columns of the well B and the well C3 are corroded is smaller is indicated that optimization of the well pipe columns of the well B and the well C3 is not needed, corresponding prompt information is output, so that staff can obtain the corrosion probability of the well pipe columns according to the prompt information, the well pipe columns can be selected in a targeted mode according to the corrosion probability of the well pipe columns, and accordingly accuracy of well pipe column selection is improved.
Fig. 3 is a schematic structural diagram of a device 30 for detecting corrosion probability of a wellbore string according to an embodiment of the present application, and as shown in fig. 3, for example, the device 30 for detecting corrosion probability of a wellbore string may include:
the detection unit 301 is configured to detect lithologic density data, matrix clay content data and longitudinal fracture development data of a reservoir of a well to be detected, where the wellbore tubular column to be detected is located, respectively.
The processing unit 302 is configured to determine phase information to which the reservoir to be logged belongs according to lithology density data and longitudinal fracture development data of the reservoir to be logged; and determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir to be detected and the matrix argillaceous content data.
And the prompting unit 303 is used for outputting corresponding prompting information according to the corrosion probability of the well pipe column to be detected.
Optionally, the prompting unit 303 is specifically configured to output a first prompting message if the corrosion probability of the wellbore tubular column to be detected is less than a preset threshold; the first prompt information is used for indicating that the corrosion probability of the well pipe column to be detected is low; outputting second prompt information if the corrosion probability of the well bore pipe column to be detected is greater than or equal to a preset threshold value; the second prompt information is used for indicating that the corrosion probability of the well pipe column to be detected is higher.
Optionally, the phase section information comprises thickness information of a permeable phase section of the fracture system, thickness information of a permeable phase section of the matrix reservoir, and thickness information of a diffusion phase section of the matrix reservoir; correspondingly, the matrix shale content data comprises average shale content information of a permeable phase section of the fracture system, average shale content information of a permeable phase section of the matrix reservoir, and average shale content information of a diffusion phase section of the matrix reservoir.
Optionally, the processing unit 302 is specifically configured to, according to the followingDetermining the corrosion probability of a well pipe column to be detected; wherein F represents the corrosion probability of the well pipe column to be detected, h 1 Thickness information indicating a permeable phase section of a fracture system, h 2 Information indicating thickness of the permeable phase section of the matrix reservoir, h 3 Thickness information representing the diffusion phase section of the matrix reservoir,information indicating the average clay content of the permeable phase section of the fracture system>Information indicating the average argillaceous content of the permeable phase section of the matrix reservoir,/for>Average shale content information representing the diffusion phase section of the matrix reservoir.
Optionally, if the area where the reservoir to be logged is currently located is a side water area, the apparatus 30 for detecting the corrosion probability of the wellbore string further includes a correction unit:
and the correction unit 304 is used for determining a risk correction coefficient of the bottom water reservoir water in the side water section, and correcting the corrosion probability of the well pipe column to be detected according to the risk correction coefficient to obtain the target corrosion probability of the well pipe column to be detected.
Optionally, the correction unit 304 is specifically configured to calculate a ratio of the corrosion probability of the wellbore tubular string to be detected to the risk correction coefficient, and determine the ratio as the target probability of corrosion of the wellbore tubular string to be detected.
Optionally, the processing unit 302 is specifically configured to determine matrix porosity data of the reservoir to be logged according to lithologic density data of the reservoir to be logged; according to the matrix porosity data of the reservoir to be logged and the corresponding relation between the matrix porosity data and the permeability data, determining matrix permeability data corresponding to the matrix porosity data of the reservoir to be logged; and determining phase section information of the reservoir to be logged according to matrix permeability data corresponding to the matrix porosity data of the reservoir to be logged and longitudinal crack development data.
The device for detecting the corrosion probability of the well pipe column provided by the embodiment of the application can execute the technical scheme of the method for detecting the corrosion probability of the well pipe column in any embodiment, and the implementation principle and the beneficial effects of the device are similar to those of the method for detecting the corrosion probability of the well pipe column, and can refer to the implementation principle and the beneficial effects of the method for detecting the corrosion probability of the well pipe column, and redundant description is omitted here.
Fig. 4 is a schematic structural diagram of another apparatus 40 for detecting a corrosion probability of a wellbore string according to an embodiment of the present application, and as shown in fig. 4, the apparatus 40 for detecting a corrosion probability of a wellbore string may include a processor 401 and a memory 402; wherein,
the memory 402 is used for storing a computer program.
The processor 401 is configured to read the computer program stored in the memory 402, and execute the technical scheme of the method for detecting the corrosion probability of the wellbore tubular column in any of the foregoing embodiments according to the computer program in the memory 402.
Alternatively, the memory 402 may be separate or integrated with the processor 401. When the memory 402 is separate from the processor 401, the apparatus 40 for detecting a probability of corrosion of a wellbore string may further comprise: a bus for connecting the memory 402 and the processor 401.
Optionally, the present embodiment further includes: a communication interface, which may be connected to the processor 401 via a bus. The processor 401 may control the communication interface to perform the functions described above for the reception and transmission of the apparatus 40 for detecting the probability of corrosion of the wellbore string.
The device 40 for detecting the corrosion probability of the wellbore pipe column according to the embodiment of the present invention may implement the technical scheme of the method for detecting the corrosion probability of the wellbore pipe column according to any of the embodiments described above, and the implementation principle and the beneficial effects of the method for detecting the corrosion probability of the wellbore pipe column are similar to those of the method for detecting the corrosion probability of the wellbore pipe column, and may refer to the implementation principle and the beneficial effects of the method for detecting the corrosion probability of the wellbore pipe column, and will not be described herein.
The embodiment of the invention also provides a computer readable storage medium, in which computer execution instructions are stored, when a processor executes the computer execution instructions, the technical scheme of the method for detecting the corrosion probability of the well pipe column in any embodiment is realized, the implementation principle and the beneficial effects of the method are similar to those of the well pipe column, and the implementation principle and the beneficial effects of the method for detecting the corrosion probability of the well pipe column can be seen, so that the description is omitted herein.
In the several embodiments provided by the present invention, it should be understood that the disclosed apparatus and method may be implemented in other manners. For example, the apparatus embodiments described above are merely illustrative, e.g., the division of the units is merely a logical function division, and there may be additional divisions when actually implemented, e.g., multiple units or components may be combined or integrated into another system, or some features may be omitted or not performed. Alternatively, the coupling or direct coupling or communication connection illustrated or discussed with each other may be an indirect coupling or communication connection via some interfaces, devices or units, which may be in electrical, mechanical or other form.
The units described as separate units may or may not be physically separate, and units shown as units may or may not be physical units, may be located in one place, or may be distributed on a plurality of network units. Some or all of the units may be selected according to actual needs to achieve the purpose of the solution of this embodiment. In addition, each functional unit in the embodiments of the present invention may be integrated in one processing unit, or each unit may exist alone physically, or two or more units may be integrated in one unit. The integrated units may be implemented in hardware or in hardware plus software functional units.
The integrated modules, which are implemented in the form of software functional modules, may be stored in a computer readable storage medium. The software functional module is stored in a storage medium, and includes several instructions for causing a computer device (which may be a personal computer, a server, or a network device, etc.) or a processor (english: processor) to perform some steps of the methods of the embodiments of the invention.
It should be understood that the above processor may be a central processing unit (english: central Processing Unit, abbreviated as CPU), or may be other general purpose processors, digital signal processors (english: digital Signal Processor, abbreviated as DSP), application specific integrated circuits (english: application Specific Integrated Circuit, abbreviated as ASIC), or the like. A general purpose processor may be a microprocessor or the processor may be any conventional processor or the like. The steps of a method disclosed in connection with the present invention may be embodied directly in a hardware processor for execution, or in a combination of hardware and software modules in a processor for execution.
The memory may comprise a high-speed RAM memory, and may further comprise a non-volatile memory NVM, such as at least one magnetic disk memory, and may also be a U-disk, a removable hard disk, a read-only memory, a magnetic disk or optical disk, etc.
The bus may be an industry standard architecture (Industry Standard Architecture, ISA) bus, an external device interconnect (Peripheral Component, PCI) bus, or an extended industry standard architecture (Extended Industry Standard Architecture, EISA) bus, among others. The buses may be divided into address buses, data buses, control buses, etc. For ease of illustration, the buses in the drawings of the present invention are not limited to only one bus or to one type of bus.
The computer-readable storage medium described above may be implemented by any type or combination of volatile or non-volatile memory devices, such as Static Random Access Memory (SRAM), electrically erasable programmable read-only memory (EEPROM), erasable programmable read-only memory (EPROM), programmable read-only memory (PROM), read-only memory (ROM), magnetic memory, flash memory, magnetic or optical disk. A storage media may be any available media that can be accessed by a general purpose or special purpose computer.
Finally, it should be noted that: the above embodiments are only for illustrating the technical solution of the present invention, and not for limiting the same; although the invention has been described in detail with reference to the foregoing embodiments, it will be understood by those of ordinary skill in the art that: the technical scheme described in the foregoing embodiments can be modified or some or all of the technical features thereof can be replaced by equivalents; such modifications and substitutions do not depart from the spirit of the invention.
Claims (12)
1. A method of detecting a probability of a wellbore string being corroded, the method comprising:
respectively detecting lithologic density data, matrix argillaceous content data and longitudinal crack development data of a reservoir of a well to be detected, in which a well pipe column to be detected is located;
Determining phase section information of the reservoir of the well to be tested according to lithologic density data of the reservoir of the well to be tested and the longitudinal fracture development data;
determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir of the well to be detected and the matrix argillaceous content data;
outputting corresponding prompt information according to the corrosion probability of the well pipe column to be detected;
determining the corrosion probability of the well pipe column to be detected according to the phase section information of the well reservoir to be detected and the matrix argillaceous content data, wherein the determining comprises the following steps:
according toDetermining the corrosion probability of the well pipe column to be detected;
wherein F represents the corrosion probability of the well pipe column to be detected, h 1 Thickness information indicating a permeable phase section of a fracture system, h 2 Information indicating thickness of the permeable phase section of the matrix reservoir, h 3 Thickness information representing the diffusion phase section of the matrix reservoir,information indicating the average clay content of the permeable phase section of the fracture system>Information representing the average shale content of the permeable phase section of the matrix reservoir,average shale content information representing a matrix reservoir diffusion phase section;
determining phase section information of the reservoir of the well to be tested according to lithology density data of the reservoir of the well to be tested and the longitudinal fracture development data, wherein the phase section information comprises the following steps:
Determining matrix porosity data of the reservoir of the well to be tested according to lithologic density data of the reservoir of the well to be tested;
determining matrix permeability data corresponding to the matrix porosity data of the well reservoir to be tested according to the matrix porosity data of the well reservoir to be tested and the corresponding relation between the matrix porosity data and the permeability data;
and determining phase section information of the reservoir of the well to be tested according to matrix permeability data corresponding to the matrix porosity data of the reservoir of the well to be tested and the longitudinal fracture development data.
2. The method of claim 1, wherein outputting a corresponding hint information based on the probability of corrosion of the wellbore tubular string to be detected comprises:
outputting first prompt information if the corrosion probability of the well pipe column to be detected is smaller than a preset threshold value; the first prompt message is used for indicating that the corrosion probability of the well pipe column to be detected is low;
outputting second prompt information if the corrosion probability of the well bore pipe column to be detected is greater than or equal to a preset threshold value; and the second prompt information is used for indicating that the to-be-detected well pipe column has higher corrosion probability.
3. The method of claim 1, wherein the step of determining the position of the substrate comprises,
The phase section information comprises thickness information of a permeable phase section of a fracture system, thickness information of a permeable phase section of a matrix reservoir, and thickness information of a diffusion phase section of the matrix reservoir; correspondingly, the matrix shale content data comprises average shale content information of a permeable phase section of the fracture system, average shale content information of a permeable phase section of the matrix reservoir and average shale content information of a diffusion phase section of the matrix reservoir.
4. The method of claim 1, wherein if the zone in which the well reservoir to be tested is currently located is a side water zone, the method further comprises:
determining a risk correction coefficient of bottom water and gas reservoir water in the side water section;
and correcting the corrosion probability of the well pipe column to be detected according to the risk correction coefficient to obtain the target probability of corrosion of the well pipe column to be detected.
5. The method of claim 4, wherein correcting the corrosion probability of the wellbore tubular string to be detected based on the risk correction factor yields a target probability of corrosion of the wellbore tubular string to be detected, comprising:
calculating the ratio of the corrosion probability of the well pipe column to be detected to the risk correction coefficient;
And determining the ratio as the target probability of corrosion of the well pipe column to be detected.
6. A device for detecting the probability of a wellbore string being corroded, the device comprising:
the detection unit is used for respectively detecting lithologic density data, matrix argillaceous content data and longitudinal crack development data of a reservoir of the well to be detected, in which the well pipe column to be detected is located;
the processing unit is used for determining phase section information of the reservoir of the well to be tested according to lithology density data of the reservoir of the well to be tested and the longitudinal crack development data; determining the corrosion probability of the well pipe column to be detected according to the phase section information of the reservoir of the well to be detected and the matrix argillaceous content data;
the prompting unit is used for outputting corresponding prompting information according to the corrosion probability of the well pipe column to be detected;
the processing unit is specifically configured toDetermining the corrosion probability of the well pipe column to be detected;
wherein F represents the corrosion probability of the well pipe column to be detected, h 1 Thickness information indicating a permeable phase section of a fracture system, h 2 Information indicating thickness of the permeable phase section of the matrix reservoir, h 3 Thickness information representing the diffusion phase section of the matrix reservoir, Information indicating the average clay content of the permeable phase section of the fracture system>Information representing the average shale content of the permeable phase section of the matrix reservoir,average shale content information representing a matrix reservoir diffusion phase section;
the processing unit is specifically configured to determine matrix porosity data of the reservoir of the well to be tested according to lithologic density data of the reservoir of the well to be tested; determining matrix permeability data corresponding to the matrix porosity data of the well reservoir to be tested according to the matrix porosity data of the well reservoir to be tested and the corresponding relation between the matrix porosity data and the permeability data; and determining phase section information of the reservoir of the well to be tested according to matrix permeability data corresponding to the matrix porosity data of the reservoir of the well to be tested and the longitudinal fracture development data.
7. The apparatus of claim 6, wherein the device comprises a plurality of sensors,
the prompting unit is specifically configured to output a first prompting message if the corrosion probability of the wellbore tubular column to be detected is less than a preset threshold value; the first prompt message is used for indicating that the corrosion probability of the well pipe column to be detected is low;
the prompting unit is specifically configured to output a second prompting message if the corrosion probability of the wellbore tubular column to be detected is greater than or equal to a preset threshold value; and the second prompt information is used for indicating that the to-be-detected well pipe column has higher corrosion probability.
8. The apparatus of claim 7, wherein the device comprises a plurality of sensors,
the phase section information comprises thickness information of a permeable phase section of a fracture system, thickness information of a permeable phase section of a matrix reservoir, and thickness information of a diffusion phase section of the matrix reservoir; correspondingly, the matrix shale content data comprises average shale content information of a permeable phase section of the fracture system, average shale content information of a permeable phase section of the matrix reservoir and average shale content information of a diffusion phase section of the matrix reservoir.
9. The apparatus of claim 6, wherein if the zone in which the well reservoir to be tested is currently located is a side water zone, the apparatus further comprises a correction unit:
the correcting unit is used for determining a risk correction coefficient of bottom water gas reservoir water in the side water section, correcting the corrosion probability of the well pipe column to be detected according to the risk correction coefficient, and obtaining the target probability of corrosion of the well pipe column to be detected.
10. The apparatus of claim 9, wherein the device comprises a plurality of sensors,
the correction unit is specifically configured to calculate a ratio of the corrosion probability of the well pipe string to be detected to the risk correction coefficient, and determine the ratio as a target probability of corrosion of the well pipe string to be detected.
11. A device for detecting corrosion probability of a well bore string, which is characterized by comprising a memory and a processor; wherein,
the memory is used for storing a computer program;
the processor is configured to read the computer program stored in the memory, and execute the method for detecting the corrosion probability of the wellbore string according to any one of claims 1-5 according to the computer program stored in the memory.
12. A computer readable storage medium having stored therein computer executable instructions which, when executed by a processor, implement the method of detecting the probability of a wellbore string being corroded according to any one of claims 1-5.
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| CN103091234A (en) * | 2011-11-03 | 2013-05-08 | 中国石油天然气股份有限公司 | Method for evaluating corrosion status of well cement ring in acid gas reservoir well |
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