Method and device for determining oil-water relative permeability information of medium-high permeability reservoir

Abstract

A method and device for determining oil-water relative permeability information of a medium-high permeability reservoir, relating to the technical field of oil and gas reservoir development. The method comprises: acquiring nuclear magnetic resonance T2 spectrum information of a medium-high permeability reservoir in multiple states (101); determining pore distribution and oil phase distribution on the basis of the nuclear magnetic resonance T2 spectrum information in multiple states (102); using the pore distribution and the oil phase distribution of the medium-high permeability reservoir, combined with the wettability type of a core of the medium-high permeability reservoir, to divide movable oil-water space in the nuclear magnetic resonance T2 spectrum information in multiple states (103); on the basis of the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in multiple states, determining a correspondence between the normalized saturation of the movable oil-water space and a T2 value (104); and on the basis of the correspondence between the normalized saturation of the movable oil-water space and the T2 value, determining an oil-phase relative permeability curve and a water-phase relative permeability curve of the medium-high permeability reservoir (105).

Description

Method and device for determining oil-water relative permeability information of medium- and high-permeability oil reservoirs

[0001] Related applications

[0002] This application claims priority to the Chinese invention patent application with application number 202311852963.X filed on December 28, 2023, and cites the entire contents disclosed in the above patent application as part of this application. Technical Field

[0003] The present application relates to the technical field of oil and gas reservoir development, and in particular to a method and device for determining oil-water relative permeability information of medium- and high-permeability oil reservoirs. Background Art

[0004] This section is intended to provide background or context for the embodiments of the present application. The description herein is not admitted to be prior art by virtue of its inclusion in this section.

[0005] A relative permeability curve describes how the relative permeabilities of different phases of a multiphase fluid flow through a porous medium vary with saturation. Relative permeability curves are essential data for predicting oil and gas field development indicators, formulating development plans, and researching numerical simulation techniques for oil and gas reservoirs.

[0006] At present, the methods for determining relative permeability curves are mainly divided into direct measurement and indirect calculation. Direct measurement is relatively less used due to the existence of end effects and the long measurement period. The non-steady-state method is widely used, but it ignores the influence of capillary forces and assumes that the fluid advances at an isosaturated surface in the core, which is inconsistent with reality. In recent years, nuclear magnetic resonance, as a completely non-destructive visualization technology, has been widely used in the field of petroleum engineering. Studies have found that the capillary pressure converted from the nuclear magnetic resonance T2 spectrum can be used to calculate relative permeability. However, the essence of the existing method of calculating relative permeability using nuclear magnetic resonance T2 spectrum is to use static pore structure to invert the dynamic oil-water flow law. Therefore, it can only make assumptions about the dynamic oil-water flow process, and does not consider the oil-water flow law, which is significantly different from the actual flow process and cannot provide an accurate relative permeability curve. Summary of the Invention

[0007] The present invention provides a method for determining oil-water relative permeability information of a medium-to-high permeability reservoir, which is used to solve the problem that the oil-water flow pattern cannot be considered when determining the existing relative permeability curve, thereby improving the accuracy of the obtained relative permeability curve. The method includes:

[0008] Obtaining nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 value and signal intensity;

[0009] Determine the pore distribution and oil phase distribution information of medium- and high-permeability reservoirs based on multi-state NMR T2 spectrum information;

[0010] By using the pore distribution information and oil phase distribution information of medium- and high-permeability reservoirs, combined with the wetting type of the core of the medium- and high-permeability reservoir, the oil-water movable space is divided in the multi-state nuclear magnetic resonance T2 spectrum information;

[0011] Based on the nuclear magnetic resonance T2 spectrum information of medium- and high-permeability reservoirs under multiple states, the corresponding relationship between the normalized saturation of oil-water movable space and T2 value is determined;

[0012] According to the corresponding relationship between the normalized saturation of oil-water movable space and T2 value, the oil phase relative permeability curve and water phase relative permeability curve of medium-high permeability reservoir are determined.

[0013] The present application also provides a device for determining oil-water relative permeability information of a medium-to-high permeability reservoir, which is used to solve the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve, thereby improving the accuracy of the obtained relative permeability curve. The device includes:

[0014] An acquisition module is used to acquire nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 value and signal intensity;

[0015] An information determination module is used to determine the pore distribution information and oil phase distribution information of the medium- and high-permeability oil reservoir based on the multi-state nuclear magnetic resonance T2 spectrum information;

[0016] A partitioning module is used to use the pore distribution information and oil phase distribution information of medium- and high-permeability reservoirs, combined with the wetting type of the core of the medium- and high-permeability reservoir, to partition the oil-water movable space in the multi-state nuclear magnetic resonance T2 spectrum information;

[0017] The first processing module is used to determine the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value based on the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoir in multiple states;

[0018] The second processing module is used to determine the oil phase relative permeability curve and the water phase relative permeability curve of the medium-high permeability oil reservoir according to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value.

[0019] An embodiment of the present application further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the method for determining the oil-water relative permeability information of the above-mentioned medium- and high-permeability oil reservoir is implemented.

[0020] An embodiment of the present application further provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the above-mentioned method for determining the oil-water relative permeability information of the medium- and high-permeability oil reservoir.

[0021] In an embodiment of the present application, nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states is obtained; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 values ​​and signal intensities; based on the nuclear magnetic resonance T2 spectrum information in multiple states, the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir are determined; using the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir, combined with the wetting type of the core of the medium-to-high permeability oil reservoir, the oil-water movable space is divided in the nuclear magnetic resonance T2 spectrum information in multiple states; based on the nuclear magnetic resonance T2 spectrum information of the medium-to-high permeability oil reservoir in multiple states, the correspondence between the normalized saturation of the oil-water movable space and the T2 value is determined; based on the correspondence between the normalized saturation of the oil-water movable space and the T2 value, the oil phase relative permeability curve and the water phase relative permeability curve of the medium-to-high permeability oil reservoir are determined. Compared with the existing solutions for determining the oil-water relative permeability of medium- and high-permeability reservoirs, the technical solution of the present application can solve the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve, thereby improving the accuracy of the obtained relative permeability curve. BRIEF DESCRIPTION OF THE DRAWINGS

[0022] In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the following briefly introduces the drawings required for the embodiments or the description of the prior art. Obviously, the drawings described below are only some embodiments of the present application. For those skilled in the art, other drawings can be obtained based on these drawings without creative work. In the drawings:

[0023] FIG1 is a flow chart of a method for determining oil-water relative permeability information of a medium-to-high permeability oil reservoir provided in an embodiment of the present application;

[0024] FIG2 is a schematic diagram of the movable space of oil and water when the wetting type of the core provided in the embodiment of the present application is water-wetting;

[0025] FIG3 is an example diagram of a corresponding relationship curve between the normalized saturation of the oil-water movable space and the T2 value provided in an embodiment of the present application;

[0026] FIG4 is a schematic diagram of the tortuosity of the oil phase and the water phase at different saturations provided in the examples of the present application;

[0027] FIG5 is a schematic diagram of the oil phase relative permeability and water phase relative permeability curves corresponding to the core saturation provided in the embodiment of the present application;

[0028] FIG6 is a schematic diagram of a device for determining oil-water relative permeability information of a medium-to-high permeability oil reservoir provided in an embodiment of the present application;

[0029] FIG7 is a schematic diagram of a computer device provided in an embodiment of the present application. DETAILED DESCRIPTION

[0030] In order to make the purpose, technical solutions and advantages of the embodiments of the present application more clear, the embodiments of the present application are further described in detail below with reference to the accompanying drawings. Here, the illustrative embodiments of the present application and their descriptions are used to explain the present application, but are not intended to limit the present application.

[0031] In the description of this specification, the terms "include", "including", "have", "contain", etc. are all open terms, which mean including but not limited to. The descriptions with reference to the terms "one embodiment", "a specific embodiment", "some embodiments", "for example", etc. mean that the specific features, structures or characteristics described in conjunction with the embodiment or example are included in at least one embodiment or example of the present application. In this specification, the schematic expressions of the above terms do not necessarily refer to the same embodiment or example. Moreover, the specific features, structures or characteristics described can be combined in a suitable manner in any one or more embodiments or examples. The order of steps involved in each embodiment is used to schematically illustrate the implementation of the present application, and the order of steps therein is not limited and can be appropriately adjusted as needed.

[0032] Research has shown that nuclear magnetic resonance (NMR), a completely nondestructive visualization technique, has been widely used in petroleum engineering in recent years. However, it is primarily used for reservoir geology and fluid parameter measurement and analysis. Currently, there are various methods for determining relative permeability curves based on NMR, such as using capillary pressure to determine relative permeability. Furthermore, there are methods that use NMR T2 spectra to convert capillary pressure to calculate relative permeability. Furthermore, a new method has been proposed that converts NMR T2 spectra to capillary pressure, and then uses the Burdine method to combine irreducible water saturation and residual oil saturation to convert capillary pressure into a relative permeability curve. However, this method of inverting relative permeability curves based on capillary force curves essentially uses static pore structures to invert dynamic oil-water flow patterns. Therefore, it can only make assumptions about the dynamic oil-water flow process, which differs significantly from the actual flow process.

[0033] In response to the above problems, the embodiment of the present application proposes a scheme for determining the oil-water relative permeability information of medium- and high-permeability oil reservoirs, which can more accurately reflect the oil-water distribution characteristics under different states, and overcome the shortcomings of conventional relative permeability curve testing methods that cannot consider the oil-water flow law.

[0034] FIG1 is a flow chart of a method for determining oil-water relative permeability information of a medium-to-high permeability oil reservoir provided in an embodiment of the present application. The method comprises the following steps:

[0035] Step 101, obtaining nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 values ​​and signal intensities;

[0036] Step 102, determining the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir based on the multi-state nuclear magnetic resonance T2 spectrum information;

[0037] Step 103, using the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir, combined with the wetting type of the core of the medium-high permeability oil reservoir, to divide the oil-water movable space in the multi-state nuclear magnetic resonance T2 spectrum information;

[0038] Step 104, determining the correspondence between the normalized saturation of the oil-water movable space and the T2 value based on the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoirs in multiple states; and

[0039] Step 105 : determining the oil phase relative permeability curve and the water phase relative permeability curve of the medium-high permeability reservoir according to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value.

[0040] In an embodiment of the present application, nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states is obtained; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 values ​​and signal intensities; based on the nuclear magnetic resonance T2 spectrum information in multiple states, the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir are determined; using the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir, combined with the wetting type of the core of the medium-to-high permeability oil reservoir, the oil-water movable space is divided in the nuclear magnetic resonance T2 spectrum information in multiple states; based on the nuclear magnetic resonance T2 spectrum information of the medium-to-high permeability oil reservoir in multiple states, the correspondence between the normalized saturation of the oil-water movable space and the T2 value is determined; based on the correspondence between the normalized saturation of the oil-water movable space and the T2 value, the oil phase relative permeability curve and the water phase relative permeability curve of the medium-to-high permeability oil reservoir are determined. Compared with the existing solutions for determining the oil-water relative permeability of medium- and high-permeability reservoirs, the technical solution of the present application can solve the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve, thereby improving the accuracy of the obtained relative permeability curve.

[0041] The following is a detailed description of the method for determining the oil-water relative permeability information of the medium- and high-permeability oil reservoir shown in FIG1 .

[0042] In step 101, first, the NMR T2 spectrum information of the medium-to-high permeability oil reservoir under multiple states can be tested. Specifically, the NMR T2 spectrum information under multiple states can include: NMR T2 spectrum information under a saturated oil state, NMR T2 spectrum information under a bound water state, and NMR T2 spectrum information under a residual oil state.

[0043] In one embodiment, the above step 101 can specifically obtain the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoirs in multiple states by the following method:

[0044] Obtaining nuclear magnetic resonance T2 spectrum information of medium- and high-permeability reservoirs in oil-saturated state; and

[0045] According to the theory of transverse relaxation of nuclear magnetic resonance, the signals of aqueous fluid in medium- and high-permeability reservoirs are shielded by tritium water or manganese ion water, and the nuclear magnetic resonance T2 spectrum information of medium- and high-permeability reservoirs in the bound water state and the residual oil state are obtained.

[0046] In specific implementation, first, the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoirs in the oil-saturated state can be tested; then, based on the nuclear magnetic resonance transverse relaxation theory, the signal of the aqueous fluid in tritium water shielding or manganese ion water shielding is used to test the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoirs in the bound water state and the residual oil state.

[0047] In the embodiment of the present application, the nuclear magnetic resonance T2 spectrum information may include a correspondence between a T2 value and a signal intensity, wherein the T2 value refers to a transverse relaxation time.

[0048] In the above step 102, the pore distribution information and oil phase distribution information of the medium- and high-permeability oil reservoir can be determined based on the multi-state nuclear magnetic resonance T2 spectrum information.

[0049] In a specific implementation, the oil phase distribution information may include the oil phase space in the bound water state and the oil phase space in the residual oil state.

[0050] In one embodiment, the above step 102 may specifically include:

[0051] Determine the pore distribution information of the medium-high permeability reservoir based on the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the oil-saturated state; and

[0052] The oil phase space under irreducible water state and the oil phase space under residual oil state are determined based on the nuclear magnetic resonance T2 spectrum information of medium- and high-permeability oil reservoirs under irreducible water state and residual oil state.

[0053] In step 103, the pore distribution information and oil phase distribution information of the medium-high permeability reservoir can be used in combination with the wetting type of the core of the medium-high permeability reservoir to divide the oil-water movable space in the multi-state nuclear magnetic resonance T2 spectrum information.

[0054] In specific implementation, the wetting type of the core can be determined based on the core samples obtained from the medium- and high-permeability oil reservoirs. The wetting type of the core can be water-wet or oil-wet. Then, the oil-water movable space is divided in the multi-state nuclear magnetic resonance T2 spectrum information based on the wetting type of the core, the pore distribution information of the medium- and high-permeability oil reservoirs, and the oil phase distribution information.

[0055] In one embodiment, the movable oil and water space may include a pore space, a movable water space, and a movable oil space;

[0056] The above step 103 may specifically include:

[0057] Determine the pore space based on the pore distribution information of medium and high permeability reservoirs;

[0058] When the wetting type of the core of a medium-to-high permeability reservoir is water-wet, the oil phase space in the bound water state is determined as the movable water space, and the movable oil space is obtained by subtracting the oil phase space in the residual oil state from the oil phase space in the bound water state; and

[0059] When the wetting type of the core of a medium-to-high permeability reservoir is oil-wet, the movable water space is obtained by subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state. The oil phase space in the irreducible water state is determined as the movable oil space.

[0060] In a specific implementation, both oil and water can flow in the pore space. The movable water space is a space in which only water can flow; and the movable oil space is a space in which only oil can flow.

[0061] In this way, the oil-water movable space can be divided based on the oil-water flow characteristics under different states.

[0062] For example, Figure 2 is a schematic diagram of the movable oil-water space when the wetting type of the core provided in the embodiment of the present application is water-wet. As shown in Figure 2, the correspondence between the T2 value and the signal intensity in the nuclear magnetic resonance T2 spectrum information can be represented in the form of a coordinate curve. In the coordinate curve, the horizontal axis is the T2 value and the vertical axis is the signal intensity. The area enclosed by the X-axis of the curve corresponding to the saturated oil state is used as the pore space, in which both oil and water can flow; the area enclosed by the X-axis of the curve in the bound water state is used as the movable water space, and the area enclosed by the curve in the bound water state and the curve in the residual oil state is used as the movable oil space.

[0063] In the above step 104, the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value can be determined based on the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoir in multiple states.

[0064] In one embodiment, the above step 104 may specifically include:

[0065] According to the corresponding relationship between T2 value and signal intensity under oil saturation state, the oil-water movable signal intensity corresponding to different T2 values ​​in pore space is determined;

[0066] Determine the water phase movable signal intensity corresponding to different T2 values ​​of the movable water space and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space based on the corresponding relationship between the T2 value and the signal intensity in the bound water state and the corresponding relationship between the T2 value and the signal intensity in the residual oil state; and

[0067] According to the oil-water movable signal intensity corresponding to different T2 values ​​of the pore space, the water phase movable signal intensity corresponding to different T2 values ​​of the movable water space, and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space, the corresponding relationship between the normalized saturation of the pore space and the T2 value, the corresponding relationship between the normalized saturation of the movable water space and the T2 value, and the corresponding relationship between the normalized saturation of the movable oil space and the T2 value are determined.

[0068] In specific implementation, since the nuclear magnetic resonance T2 spectrum information refers to the correspondence between the T2 value and the signal intensity, the oil-water movable signal intensity, the water phase movable signal intensity and the oil phase movable signal intensity corresponding to the T2 values ​​of the pore space, movable oil space and movable water space can be determined respectively based on the nuclear magnetic resonance T2 spectrum information under multiple states; and then the correspondence between the normalized saturation of the pore space, movable water space and movable oil space and the T2 value is calculated.

[0069] In specific implementation, both oil and water can flow in the entire void space. According to the corresponding relationship between the T2 value and the signal intensity in the oil-saturated state, the signal intensity corresponding to the T2 value in the oil-saturated state can be determined as the oil-water movable signal intensity corresponding to different T2 values ​​in the pore space.

[0070] In one embodiment, based on the correspondence between the T2 value and the signal intensity in the bound water state and the correspondence between the T2 value and the signal intensity in the residual oil state, determining the water phase movable signal intensity corresponding to different T2 values ​​of the movable water space and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space may specifically include:

[0071] The water phase movable signal intensity corresponding to different T2 values ​​of the movable water space and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space are determined by the following formula: w =I wc I nw =I wc -I or

[0072] Among them, I w Indicates the wetting phase mobile signal intensity, I wc Indicates the signal intensity corresponding to the T2 value in the NMR T2 spectrum information under the bound water state, I nw represents the non-wetting phase mobile signal intensity, I or Indicates the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information under the residual oil state;

[0073] Among them, when the wetting phase is the water phase, the non-wetting phase is the oil phase; when the wetting phase is the oil phase, the non-wetting phase is the water phase.

[0074] In this way, based on the above formula, the water phase movable signal intensity and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable water space and the movable oil space can be determined.

[0075] In one embodiment, based on the oil-water movable signal intensities corresponding to different T2 values ​​of the pore space, the water phase movable signal intensities corresponding to different T2 values ​​of the movable water space, and the oil phase movable signal intensities corresponding to different T2 values ​​of the movable oil space, the corresponding relationship between the normalized saturation of the pore space and the T2 value, the corresponding relationship between the normalized saturation of the movable water space and the T2 value, and the corresponding relationship between the normalized saturation of the movable oil space and the T2 value are determined. Specifically, the following steps may be performed:

[0076] Normalizing the oil-water movable signal intensities corresponding to different T2 values ​​of the pore space, the water phase movable signal intensities corresponding to different T2 values ​​of the movable water space, and the oil phase movable signal intensities corresponding to different T2 values ​​of the movable oil space, respectively, to obtain the normalized oil-water movable signal intensities corresponding to different T2 values ​​of the pore space, the normalized water phase movable signal intensities corresponding to different T2 values ​​of the movable water space, and the normalized oil phase movable signal intensities corresponding to different T2 values ​​of the movable oil space;

[0077] The normalized oil-water movable signal intensity corresponding to different T2 values ​​of the pore space is used as the normalized saturation corresponding to different T2 values, and the corresponding relationship between the normalized saturation of the pore space and the T2 value is obtained;

[0078] The normalized water phase movable signal intensity corresponding to different T2 values ​​of the movable water space is used as the normalized saturation corresponding to different T2 values, and the corresponding relationship between the normalized saturation of the movable water space and the T2 value is obtained; and

[0079] The normalized oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space is used as the normalized saturation corresponding to different T2 values, and the corresponding relationship between the normalized saturation of the movable oil space and the T2 value is obtained.

[0080] During specific implementation, the correspondence between the normalized saturation of the pore space, movable water space, and movable oil space and the T2 value can be displayed in a coordinate system in the form of a curve, wherein the horizontal axis is the normalized saturation and the vertical axis is the T2 value. For example, FIG3 is an example diagram of a curve of the correspondence between the normalized saturation of the oil-water movable space and the T2 value (transverse relaxation time) provided in an embodiment of the present application. As shown in FIG3, different curves represent the T2 values ​​corresponding to different percentages of pore space, movable water space, and movable oil space.

[0081] In the above step 105, the oil phase relative permeability curve and the water phase relative permeability curve of the medium-high permeability reservoir can be determined according to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value.

[0082] During specific implementation, the relative permeability formula can be determined based on the absolute permeability formula and the effective permeability.

[0083] In one embodiment, the above step 105 may specifically include:

[0084] Calculate the oil phase relative permeability and the water phase relative permeability corresponding to different normalized saturations based on the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time; and

[0085] The normalized saturation is converted into core saturation. According to the oil phase relative permeabilities corresponding to the core saturation and different normalized saturations and the water phase relative permeabilities corresponding to different normalized saturations, the oil phase relative permeabilities corresponding to the core saturation and the water phase relative permeabilities corresponding to the core saturation are determined, and the oil phase relative permeability curve and the water phase relative permeability curve of the medium- and high-permeability oil reservoirs are obtained.

[0086] In one embodiment, based on the correspondence between the normalized saturation of the oil-water movable space and the T2 value and a preset absolute permeability formula based on the transverse relaxation time, the oil phase relative permeability corresponding to different normalized saturations and the water phase relative permeability corresponding to different normalized saturations are calculated respectively. Specifically, the calculation may include:

[0087] Determine the oil phase effective permeability corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation based on the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time; and

[0088] According to the absolute permeability formula based on transverse relaxation time, the oil phase effective permeability corresponding to normalized saturation and the effective permeability corresponding to normalized saturation, the oil phase relative permeability corresponding to different normalized saturations and the water phase relative permeability corresponding to different normalized saturations are determined.

[0089] In specific implementation, based on the principle of nuclear magnetic resonance testing, the absolute permeability formula based on the transverse relaxation time can be determined in advance, and then the absolute permeability formula can be used to determine the effective permeability of the oil phase and the effective permeability of the water phase corresponding to the normalized saturation. In this way, based on the effective permeability of the oil phase and the effective permeability of the water phase corresponding to the normalized saturation and the absolute permeability formula, the relative permeability of the oil phase corresponding to different normalized saturations and the relative permeability of the water phase corresponding to different normalized saturations can be determined.

[0090] In specific implementation, the absolute permeability formula based on the transverse relaxation time can be the following formula (1):

[0091] Its integral form can be expressed as follows:

[0092] Where, in formula (1) and formula (2), ρ2 represents the surface relaxation strength, m / ms; F S represents the pore shape factor; Indicates porosity; i here can be expressed as the serial number of the T2 spectrum component; S i represents the saturation corresponding to the i-th T2 spectral component; T 2i represents the T2 value (ie, transverse relaxation time, in ms) corresponding to the i-th T2 spectral component; and τ represents the tortuosity.

[0093] Then, using the above absolute permeability formula (2) and the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value, the oil phase effective permeability corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation can be calculated.

[0094] The oil phase effective permeability corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation can be expressed by the following formulas (3) and (4):

[0095] Among them, K o represents the effective permeability of the oil phase corresponding to the normalized saturation; K w represents the effective permeability of water phase corresponding to normalized saturation; S 1i represents the i-th normalized saturation (i.e., the normalized saturation corresponding to the i-th T2 spectral component); T 2moi represents the T2 value corresponding to the i-th normalized saturation of the movable oil space (that is, the T2 value corresponding to the normalized saturation corresponding to the i-th T2 spectrum component of the movable oil space); T 2mwi represents the T2 value corresponding to the i-th normalized saturation of the movable water space (that is, the T2 value corresponding to the normalized saturation of the i-th T2 spectral component of the movable water space); T 2i Here, the formula can be expressed as the T2 value corresponding to the i-th normalized saturation of the pore space; S mo represents the movable oil saturation corresponding to the i-th normalized saturation; S mw represents the movable water saturation corresponding to the i-th normalized saturation; I o (T 2moi ) represents the oil phase movable signal intensity corresponding to the i-th normalized saturation of the movable oil space; I w (T 2mwi ) represents the water phase movable signal intensity corresponding to the i-th normalized saturation of the movable water space; I(T 2i ) represents the oil-water movable signal intensity corresponding to the i-th normalized saturation of the pore space; τ osi represents the oil phase tortuosity at saturation corresponding to the i-th T2 spectral component; and τ wsirepresents the water phase tortuosity at saturation corresponding to the i-th T2 spectral component.

[0096] In the embodiment of the present application, the tortuosity of the oil phase and the water phase at different saturations is shown in FIG4 . In FIG4 , as the water saturation increases, the tortuosity of the water phase increases and the tortuosity of the oil phase decreases, which is consistent with the actual situation.

[0097] Then, based on the absolute permeability under the oil-saturated state, the formula for the effective permeability of the oil phase corresponding to the normalized saturation, and the effective permeability corresponding to the normalized saturation, the oil phase relative permeability corresponding to different normalized saturations and the water phase relative permeability corresponding to different normalized saturations can be calculated respectively.

[0098] In one embodiment, the oil phase relative permeability corresponding to different normalized saturations can be expressed by the following formula (7):

[0099] The water phase relative permeability corresponding to different normalized saturations can be expressed by the following formula (8):

[0100] In the above formula, K ro represents the oil phase relative permeability corresponding to different normalized saturations; K rw represents the relative permeability of water phase corresponding to different normalized saturations; τ ro represents the ratio of the tortuosity when only one fluid is saturated to the oil phase tortuosity under two-phase flow conditions; and τ rw It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the water phase under two-phase flow conditions.

[0101] In this embodiment, τ ro and τ rw It is obtained by setting the following formula:

[0102] Among them, τ rwt It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the wetting phase under two-phase flow conditions; τ nrwt It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the non-wetting phase under two-phase flow conditions; S wt Indicates the core wetting phase saturation; S nwt Indicates the saturation of the non-wetting phase in the core; S min Indicates the minimum wetting phase saturation of the core; S nwtr Indicates the residual saturation of the non-wetting core;

[0103] When the core-wetting phase is water, the non-wetting phase is oil; when the core-wetting phase is oil, the non-wetting phase is water.

[0104] In specific implementation, according to the above formula (9) and formula (10), for example, when the wetting phase is the water phase, τ rwt It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the water phase under two-phase flow conditions, that is, τ rwt =τ rw ; τ nrwt It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the oil phase under two-phase flow conditions, that is, τ nrwt =τ ro ;S wt Indicates the core water saturation; S nwt Indicates the oil phase saturation of the core; S min It represents the minimum water saturation of the core, and for hydrowet cores it is the irreducible water saturation; S nwtr It indicates the residual saturation of the oil phase in the core. For water-wet cores, it is the residual oil saturation.

[0105] Alternatively, when the wetting phase is an oil phase, τ rwt It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the oil phase under two-phase flow conditions, that is, τ rwt =τ ro ; τ nrwt It represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the water phase under two-phase flow conditions, that is, τ nrwt =τ rw ;S wt Indicates the oil phase saturation of the core; S nwt Indicates the core water saturation; S min Indicates the minimum oil saturation of the core, S nwtr Indicates the residual saturation of the water phase in the core.

[0106] Finally, the normalized saturation is converted into core saturation. According to the oil phase relative permeability corresponding to different normalized saturations and the water phase relative permeability corresponding to different normalized saturations, the oil phase relative permeability corresponding to the corresponding core saturation and the water phase relative permeability corresponding to the core saturation can be obtained, and the oil phase relative permeability curve and water phase relative permeability curve of medium and high permeability oil reservoirs can be obtained.

[0107] In one embodiment, the core oil phase saturation and the core water phase saturation can be obtained by the following formula (11) and formula (12): S w =S1×(1-S wc -S or )+S wc Formula (11) S o =S1×(1-S wc -S or )+S orFormula (12)

[0108] in:

[0109] Among them, S w Indicates the core water saturation; S o represents the core oil phase saturation; S1 represents the normalized saturation; S wc Indicates bound water saturation; S or Indicates residual oil saturation; I or (T 2i ) represents the T in the nuclear magnetic resonance T2 spectrum information under the residual oil state 2i Corresponding signal strength; I wc (T 2i ) represents the T2 spectrum information of the bound water state. 2i The corresponding signal strength; and I(T 2i ) represents the T2 spectrum information of the nuclear magnetic resonance in the saturated oil state 2i The corresponding signal strength.

[0110] In this way, by converting the normalized saturation into core saturation, and then matching the core saturation with the relative permeability of the oil phase and the relative permeability of the water phase at the normalized saturation, the oil phase relative permeability corresponding to the core saturation and the water phase relative permeability corresponding to the core saturation are constructed. For example, Figure 5 is a schematic diagram of the oil phase relative permeability and water phase relative permeability curve corresponding to the core saturation provided in an embodiment of the present application. As shown in Figure 5, as the core water saturation increases, the water phase relative permeability increases and the oil phase relative permeability decreases, which is consistent with reality.

[0111] In the embodiment of the present application, the above-mentioned method for determining the oil-water relative permeability information of medium- and high-permeability oil reservoirs can solve the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve, thereby improving the accuracy of the obtained relative permeability curve.

[0112] The present application also provides an apparatus for determining oil-water relative permeability information for a medium-high permeability reservoir, as shown in the following embodiment. Because the principle underlying the problem solved by this apparatus is similar to that of the method for determining oil-water relative permeability information for a medium-high permeability reservoir, the implementation of this apparatus can be referenced to the implementation of the method for determining oil-water relative permeability information for a medium-high permeability reservoir, and any repetitive details will not be repeated.

[0113] FIG6 is a schematic diagram of a device for determining oil-water relative permeability information of a medium-to-high permeability oil reservoir provided by an embodiment of the present application. The device may include:

[0114] Acquisition module 601 is used to acquire nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 values ​​and signal intensities;

[0115] An information determination module 602 is configured to determine pore distribution information and oil phase distribution information of a medium-to-high permeability oil reservoir based on multi-state nuclear magnetic resonance T2 spectrum information;

[0116] A partitioning module 603 is configured to utilize the pore distribution information and oil phase distribution information of the medium- and high-permeability reservoir, combined with the wetting type of the core of the medium- and high-permeability reservoir, to partition the oil-water movable space in the multi-state nuclear magnetic resonance T2 spectrum information;

[0117] A first processing module 604 is configured to determine a correspondence between the normalized saturation of the oil-water movable space and the T2 value based on the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoirs under multiple states; and

[0118] The second processing module 605 is used to determine the oil phase relative permeability curve and the water phase relative permeability curve of the medium-high permeability oil reservoir according to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value.

[0119] In one embodiment, the acquisition module may be used to:

[0120] Obtaining nuclear magnetic resonance T2 spectrum information of medium- and high-permeability reservoirs in oil-saturated state; and

[0121] According to the theory of nuclear magnetic resonance transverse relaxation, tritium water or manganese ion water is used to shield the signal of the aqueous fluid in the medium- and high-permeability oil reservoirs, and the nuclear magnetic resonance T2 spectrum information of the medium- and high-permeability oil reservoirs in the bound water state and the residual oil state is obtained.

[0122] In one embodiment, the information determination module may be configured to:

[0123] Determine the pore distribution information of the medium-high permeability reservoir based on the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the oil-saturated state; and

[0124] The oil phase space under irreducible water state and the oil phase space under residual oil state are determined based on the nuclear magnetic resonance T2 spectrum information of medium- and high-permeability oil reservoirs under irreducible water state and residual oil state.

[0125] In one embodiment, the oil-water movable space may include a pore space, a movable water space, and a movable oil space; the pore space refers to a space where both oil and water can flow;

[0126] Divide the module into:

[0127] Determine the pore space based on the pore distribution information of medium and high permeability reservoirs;

[0128] When the wetting type of the core of a medium-to-high permeability oil reservoir is water-wet, the oil phase space in the bound water state is determined as the movable water space, and the movable oil space is determined by subtracting the oil phase space in the residual oil state from the oil phase space in the bound water state; and

[0129] When the wetting type of the core of a medium-to-high permeability reservoir is oil-wet, the movable water space is determined by subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state, and the movable oil space is determined by subtracting the oil phase space in the irreducible water state from the oil phase space in the residual oil state.

[0130] In one embodiment, the first processing module may be configured to:

[0131] According to the corresponding relationship between T2 value and signal intensity under oil saturation state, the oil-water movable signal intensity corresponding to different T2 values ​​in pore space is determined;

[0132] Determine the water phase movable signal intensity corresponding to different T2 values ​​of the movable water space and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space based on the corresponding relationship between the T2 value and the signal intensity in the bound water state and the corresponding relationship between the T2 value and the signal intensity in the residual oil state; and

[0133] According to the oil-water movable signal intensity corresponding to different T2 values ​​of the pore space, the water phase movable signal intensity corresponding to different T2 values ​​of the movable water space, and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space, the corresponding relationship between the normalized saturation of the pore space and the T2 value, the corresponding relationship between the normalized saturation of the movable water space and the T2 value, and the corresponding relationship between the normalized saturation of the movable oil space and the T2 value are determined.

[0134] In one embodiment, the first processing module may further be configured to:

[0135] The water phase movable signal intensity corresponding to different T2 values ​​of the movable water space and the oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space are determined by the following formula: w =I wc I nw =I wc -I or

[0136] Among them, I w Indicates the wetting phase mobile signal intensity, I wc Indicates the signal intensity corresponding to the T2 value in the NMR T2 spectrum information under the bound water state, I nwrepresents the non-wetting phase mobile signal intensity, I or Indicates the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information under the residual oil state;

[0137] Among them, when the wetting phase is the water phase, the non-wetting phase is the oil phase; when the wetting phase is the oil phase, the non-wetting phase is the water phase.

[0138] In one embodiment, the first processing module may further be configured to:

[0139] Normalizing the oil-water movable signal intensities corresponding to different T2 values ​​of the pore space, the water phase movable signal intensities corresponding to different T2 values ​​of the movable water space, and the oil phase movable signal intensities corresponding to different T2 values ​​of the movable oil space, respectively, to obtain the normalized oil-water movable signal intensities corresponding to different T2 values ​​of the pore space, the normalized water phase movable signal intensities corresponding to different T2 values ​​of the movable water space, and the normalized oil phase movable signal intensities corresponding to different T2 values ​​of the movable oil space;

[0140] The normalized oil-water movable signal intensity corresponding to different T2 values ​​of the pore space is used as the normalized saturation corresponding to different T2 values, and the corresponding relationship between the normalized saturation of the pore space and the T2 value is obtained;

[0141] The normalized water phase movable signal intensity corresponding to different T2 values ​​of the movable water space is used as the normalized saturation corresponding to different T2 values, and the corresponding relationship between the normalized saturation of the movable water space and the T2 value is obtained; and

[0142] The normalized oil phase movable signal intensity corresponding to different T2 values ​​of the movable oil space is used as the normalized saturation corresponding to different T2 values, and the corresponding relationship between the normalized saturation of the movable oil space and the T2 value is obtained.

[0143] In one embodiment, the second processing module may be configured to:

[0144] Calculate the oil phase relative permeability and the water phase relative permeability corresponding to different normalized saturations based on the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time; and

[0145] The normalized saturation is converted into core saturation. According to the oil phase relative permeabilities corresponding to the core saturation and different normalized saturations and the water phase relative permeabilities corresponding to different normalized saturations, the oil phase relative permeabilities corresponding to the core saturation and the water phase relative permeabilities corresponding to the core saturation are determined, and the oil phase relative permeability curve and the water phase relative permeability curve of the medium- and high-permeability oil reservoirs are obtained.

[0146] In one embodiment, the second processing module may further be configured to:

[0147] Determine the oil phase effective permeability formula corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation based on the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time; and

[0148] According to the absolute permeability formula based on transverse relaxation time, the oil phase effective permeability corresponding to normalized saturation and the effective permeability corresponding to normalized saturation, the oil phase relative permeability corresponding to different normalized saturations and the water phase relative permeability corresponding to different normalized saturations are determined.

[0149] An embodiment of the present application also provides a computer device, as shown in Figure 7, which is a schematic diagram of the computer device in an embodiment of the present application. The computer device 700 includes a memory 710, a processor 720, and a computer program 730 stored in the memory 710 and executable on the processor 720. When the processor 720 executes the computer program 730, it implements the above-mentioned method for determining the oil-water relative permeability information of the medium- and high-permeability oil reservoir.

[0150] An embodiment of the present application further provides a computer-readable storage medium storing a computer program. When the computer program is executed by a processor, the method for determining the oil-water relative permeability information of the above-mentioned medium- and high-permeability oil reservoir is implemented.

[0151] An embodiment of the present application further provides a computer program product, which includes a computer program. When the computer program is executed by a processor, it implements the method for determining the oil-water relative permeability information of the above-mentioned medium- and high-permeability oil reservoirs.

[0152] In an embodiment of the present application, nuclear magnetic resonance T2 spectrum information of a medium-to-high permeability oil reservoir in multiple states is obtained; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information in a saturated oil state, nuclear magnetic resonance T2 spectrum information in a bound water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes a correspondence between T2 values ​​and signal intensities; based on the nuclear magnetic resonance T2 spectrum information in multiple states, the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir are determined; using the pore distribution information and oil phase distribution information of the medium-to-high permeability oil reservoir, combined with the wetting type of the core of the medium-to-high permeability oil reservoir, the oil-water movable space is divided in the nuclear magnetic resonance T2 spectrum information in multiple states; based on the nuclear magnetic resonance T2 spectrum information of the medium-to-high permeability oil reservoir in multiple states, the correspondence between the normalized saturation of the oil-water movable space and the T2 value is determined; based on the correspondence between the normalized saturation of the oil-water movable space and the T2 value, the oil phase relative permeability curve and the water phase relative permeability curve of the medium-to-high permeability oil reservoir are determined. Compared with the existing scheme for determining the oil-water relative permeability of medium- and high-permeability reservoirs, the method can solve the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve, and improve the accuracy of the obtained relative permeability curve.

[0153] Those skilled in the art will appreciate that the embodiments of the present application can be provided as methods, systems, or computer program products. Therefore, the present application can adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present application can adopt the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to magnetic disk storage, CD-ROM, optical storage, etc.) that contain computer-usable program code.

[0154] The present application is described with reference to the flow chart and / or block diagram of the method, device (system), and computer program product according to the embodiment of the present application. It should be understood that each flow process and / or box in the flow chart and / or block diagram and the combination of the flow process and / or box in the flow chart and / or block diagram can be realized by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processing machine or other programmable data processing device to produce a machine, so that the instructions executed by the processor of the computer or other programmable data processing device produce a device for realizing the function specified in one flow chart flow or multiple flows and / or one box or multiple boxes of the block diagram.

[0155] These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce a product including an instruction device that implements the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0156] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, so that the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one or more processes in the flowchart and / or one or more boxes in the block diagram.

[0157] The above specific embodiments further illustrate the purpose, technical solutions and beneficial effects of the present application. It should be understood that the above are only specific embodiments of the present application and are not intended to limit the scope of protection of the present application. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present application should be included in the scope of protection of the present application.

Claims

1. A method for determining the oil-water relative permeability information of a medium-high permeability oil reservoir, characterized in that, Comprising: Obtaining nuclear magnetic resonance T2 spectrum information of a medium-high permeability oil reservoir under multiple states; The nuclear magnetic resonance T2 spectrum information under the multiple states includes: nuclear magnetic resonance T2 spectrum information in the saturated oil state, nuclear magnetic resonance T2 spectrum information in the irreducible water state, and nuclear magnetic resonance T2 spectrum information in the residual oil state; the nuclear magnetic resonance T2 spectrum information includes the correspondence between T2 values and signal intensities; Determining the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir according to the nuclear magnetic resonance T2 spectrum information under the multiple states; Utilizing the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir, and combining with the wettability type of the core of the medium-high permeability oil reservoir, dividing the oil-water movable space in the nuclear magnetic resonance T2 spectrum information under the multiple states; Determining the correspondence between the normalized saturation of the oil-water movable space and the T2 value according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under the multiple states; And Determining the relative permeability curve of the oil phase and the relative permeability curve of the water phase of the medium-high permeability oil reservoir according to the correspondence between the normalized saturation of the oil-water movable space and the T2 value.

2. The method according to claim 1, characterized in that, Obtaining the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states includes: Obtaining the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the saturated oil state; and According to the nuclear magnetic resonance transverse relaxation theory, using tritiated water or manganese ion water to shield the signal of the aqueous fluid in the medium-high permeability oil reservoir, and obtaining the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the irreducible water state and the nuclear magnetic resonance T2 spectrum information in the residual oil state.

3. The method according to claim 1, characterized in that, Determining the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir according to the nuclear magnetic resonance T2 spectrum information under the multiple states includes: Determining the pore distribution information of the medium-high permeability oil reservoir according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the saturated oil state; and Determining the oil phase space in the irreducible water state and the oil phase space in the residual oil state according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the irreducible water state and the nuclear magnetic resonance T2 spectrum information in the residual oil state.

4. The method according to claim 3, wherein The oil-water movable space includes a pore space, a movable water space, and a movable oil space; the pore space represents the space where both oil and water can flow; Utilizing the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir, and combining with the wettability type of the core of the medium-high permeability oil reservoir, dividing the oil-water movable space in the nuclear magnetic resonance T2 spectrum information under the multiple states includes: Determining the pore space according to the pore distribution information of the medium-high permeability oil reservoir; When the wettability type of the core of the medium-high permeability oil reservoir is water-wet, determining the oil phase space in the irreducible water state as the movable water space, and determining, after subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state, as the movable oil space; and When the wettability type of the core of the medium-high permeability oil reservoir is oil-wet, determining, after subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state, as the movable water space, and determining the oil phase space in the irreducible water state as the movable oil space.

5. The method according to claim 4, wherein Determining the correspondence between the normalized saturation of the oil-water movable space and the T2 value according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under the multiple states includes: Determine the movable oil-water signal intensities corresponding to different T2 values in the pore space according to the correspondence between the T2 values and the signal intensities in the saturated oil state; Determine the movable water-phase signal intensities corresponding to different T2 values in the movable water space and the movable oil-phase signal intensities corresponding to different T2 values in the movable oil space according to the correspondence between the T2 values and the signal intensities in the irreducible water state and the correspondence between the T2 values and the signal intensities in the residual oil state; and Determine the correspondence between the normalized saturation and the T2 value in the pore space, the correspondence between the normalized saturation and the T2 value in the movable water space, and the correspondence between the normalized saturation and the T2 value in the movable oil space according to the movable oil-water signal intensities corresponding to different T2 values in the pore space, the movable water-phase signal intensities corresponding to different T2 values in the movable water space, and the movable oil-phase signal intensities corresponding to different T2 values in the movable oil space.

6. The method according to claim 5, wherein Determine the movable water-phase signal intensities corresponding to different T2 values in the movable water space and the movable oil-phase signal intensities corresponding to different T2 values in the movable oil space according to the correspondence between the T2 values and the signal intensities in the irreducible water state and the correspondence between the T2 values and the signal intensities in the residual oil state, including: Determine the movable water-phase signal intensities corresponding to different T2 values in the movable water space and the movable oil-phase signal intensities corresponding to different T2 values in the movable oil space through the following formula: I w = I wc I nw = I wc - I or Among them, I w represents the movable signal intensity of the wetting phase, I wc represents the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information in the bound water state, I nw represents the movable signal intensity of the non-wetting phase, I or represents the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information in the residual oil state; Wherein, when the wetting phase is the water phase, the non-wetting phase is the oil phase; when the wetting phase is the oil phase, the non-wetting phase is the water phase.

7. The method according to claim 5, wherein Determine the correspondence between the normalized saturation and the T2 value in the pore space, the correspondence between the normalized saturation and the T2 value in the movable water space, and the correspondence between the normalized saturation and the T2 value in the movable oil space according to the movable oil-water signal intensities corresponding to different T2 values in the pore space, the movable water-phase signal intensities corresponding to different T2 values in the movable water space, and the movable oil-phase signal intensities corresponding to different T2 values in the movable oil space, including: Normalize the movable oil-water signal intensities corresponding to different T2 values in the pore space, the movable water-phase signal intensities corresponding to different T2 values in the movable water space, and the movable oil-phase signal intensities corresponding to different T2 values in the movable oil space respectively to obtain the normalized movable oil-water signal intensities corresponding to different T2 values in the pore space, the normalized movable water-phase signal intensities corresponding to different T2 values in the movable water space, and the normalized movable oil-phase signal intensities corresponding to different T2 values in the movable oil space; Use the normalized movable oil-water signal intensities corresponding to different T2 values in the pore space as the normalized saturations corresponding to different T2 values to obtain the correspondence between the normalized saturation and the T2 value in the pore space; Use the normalized movable water-phase signal intensities corresponding to different T2 values in the movable water space as the normalized saturations corresponding to different T2 values to obtain the correspondence between the normalized saturation and the T2 value in the movable water space; and Use the normalized movable oil-phase signal intensities corresponding to different T2 values in the movable oil space as the normalized saturations corresponding to different T2 values to obtain the correspondence between the normalized saturation and the T2 value in the movable oil space.

8. The method according to claim 7, wherein Based on the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value, determine the oil-phase relative permeability curve and the water-phase relative permeability curve of the medium-high permeability oil reservoir, including: According to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time, calculate the oil-phase relative permeability corresponding to different normalized saturations and the water-phase relative permeability corresponding to different normalized saturations respectively; and Convert the normalized saturation into the core saturation, and based on the core saturation, the oil-phase relative permeability corresponding to different normalized saturations, and the water-phase relative permeability corresponding to different normalized saturations, determine the oil-phase relative permeability corresponding to the core saturation and the water-phase relative permeability corresponding to the core saturation, so as to obtain the oil-phase relative permeability curve and the water-phase relative permeability curve of the medium-high permeability oil reservoir.

9. The method according to claim 8, wherein According to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time, calculate the oil-phase relative permeability corresponding to different normalized saturations and the water-phase relative permeability corresponding to different normalized saturations respectively, including: According to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time, determine the oil-phase effective permeability formula corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation; and According to the absolute permeability formula based on the transverse relaxation time, the oil-phase effective permeability corresponding to the normalized saturation, and the effective permeability corresponding to the normalized saturation, determine the oil-phase relative permeability corresponding to different normalized saturations and the water-phase relative permeability corresponding to different normalized saturations.

10. An apparatus for determining the oil-water relative permeability information of a medium-high permeability oil reservoir, characterized in that Including: An acquisition module for acquiring the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states; The nuclear magnetic resonance T2 spectrum information under the multiple states includes: the nuclear magnetic resonance T2 spectrum information in the oil-saturated state, the nuclear magnetic resonance T2 spectrum information in the irreducible water state, and the nuclear magnetic resonance T2 spectrum information in the residual oil state; the nuclear magnetic resonance T2 spectrum information includes the corresponding relationship between the T2 value and the signal intensity; An information determination module for determining the pore distribution information and the oil-phase distribution information of the medium-high permeability oil reservoir according to the nuclear magnetic resonance T2 spectrum information under the multiple states; A partitioning module for partitioning the oil-water movable space in the nuclear magnetic resonance T2 spectrum information under the multiple states by using the pore distribution information and the oil-phase distribution information of the medium-high permeability oil reservoir in combination with the wetting type of the core of the medium-high permeability oil reservoir; A first processing module for determining the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under the multiple states; and A second processing module for determining the oil-phase relative permeability curve and the water-phase relative permeability curve of the medium-high permeability oil reservoir according to the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value.

11. The device according to claim 10, characterized in that The acquisition module is used for: Acquiring the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the oil-saturated state; and According to the nuclear magnetic resonance transverse relaxation theory, the signals of the aqueous fluid in the medium-high permeability reservoir are shielded using tritiated water or manganese ion water, and the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the irreducible water state and the nuclear magnetic resonance T2 spectrum information in the residual oil state are obtained.

12. The device according to claim 10, characterized in that, The information determination module is used for: Determining the pore distribution information of the medium-high permeability reservoir according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the saturated oil state; and Determining the oil phase space in the irreducible water state and the oil phase space in the residual oil state according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the irreducible water state and the nuclear magnetic resonance T2 spectrum information in the residual oil state.

13. The device according to claim 12, characterized in that, The oil-water movable space includes a pore space, a movable water space, and a movable oil space; the pore space represents the space where both oil and water can flow; The partitioning module is used for: Determining the pore space according to the pore distribution information of the medium-high permeability reservoir; When the wetting type of the medium-high permeability reservoir core is water-wet, determining the oil phase space in the irreducible water state as the movable water space, and after subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state, determining it as the movable oil space; and When the wetting type of the medium-high permeability reservoir core is oil-wet, after subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state, determining it as the movable water space, and determining the oil phase space in the irreducible water state as the movable oil space.

14. The device according to claim 13, wherein The first processing module is used for: Determining the oil-water movable signal intensities corresponding to different T2 values in the pore space according to the correspondence between the T2 value and the signal intensity in the saturated oil state; Determining the water phase movable signal intensities corresponding to different T2 values in the movable water space and the oil phase movable signal intensities corresponding to different T2 values in the movable oil space according to the correspondence between the T2 value and the signal intensity in the irreducible water state and the correspondence between the T2 value and the signal intensity in the residual oil state; And Determining the correspondence between the normalized saturation and the T2 value in the pore space, the correspondence between the normalized saturation and the T2 value in the movable water space, and the correspondence between the normalized saturation and the T2 value in the movable oil space according to the oil-water movable signal intensities corresponding to different T2 values in the pore space, the water phase movable signal intensities corresponding to different T2 values in the movable water space, and the oil phase movable signal intensities corresponding to different T2 values in the movable oil space.

15. The device according to claim 14, characterized in that, The first processing module is further used for: Determining the water phase movable signal intensities corresponding to different T2 values in the movable water space and the oil phase movable signal intensities corresponding to different T2 values in the movable oil space through the following formula: I w = I wc I nw = I wc - I or Among them, I w represents the movable signal intensity of the wetting phase, and I wc represents the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information in the bound water state, and I nw represents the movable signal intensity of the non-wetting phase, and I or represents the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information in the residual oil state; Wherein, when the wetting phase is the water phase, the non-wetting phase is the oil phase; when the wetting phase is the oil phase, the non-wetting phase is the water phase.

16. The device according to claim 14, wherein The first processing module is further used for: Normalize the oil-water movable signal intensity corresponding to different T2 values in the pore space, the water-phase movable signal intensity corresponding to different T2 values in the movable water space, and the oil-phase movable signal intensity corresponding to different T2 values in the movable oil space, to obtain the normalized oil-water movable signal intensity corresponding to different T2 values in the pore space, the normalized water-phase movable signal intensity corresponding to different T2 values in the movable water space, and the normalized oil-phase movable signal intensity corresponding to different T2 values in the movable oil space; Use the normalized oil-water movable signal intensity corresponding to different T2 values in the pore space as the normalized saturation corresponding to different T2 values, to obtain the corresponding relationship between the normalized saturation in the pore space and the T2 values; Use the normalized water-phase movable signal intensity corresponding to different T2 values in the movable water space as the normalized saturation corresponding to different T2 values, to obtain the corresponding relationship between the normalized saturation in the movable water space and the T2 values; Use the normalized oil-phase movable signal intensity corresponding to different T2 values in the movable oil space as the normalized saturation corresponding to different T2 values, to obtain the corresponding relationship between the normalized saturation in the movable oil space and the T2 values.

17. The device according to claim 16, wherein The second processing module is used for: According to the corresponding relationship between the normalized saturation in the oil-water movable space and the T2 values and the preset absolute permeability formula based on the transverse relaxation time, calculate the oil-phase relative permeability corresponding to different normalized saturations and the water-phase relative permeability corresponding to different normalized saturations respectively; And Convert the normalized saturation into the core saturation, and according to the core saturation, the oil-phase relative permeability corresponding to different normalized saturations, and the water-phase relative permeability corresponding to different normalized saturations, determine the oil-phase relative permeability corresponding to the core saturation and the water-phase relative permeability corresponding to the core saturation, to obtain the oil-phase relative permeability curve and the water-phase relative permeability curve of the medium-high permeability oil reservoir.

18. The device according to claim 17, wherein The second processing module is further used for: According to the corresponding relationship between the normalized saturation in the oil-water movable space and the T2 values and the preset absolute permeability formula based on the transverse relaxation time, determine the oil-phase effective permeability formula corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation; And According to the absolute permeability formula based on the transverse relaxation time, the oil-phase effective permeability corresponding to the normalized saturation, and the effective permeability corresponding to the normalized saturation, determine the oil-phase relative permeability corresponding to different normalized saturations and the water-phase relative permeability corresponding to different normalized saturations.

19. A computer device, comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method according to any one of claims 1 to 9.

20. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program, and when the computer program is executed by the processor, it implements the method according to any one of claims 1 to 9.

21. A computer program product, characterized in that, The computer program product includes a computer program, and when the computer program is executed by the processor, it implements the method according to any one of claims 1 to 9.

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