Method, device, medium and equipment for predicting in-situ permeability of high-temperature and high-pressure reservoir
By establishing functional relationships between the in situ penetration of the reservoir and the surface penetration rate, temperature, and pressure, the problem of difficulty prediction of the in situ penetration of high -temperature and high pressure reservoirs is solved, and the economy of oil and gas can be collected and mining economy. Accurate assessment.
Patent Information
- Application Number
- CN202411760356.5
- Authority / Receiving Office
- CN · China
- Patent Type
- Applications(China)
- Current Assignee / Owner
- Filing Date
- 2024-12-03
- Publication Date
- 2025-01-24
AI Technical Summary
The prior art is difficult to accurately predict the in-situ permeability of high-temperature and high-pressure reservoirs, which makes it difficult to evaluate the recoverable amount and mining economy of oil and gas reservoirs.
By establishing functional relationships between the in situ penetration of the reservoir and the surface penetration rate, temperature, and pressure, the flow test data and fluid properties are used to calculate and predict the in situ penetration rate of the reservoir.
The accurate prediction of the in situ penetration rate of reservoirs under the temperature and pressure of oil and gas hidden, and improved the accuracy and economy of oil and gas exploration and development.
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Figure CN119352965A_ABST
Abstract
Description
Technical Field
[0001] The present invention relates to the technical field of oil and gas exploitation, and in particular to a method, device, medium and equipment for predicting in-situ permeability of a high-temperature and high-pressure reservoir. Background Art
[0002] The permeability of the reservoir is directly related to the recoverable amount of oil and gas resources and the economic feasibility of mining. Accurately predicting the permeability helps to reasonably evaluate the value of oil and gas reservoirs and provide a key basis for investment decisions in exploration and development. The permeability (surface permeability) obtained from core testing helps to understand the fluidity inside the reservoir, but the difference between surface permeability and in-situ (underground) fluidity is a common problem in the fields of oil and gas reservoir geology and hydrogeology. This difference is mainly caused by the following reasons:
[0003] Differences in measurement conditions: Surface permeability is usually obtained from laboratory test samples, which may have undergone physical structural changes during collection, processing and testing, such as dehydration, compaction or fracture closure, resulting in deviations from the actual underground in situ conditions.
[0004] Scale effect: The sample scale of laboratory testing is much smaller than the scale of the actual underground reservoir. The permeability at a small scale may not accurately represent the fluid flow characteristics at a large scale. The heterogeneity within the reservoir, such as pore size distribution, fracture network, and bedding structure, controls the fluidity more significantly at a large scale.
[0005] Influence of fluid properties: Clean water is often used as the fluid in laboratory tests, while underground fluids may contain dissolved minerals, organic matter, etc. These substances will affect the viscosity of the fluid and its interaction with rocks, thereby affecting the actual fluidity.
[0006] In-situ stress state: Rocks deep underground are subject to high confining pressure and tectonic stress, which affects the porosity and permeability of the rocks. It is difficult to fully simulate this complex stress environment under laboratory conditions.
[0007] Chemical and biological effects: In underground environments, chemical reactions between fluids and rocks (such as mineral dissolution and precipitation) and microbial activity can change the permeability of rocks. These processes are not usually reflected in surface testing.
[0008] Time scale considerations: In situ flow also involves long-term processes, such as compaction and dissolution on geological time scales, which have a cumulative effect on permeability that is difficult to reflect in short-term surface tests.
[0009] In view of these factors, the in-situ permeability of reservoirs has always been an important research issue in the field of oil and gas exploration and development. The in-situ permeability of reservoirs can generally be evaluated through flow testing. In actual operations, the R&D cost of high-precision in-situ testing technology and equipment is high, and direct measurement data is limited. In addition, high temperature, high pressure, strong heterogeneity and reservoirs containing complex mineral components make permeability measurement and prediction extremely difficult, making it difficult to obtain an overall understanding of the in-situ permeability of high-temperature and high-pressure oil and gas reservoirs.
[0010] Due to the difficulty in obtaining in-situ permeability test data, overburden porosity testing is generally used to indirectly evaluate reservoir permeability. The core samples used in the overburden porosity technology have undergone a sudden drop in temperature and pressure when they were extracted from oil and gas reservoirs. The change in the internal structure of the rock in this process is usually simply considered to be the increase in rock expansion and porosity, so the reservoir pressure state is attempted to be restored by overburdening. However, during the pressure reduction process of the core being taken out, the expansion of its skeleton particles should be in all directions, that is, it also includes expansion into the pore space. Based on this principle, the relationship between the pore structure of the surface core and the in-situ reservoir has yet to be analyzed. And overburden porosity testing generally does not involve temperature.
[0011] In summary, there is an urgent need to study an in-situ permeability prediction method for high-temperature and high-pressure reservoirs. Summary of the invention
[0012] In view of the above problems, the purpose of the present invention is to provide a method, device, medium and equipment for predicting the in-situ permeability of high-temperature and high-pressure reservoirs, by establishing a functional relationship between the in-situ permeability of the reservoir and the surface permeability (or conventional permeability of the core), temperature and pressure, so as to determine the in-situ permeability of the reservoir under the temperature and pressure conditions of the oil and gas reservoir.
[0013] To achieve the above object, the present invention adopts the following technical solutions:
[0014] The in-situ permeability prediction method of a high-temperature and high-pressure reservoir according to the present invention comprises the following steps:
[0015] Calculate the in-situ permeability of the reservoir using the fluidity data in the fluidity test data and the fluid property data under the temperature and pressure conditions of the measuring point;
[0016] Obtain the surface physical property test data of the core or wall core sample of the single well corresponding to the fluidity test at the fluidity test depth, and list it together with the in-situ permeability calculated by the fluidity test, and also list the measured data of depth, temperature, pressure, and lithology;
[0017] The in-situ permeability calculated by the flow test is used as the dependent variable, and the temperature T, pressure P, and surface test permeability are used as independent variables to establish a three-variable fitting function.
[0018] Using the fitting function, in-situ permeability prediction is carried out for high-temperature and high-pressure reservoirs with similar conditions without fluidity testing.
[0019] The in-situ permeability prediction method for high-temperature and high-pressure reservoirs preferably also includes the following steps: if there is no clear functional relationship in the overall fitting of the data points, segmented fitting is performed by distinguishing blocks, layers, lithologies, and reservoir physical property intervals to obtain a more targeted in-situ permeability prediction function.
[0020] In the high-temperature and high-pressure reservoir in-situ permeability prediction method, preferably, the calculation formula for calculating the in-situ permeability of the reservoir is:
[0021]
[0022] In the formula, k res is the in-situ permeability of the reservoir; f res is the fluidity obtained by the test; μ res is the fluid viscosity under the temperature and pressure conditions of the measuring point.
[0023] In the high-temperature and high-pressure reservoir in-situ permeability prediction method, preferably, the establishment of a ternary fitting function is specifically:
[0024] k res =f(P,T,k) (2)
[0025] In the formula, k res is the in-situ permeability of the reservoir; P is the reservoir pressure at the mobility measurement point; T is the reservoir temperature at the mobility measurement point; k is the surface permeability of the core sample corresponding to the mobility measurement point.
[0026] The present invention also provides a high-temperature and high-pressure reservoir in-situ permeability prediction device, comprising:
[0027] The first processing unit is used to calculate the in-situ permeability of the reservoir using the fluidity data in the fluidity test data and the fluid property data under the temperature and pressure conditions of the measuring point;
[0028] The second processing unit is used to obtain the surface physical property test data of the core or wall core sample of the single well corresponding to the fluidity test at the fluidity test depth, and list them together with the in-situ permeability calculated by the fluidity test, and also list the measured data of depth, temperature, pressure and lithology;
[0029] The third processing unit is used to establish a ternary fitting function with the in-situ permeability obtained by the fluidity test as the dependent variable and the temperature T, the pressure P and the surface test permeability as the independent variables;
[0030] The fourth processing unit is used to use the fitting function to carry out in-situ permeability prediction for high-temperature and high-pressure reservoirs with similar conditions without fluidity testing.
[0031] The present invention also provides a computer storage medium on which a computer program is stored. When the computer program is executed by a processor, the steps of the high-temperature and high-pressure reservoir in-situ permeability prediction method are implemented.
[0032] The present invention also provides a computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of the high-temperature and high-pressure reservoir in-situ permeability prediction method when executing the computer program.
[0033] The present invention adopts the above technical solution, which has the following advantages:
[0034] (1) The calculation parameters used in the present invention, such as reservoir temperature, reservoir pressure, and surface permeability, are commonly used data in oil and gas reservoir research, and the data acquisition is convenient and complete;
[0035] (2) The prediction function adopted by the present invention is easy to fit, has wide applicability, strong practicality, and is easy to operate. There is no similar research at present. BRIEF DESCRIPTION OF THE DRAWINGS
[0036] Various other advantages and benefits will become apparent to those of ordinary skill in the art by reading the following detailed description of the preferred embodiment.The drawings are only for the purpose of illustrating the preferred embodiments and are not to be construed as limiting the invention.
[0037] Throughout the drawings, the same reference numerals are used to denote the same components. In the drawings:
[0038] Figure 1 It is a flow chart of the present invention. DETAILED DESCRIPTION
[0039] The exemplary embodiments of the present invention will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present invention are shown in the accompanying drawings, it should be understood that the present invention can be implemented in various forms and should not be limited by the embodiments described herein. On the contrary, these embodiments are provided in order to enable a more thorough understanding of the present invention and to fully convey the scope of the present invention to those skilled in the art.
[0040] The present invention provides a method for predicting the in-situ permeability of a high-temperature and high-pressure reservoir, by establishing a functional relationship between the in-situ permeability of the reservoir and the surface permeability (or conventional permeability of the core), temperature and pressure, so as to determine the in-situ permeability of the reservoir under the temperature and pressure conditions of the oil and gas reservoir.
[0041] like Figure 1 As shown, the in-situ permeability prediction method of high-temperature and high-pressure reservoirs described in the present invention comprises the following steps:
[0042] S1. Calculate the in-situ permeability of the reservoir using the fluidity data in the fluidity test data and the fluid property data under the temperature and pressure conditions of the measuring point;
[0043] S2. Obtain the surface physical property test data of the core or wall core sample of the single well corresponding to the fluidity test at the fluidity test depth, list them together with the in-situ permeability calculated by the fluidity test, and list the measured data of depth, temperature, pressure, and lithology at the same time;
[0044] S3, using the in-situ permeability obtained by the flow test as the dependent variable, and temperature T, pressure P, and surface test permeability as the independent variables, to establish a ternary fitting function;
[0045] S4. Using the fitting function, in-situ permeability prediction is carried out for high-temperature and high-pressure reservoirs with similar conditions without fluidity testing.
[0046] In the above embodiment, preferably, the present invention further comprises the following steps:
[0047] S5. If there is no clear functional relationship in the overall fitting of the data points, segmented fitting is performed based on the blocks, layers, lithology, and reservoir physical property intervals to obtain a more targeted in-situ permeability prediction function.
[0048] In the above embodiment, preferably, the calculation formula for calculating the in-situ permeability of the reservoir is:
[0049]
[0050] In the formula, k res is the in-situ permeability of the reservoir; f res is the fluidity obtained by the test; μ res is the fluid viscosity under the temperature and pressure conditions of the measuring point.
[0051] In the above embodiment, preferably, the establishment of a ternary fitting function is specifically:
[0052] k res =f(P,T,k) (2)
[0053] In the formula, k res is the in-situ permeability of the reservoir; P is the reservoir pressure at the mobility measurement point; T is the reservoir temperature at the mobility measurement point; k is the surface permeability of the core sample corresponding to the mobility measurement point.
[0054] The present invention also provides a high-temperature and high-pressure reservoir in-situ permeability prediction device, comprising:
[0055] The first processing unit is used to calculate the in-situ permeability of the reservoir using the fluidity data in the fluidity test data and the fluid property data under the temperature and pressure conditions of the measuring point;
[0056] The second processing unit is used to obtain the surface physical property test data of the core or wall core sample of the single well corresponding to the fluidity test at the fluidity test depth, and list them together with the in-situ permeability calculated by the fluidity test, and also list the measured data of depth, temperature, pressure and lithology;
[0057] The third processing unit is used to establish a ternary fitting function with the in-situ permeability obtained by the fluidity test as the dependent variable and the temperature T, the pressure P and the surface test permeability as the independent variables;
[0058] The fourth processing unit is used to use the fitting function to carry out in-situ permeability prediction for high-temperature and high-pressure reservoirs with similar conditions without fluidity testing.
[0059] The present invention also provides a computer storage medium on which a computer program is stored. When the computer program is executed by a processor, the steps of the high-temperature and high-pressure reservoir in-situ permeability prediction method are implemented.
[0060] The present invention also provides a computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor implements the steps of the high-temperature and high-pressure reservoir in-situ permeability prediction method when executing the computer program.
[0061] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the aforementioned embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the aforementioned embodiments, or make equivalent replacements for some of the technical features therein. However, these modifications or replacements do not deviate the essence of the corresponding technical solutions from the spirit and scope of the technical solutions of the embodiments of the present invention.
Claims
1. A method for predicting in-situ permeability of high-temperature and high-pressure reservoirs, characterized in that: The steps include: Calculate the in-situ permeability of the reservoir using the mobility data from the mobility test data and the fluid property data under the temperature and pressure conditions of the measuring point; Obtain surface physical property test data of core or wall core samples of a single well corresponding to the fluidity test at the fluidity test depth, and list them together with the in-situ permeability calculated from the fluidity test, along with the measured data of depth, temperature, pressure, and lithology; A three-variable fitting function was established with the in-situ permeability obtained from the fluidity test as the dependent variable and temperature T, pressure P, and surface test permeability as the independent variables. Using the fitting function, in-situ permeability prediction is carried out for high-temperature and high-pressure reservoirs with similar conditions without mobility testing.
2. The in-situ permeability prediction method for high-temperature and high-pressure reservoirs according to claim 1, characterized in that: The method also includes the following steps: if there is no clear functional relationship in the overall fitting of the data points, segmented fitting is performed based on the blocks, layers, lithologies, and reservoir physical property intervals to obtain a more targeted in-situ permeability prediction function.
3. The in-situ permeability prediction method for high-temperature and high-pressure reservoirs according to claim 1, characterized in that: The calculation formula for calculating the in-situ permeability of the reservoir is: Where k res is the in-situ permeability of the reservoir; f res is the fluidity obtained by the test; μ res is the fluid viscosity under the temperature and pressure conditions of the measuring point.
4. The in-situ permeability prediction method for high-temperature and high-pressure reservoirs according to claim 1, characterized in that: The establishment of the ternary fitting function is specifically as follows: k res =f(P,T,k) (2) Where k res is the in-situ permeability of the reservoir; P is the reservoir pressure at the mobility measurement point; T is the reservoir temperature at the mobility measurement point; k is the surface permeability of the core sample corresponding to the mobility measurement point.
5. A device for predicting in-situ permeability of high-temperature and high-pressure reservoirs, characterized in that: include: The first processing unit is used to calculate the in-situ permeability of the reservoir using the mobility data in the mobility test data and the fluid property data under the temperature and pressure conditions of the measuring point; The second processing unit is used to obtain surface physical property test data of core or wall core samples of a single well corresponding to the fluidity test at the fluidity test depth, and list them together with the in-situ permeability calculated by the fluidity test, and also list the measured data of depth, temperature, pressure, and lithology; The third processing unit is used to establish a three-variable fitting function with the in-situ permeability obtained by the fluidity test as the dependent variable and the temperature T, pressure P, and the surface test permeability as the independent variables; The fourth processing unit is used to use the fitting function to carry out in-situ permeability prediction for high-temperature and high-pressure reservoirs with similar conditions without mobility testing.
6. A computer storage medium having a computer program stored thereon, characterized in that: When the computer program is executed by a processor, the steps of the method for predicting in-situ permeability of a high-temperature and high-pressure reservoir according to any one of claims 1 to 4 are implemented.
7. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein: When the processor executes the computer program, the steps of the high-temperature and high-pressure reservoir in-situ permeability prediction method according to any one of claims 1 to 4 are implemented.