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

Abstract

The invention discloses a method and a device for determining oil-water relative permeability information of a medium-high permeability reservoir, and relates to the technical field of oil and gas reservoir development, the method comprises the following steps: acquiring nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in multiple states; determining pore distribution and oil phase distribution according to the nuclear magnetic resonance T2 spectrum information in multiple states; dividing an oil-water movable space in multi-state nuclear magnetic resonance T2 spectrum information by utilizing pore distribution and oil phase distribution of the medium-high permeability reservoir and combining a wetting type of a core of the medium-high permeability reservoir; according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in multiple states, the corresponding relation between the normalized saturation of the oil-water movable space and the T2 value is determined; and determining an oil-phase relative permeability curve and a 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. The problem that the oil-water flow rule cannot be considered when the existing relative permeability curve is determined can be solved.

Description

Technical Field

[0001] The present invention relates to the technical field of oil and gas reservoir development, and particularly to a method and device for determining the oil-water relative permeability information of medium-high permeability oil reservoirs. Background Art

[0002] This section aims to provide background or context for the embodiments of the present invention. The descriptions herein are not admitted to be prior art by including them in this section.

[0003] The relative permeability curve is a curve that describes the relative permeability of different phases changing with saturation when multiphase fluids flow in a porous medium, and is an indispensable important basic data for predicting oil and gas field development indicators, formulating development plans, and researching oil and gas reservoir numerical simulation technologies.

[0004] At present, the methods for determining the relative permeability curve are mainly divided into direct measurement and indirect calculation. Due to the existence of end effects and the too long measurement period, direct measurement is less applied. The unsteady state method is widely used, but it ignores the influence of capillary force and assumes that the fluid advances in the core with an equal saturation surface, which is inconsistent with the actual situation. In recent years, nuclear magnetic resonance (NMR), as a completely non-destructive visualization technology, has been widely used in the field of petroleum engineering. Some studies have found that the capillary pressure converted from the NMR T2 spectrum can be used to calculate the relative permeability. However, the existing methods for calculating the relative permeability using the NMR T2 spectrum essentially use the static pore structure to invert the dynamic oil-water flow law, so only assumptions can be made about the dynamic oil-water flow process, which is significantly different from the actual flow process and cannot provide an accurate relative permeability curve. Summary of the Invention

[0005] Embodiments of the present invention provide a method for determining the oil-water relative permeability information of medium-high permeability oil reservoirs, aiming to solve the problem that the existing methods for determining the relative permeability curve cannot consider the oil-water flow law and improve the accuracy of the obtained relative permeability curve. The method includes:

[0006] Obtain the NMR T2 spectrum information of the medium-high permeability oil reservoir in multiple states; the NMR T2 spectrum information in multiple states includes: the NMR T2 spectrum information in the oil-saturated state, the NMR T2 spectrum information in the irreducible water state, and the NMR T2 spectrum information in the residual oil state; the NMR T2 spectrum information includes the correspondence between the T2 value and the signal intensity;

[0007] Determine the pore distribution information and the oil phase distribution information of the medium-high permeability oil reservoir according to the NMR T2 spectrum information in multiple states;

[0008] Divide the oil-water movable space in the NMR T2 spectrum information in 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.

[0009] Based on the nuclear magnetic resonance T2 spectrum information of medium-high permeability oil reservoirs under multiple states, determine the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value;

[0010] 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.

[0011] An embodiment of the present invention also provides a device for determining the oil-water relative permeability information of a medium-high permeability oil reservoir, which is used to solve the problem that the existing relative permeability curve determination cannot consider the oil-water flow law and improve the accuracy of the obtained relative permeability curve. The device includes:

[0012] An acquisition module, configured to acquire 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 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;

[0013] An information determination module, configured to determine 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 multiple states;

[0014] A division module, configured to divide the oil-water movable space in the nuclear magnetic resonance T2 spectrum information under 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;

[0015] A first processing module, configured to determine 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 multiple states;

[0016] A second processing module, configured 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.

[0017] An embodiment of the present invention also provides a computer-readable storage medium, which stores 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 medium-high permeability oil reservoir as described above.

[0018] An embodiment of the present invention also 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 medium-high permeability oil reservoir as described above.

[0019] In an embodiment of the present invention, nuclear magnetic resonance T2 spectrum information of a medium-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 an irreducible water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes the correspondence between T2 values and signal intensities; based on the nuclear magnetic resonance T2 spectrum information in multiple states, pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir are determined; 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, 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-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-high permeability oil reservoir are determined. Compared with the existing solution for determining the oil-water relative permeability of a medium-high permeability oil reservoir, the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve can be solved, and the accuracy of the obtained relative permeability curve can be improved. BRIEF DESCRIPTION OF THE DRAWINGS

[0020] In order to more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments or the prior art. Obviously, the following drawings are only some embodiments of the present invention. For those of ordinary skill in the art, other drawings can be obtained based on these drawings without creative efforts. In the drawings:

[0021] Figure 1 is a flowchart of a method for determining oil-water relative permeability information of a medium-high permeability oil reservoir provided in an embodiment of the present invention;

[0022] Figure 2 is a schematic diagram of the oil-water movable space when the wetting type of the core provided in an embodiment of the present invention is water-wet;

[0023] Figure 3 is an example diagram of the correspondence curve between the normalized saturation of the oil-water movable space and the T2 value provided in an embodiment of the present invention;

[0024] Figure 4 is a schematic diagram of the tortuosity of the oil phase and the water phase at different saturations provided in an embodiment of the present invention;

[0025] Figure 5 is a schematic diagram of the oil-phase relative permeability and water-phase relative permeability curves corresponding to the core saturation provided in an embodiment of the present invention;

[0026] Figure 6Schematic diagram of a device for determining oil-water relative permeability information of medium-high permeability reservoirs provided in an embodiment of the present invention;

[0027] Figure 7 Schematic diagram of a computer device provided in an embodiment of the present invention. Detailed implementation manners

[0028] To make the objectives, technical solutions and advantages of the embodiments of the present invention clearer and more understandable, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings. Herein, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but not to limit the present invention.

[0029] In the description of this specification, the terms "comprising", "including", "having", "containing", etc. are all open-ended terms, that is, they are intended to include but not limited to. The description with reference to terms such as "an embodiment", "a specific embodiment", "some embodiments", "for example", etc. means that the specific features, structures or characteristics described in connection with the embodiment or example are included in at least one embodiment or example of the present application. In this specification, the schematic descriptions 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 step sequences involved in each embodiment are used to schematically illustrate the implementation of the present application, and the step sequences are not limited and can be adjusted appropriately as needed.

[0030] Through research, it has been found that nuclear magnetic resonance, as a completely non-destructive visualization technology, has been widely used in the field of petroleum engineering in recent years. However, it is mainly used for reservoir geology and fluid parameter measurement and analysis. At present, there are various methods for determining relative permeability curves based on nuclear magnetic resonance means. For example, relative permeability is obtained by using capillary pressure; on this basis, there is also a method of calculating relative permeability by using the capillary pressure converted from the nuclear magnetic resonance T2 spectrum; further, someone has proposed a new method of converting the nuclear magnetic resonance T2 spectrum into capillary pressure, and then using the Burdine method combined with irreducible water saturation and residual oil saturation to convert the capillary pressure into a relative permeability curve. However, the essence of this method of inverting the relative permeability curve based on the capillary force curve is to invert the dynamic oil-water flow law with a static pore structure, so it can only make assumptions about the dynamic oil-water flow process, which is significantly different from the actual flow process.

[0031] In view of the above problems, the embodiments of the present invention propose a solution for determining oil-water relative permeability information of medium-high permeability reservoirs, which can more accurately reflect the oil-water distribution characteristics in different states and overcome the disadvantage that the conventional relative permeability curve test method cannot consider the oil-water flow law.

[0032] Figure 1The flowchart of a method for determining the oil-water relative permeability information of a medium-high permeability oil reservoir provided by an embodiment of the present invention, the method comprising the following steps:

[0033] Step 101, obtain 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 correspondence between the T2 value and the signal intensity;

[0034] Step 102, determine 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 multiple states;

[0035] Step 103, use the pore distribution information and the 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 nuclear magnetic resonance T2 spectrum information under multiple states;

[0036] Step 104, determine 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 multiple states;

[0037] Step 105, determine the oil phase relative permeability curve and the water phase relative permeability curve 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.

[0038] In an embodiment of the present invention, the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states is obtained; 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 correspondence between the T2 value and the signal intensity; the pore distribution information and the oil phase distribution information of the medium-high permeability oil reservoir are determined according to the nuclear magnetic resonance T2 spectrum information under multiple states; the oil-water movable space is divided in the nuclear magnetic resonance T2 spectrum information under multiple states by using the pore distribution information and the 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; the correspondence between the normalized saturation of the oil-water movable space and the T2 value is determined according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states; the oil phase relative permeability curve and the water phase relative permeability curve of the medium-high permeability oil reservoir are determined according to the correspondence between the normalized saturation of the oil-water movable space and the T2 value. Compared with the existing scheme for determining the oil-water relative permeability of a medium-high permeability oil reservoir, the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve can be solved, and the accuracy of the obtained relative permeability curve can be improved.

[0039] Next, for Figure 1A method for determining the oil-water relative permeability information of the medium-high permeability reservoir shown is described in detail.

[0040] In step 101 above, first, the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in multiple states can be tested. Specifically, the nuclear magnetic resonance T2 spectrum information in multiple states can include: 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.

[0041] In one embodiment, step 101 above can specifically obtain the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in multiple states in the following manner:

[0042] Obtain the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the oil-saturated state;

[0043] According to the nuclear magnetic resonance transverse relaxation theory, use tritiated water or manganese ion water to shield the signal of the aqueous fluid in the medium-high permeability reservoir, and obtain 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.

[0044] In specific implementation, first, the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir in the oil-saturated state can be tested; then, according to the nuclear magnetic resonance transverse relaxation theory, use tritiated water or manganese ion water to shield the signal of the aqueous fluid, and test 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.

[0045] In the embodiment of the present invention, the nuclear magnetic resonance T2 spectrum information can include the correspondence between the T2 value and the signal intensity, where the T2 value refers to the transverse relaxation time.

[0046] In step 102 above, the pore distribution information and the oil phase distribution information of the medium-high permeability reservoir can be determined according to the nuclear magnetic resonance T2 spectrum information in multiple states.

[0047] In specific implementation, the oil phase distribution information can include the oil phase space in the irreducible water state and the oil phase space in the residual oil state.

[0048] In one embodiment, step 102 above can specifically include:

[0049] Determine 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 oil-saturated state;

[0050] Determine 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.

[0051] In the above step 103, the pore distribution information and oil phase distribution information of the medium-high permeability reservoir can be utilized, and combined with the wetting type of the core of the medium-high permeability reservoir, the oil-water movable space can be divided in the nuclear magnetic resonance T2 spectrum information under multiple states.

[0052] During specific implementation, the wetting type of the core can be determined according to the obtained core rock sample of the medium-high permeability reservoir, and the wetting type of the core can be water-wet or oil-wet; then, the oil-water movable space can be divided in the nuclear magnetic resonance T2 spectrum information according to the wetting type of the core, the pore distribution information and the oil phase distribution information of the medium-high permeability reservoir.

[0053] In one embodiment, the oil-water movable space can include a pore space, a movable water space and a movable oil space;

[0054] The above step 103 can specifically include:

[0055] Determine the pore space according to the pore distribution information of the medium-high permeability reservoir;

[0056] When the wetting type of the core of the medium-high permeability reservoir is water-wet, the oil phase space in the irreducible water state is determined 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, the movable oil space is obtained;

[0057] When the wetting type of the core of the medium-high permeability reservoir is oil-wet, after subtracting the oil phase space in the residual oil state from the oil phase space in the irreducible water state, the movable water space is obtained, and the oil phase space in the irreducible water state is determined as the movable oil space.

[0058] During specific implementation, in the pore space, both oil and water can flow, the movable water space is the space where only water can flow; the movable oil space is the space where only oil can flow.

[0059] In this way, the oil-water movable space can be divided based on the oil-water flow characteristics under different states.

[0060] For example, Figure 2 is a schematic diagram of the oil-water movable space when the wetting type of the core provided by the embodiment of the present invention is water-wet, as Figure 2 shown. In the nuclear magnetic resonance T2 spectrum information, the corresponding relationship between the T2 value and the signal intensity can be represented in the form of a coordinate curve. In the coordinate curve, the horizontal axis is the T2 value, the vertical axis is the signal intensity, and the area enclosed by the curve corresponding to the saturated oil state and the X-axis is used as the pore space, where both oil and water can flow; the area enclosed by the curve in the irreducible water state and the X-axis is used as the movable water space, and the area enclosed by the curve in the irreducible water state and the curve in the residual oil state is used as the movable oil space.

[0061] In the above step 104, according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability reservoir under multiple states, the corresponding relationship between the normalized saturation of the oil-water movable space and the T2 value can be determined.

[0062] In one embodiment, the above step 104 may specifically include:

[0063] According to the corresponding relationship between the T2 value and the signal intensity in the oil-saturated state, determine the oil-water movable signal intensities corresponding to different T2 values in the pore space;

[0064] According to the corresponding relationship between the T2 value and the signal intensity in the irreducible water state and the corresponding relationship between the T2 value and the signal intensity in the residual oil state, determine 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;

[0065] 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, determine 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.

[0066] During specific implementation, since the nuclear magnetic resonance T2 spectrum information refers to the corresponding relationship between the T2 value and the signal intensity, therefore, according to the nuclear magnetic resonance T2 spectrum information under multiple states, the oil-water movable signal intensities, water-phase movable signal intensities, and oil-phase movable signal intensities corresponding to the T2 values in the pore space, movable oil space, and movable water space can be determined respectively; and then the corresponding relationships between the normalized saturations of the pore space, movable water space, and movable oil space and the T2 value can be obtained.

[0067] During specific implementation, in the entire void space, both oil and water can flow. 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 intensities corresponding to different T2 values in the pore space.

[0068] In one embodiment, according to the corresponding relationship between the T2 value and the signal intensity in the irreducible water state and the corresponding relationship between the T2 value and the signal intensity in the residual oil state, to determine 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, it may specifically include:

[0069] Through the following formula, determine 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:

[0070] Iw = I wc

[0071] I nw = I wc -I or

[0072] wherein, 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;

[0073] wherein, when the wetting phase is an aqueous phase, the non-wetting phase is an oil phase; when the wetting phase is an oil phase, the non-wetting phase is an aqueous phase.

[0074] Thus, based on the above formula, the movable signal intensities of the aqueous phase and the oil phase corresponding to different T2 values in the movable water space and the movable oil space can be determined.

[0075] In one embodiment, according to the oil-water movable signal intensities corresponding to different T2 values in the pore space, the aqueous-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, to determine the corresponding relationships between the normalized saturations and the T2 values in the pore space, the movable water space, and the movable oil space, specifically, it may include:

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

[0077] Take the normalized oil-water movable signal intensities corresponding to different T2 values in the pore space as the normalized saturations corresponding to different T2 values, to obtain the corresponding relationship between the normalized saturation and the T2 value in the pore space;

[0078] Take the normalized aqueous-phase movable signal intensities corresponding to different T2 values in the movable water space as the normalized saturations corresponding to different T2 values, to obtain the corresponding relationship between the normalized saturation and the T2 value in the movable water space;

[0079] Taking the normalized movable oil-phase signal intensity corresponding to different T2 values in the movable oil space as the normalized saturation corresponding to different T2 values, the corresponding relationship between the normalized saturation in the movable oil space and the T2 value is obtained.

[0080] In specific implementation, the corresponding relationships between the normalized saturations in the pore space, the movable water space, and the movable oil space and the T2 value can be displayed in a coordinate system in the form of curves, where the horizontal axis is the normalized saturation and the vertical axis is the T2 value. For example, Figure 3 This is an example graph of the corresponding relationship curve between the normalized saturation in the movable oil-water space and the T2 value (transverse relaxation time) provided by the embodiment of the present invention. As Figure 3 shown, different curves respectively represent the T2 values corresponding to different percentages of the pore space, the movable water space, and the movable oil space occupied.

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

[0082] In 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] According to the corresponding relationship between the normalized saturation in the movable oil-water 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;

[0085] Convert the normalized saturation into the core saturation, and determine the oil-phase relative permeability corresponding to the core saturation and the water-phase relative permeability corresponding to the core saturation 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, so as to obtain the oil-phase relative permeability curve and the water-phase relative permeability curve of the medium-high permeability oil reservoir.

[0086] In one embodiment, according to the corresponding relationship between the normalized saturation in the movable oil-water space and the T2 value and the preset absolute permeability formula based on the transverse relaxation time, calculating the oil-phase relative permeability corresponding to different normalized saturations and the water-phase relative permeability corresponding to different normalized saturations respectively may specifically include:

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

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

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

[0092] Its integral form can be the following formula (2):

[0093]

[0094] Wherein, in formula (1) and formula (2), ρ2 represents the surface relaxation intensity, m / ms; F S represents the pore shape factor; represents the porosity; i can be expressed as the serial number of the T2 spectral component here; S i represents the saturation corresponding to the i-th T2 spectral component; T 2i represents the T2 value (i.e., the transverse relaxation time, ms) corresponding to the i-th T2 spectral component; τ represents the tortuosity.

[0095] 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 effective oil-phase permeability corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation can be calculated.

[0096] The effective oil-phase permeability corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation can be expressed by the following formula (3) and formula (4):

[0097]

[0098]

[0099]

[0100]

[0101] Among them, K o represents the effective permeability of the oil phase corresponding to the normalized saturation; K w represents the effective permeability of the water phase corresponding to the 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 in the mobile oil space (i.e., the T2 value corresponding to the normalized saturation corresponding to the i-th T2 spectral component in the mobile oil space); T 2mwi represents the T2 value corresponding to the i-th normalized saturation in the mobile water space (i.e., the T2 value corresponding to the normalized saturation corresponding to the i-th T2 spectral component in the mobile water space); T 2i In this formula, it can be expressed as the T2 value corresponding to the i-th normalized saturation in the pore space; S mo represents the mobile oil saturation corresponding to the i-th normalized saturation; S mw represents the mobile water saturation corresponding to the i-th normalized saturation; I o (T 2moi ) represents the mobile oil signal intensity of the oil phase corresponding to the i-th normalized saturation in the mobile oil space; I w (T 2mwi ) represents the mobile water signal intensity of the water phase corresponding to the i-th normalized saturation in the mobile water space; I(T 2i ) represents the mobile oil and water signal intensity corresponding to the i-th normalized saturation in the pore space; τ osi represents the tortuosity of the oil phase at the saturation corresponding to the i-th T2 spectral component; τ wsi represents the tortuosity of the water phase at the saturation corresponding to the i-th T2 spectral component.

[0102] In the embodiments of the present invention, the tortuosities of the oil phase and the water phase at different saturations are as Figure 4 shown, Figure 4 in which, 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.

[0103] Next, according to the absolute permeability in 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 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 calculated respectively.

[0104] In one embodiment, the relative permeability of the oil phase corresponding to different normalized saturations can be expressed by the following formula (7):

[0105]

[0106] The relative permeability of the aqueous phase corresponding to different normalized saturations can be expressed by the following formula (8):

[0107]

[0108] Among them, in the above formula, K ro represents the relative permeability of the oil phase corresponding to different normalized saturations; K rw represents the relative permeability of the aqueous phase corresponding to different normalized saturations; τ ro represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the oil phase under two-phase seepage conditions; τ rw represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the aqueous phase under two-phase seepage conditions;

[0109] Among them, τ ro and τ rw are set by the following formula:

[0110]

[0111]

[0112] τ rwt represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the wetting phase under two-phase seepage conditions; τ nrwt represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the non-wetting phase under two-phase seepage conditions; S wt represents the wetting-phase saturation of the core; S nwt represents the non-wetting-phase saturation of the core; S min represents the minimum wetting-phase saturation of the core; S nwtr represents the non-wetting residual saturation of the core;

[0113] In the case where the wetting phase of the core is the aqueous phase, the non-wetting is the oil phase; in the case where the wetting phase of the core is the oil phase, the non-wetting is the aqueous phase.

[0114] In specific implementation, according to the above formula (9) and formula (10), for example, in the case where the wetting phase is the aqueous phase, τ rwt represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the aqueous phase under two-phase seepage conditions, that is, τ rwt = τ rw ; τ nrwt represents the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the oil phase under two-phase seepage conditions, that is, τ nrwt = τ ro ; S wt represents the aqueous-phase saturation of the core; S nwt represents the oil-phase saturation of the core; S minDenotes the minimum aqueous saturation of the core, which is the irreducible water saturation for a water-wet core; S nwtr Denotes the residual saturation of the oil phase in the core, which is the residual oil saturation for a water-wet core.

[0115] Alternatively, in the case where the wetting phase is the oil phase, τ rwt Denotes the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the oil phase under two-phase flow conditions, i.e., τ rwt = τ ro ; τ nrwt Denotes the ratio of the tortuosity when only one fluid is saturated to the tortuosity of the aqueous phase under two-phase flow conditions, i.e., τ nrwt = τ rw ; S wt Denotes the oil phase saturation of the core; S nwt Denotes the aqueous phase saturation of the core; S min Denotes the minimum oil phase saturation of the core, S nwtr Denotes the residual saturation of the aqueous phase in the core.

[0116] Finally, the normalized saturation is converted into the core saturation. Based on the relative permeability of the oil phase corresponding to different normalized saturations and the relative permeability of the aqueous phase corresponding to different normalized saturations, the relative permeability curve of the oil phase corresponding to the corresponding core saturation and the relative permeability curve of the aqueous phase corresponding to the core saturation can be obtained, and the relative permeability curve of the oil phase and the relative permeability curve of the aqueous phase in the medium-high permeability oil reservoir are obtained.

[0117] In one embodiment, the oil phase saturation and the aqueous phase saturation of the core can be obtained through the following formulas (11) and (12):

[0118] S w = S1×(1 - S wc - S or ) + S wc Formula (11)

[0119] S o = S1×(1 - S wc - S or ) + S or Formula (12)

[0120] Where:

[0121]

[0122]

[0123] Where, S w Denotes the aqueous phase saturation of the core; S o Denotes the oil phase saturation of the core; S1 denotes the normalized saturation; S wcDenote the irreducible water saturation; S or Denote the residual oil saturation; I or (T 2i ) Denote the signal intensity corresponding to T in the nuclear magnetic resonance T2 spectrum information under the residual oil state; I 2i ; I wc (T 2i ) Denote the signal intensity corresponding to T in the nuclear magnetic resonance T2 spectrum information under the irreducible water state; I(T 2i ; I(T 2i ) Denote the signal intensity corresponding to T in the nuclear magnetic resonance T2 spectrum information under the saturated oil state; I 2i ; I

[0124] In this way, by converting the normalized saturation into the core saturation, and then corresponding the core saturation with the relative permeability of the oil phase and the relative permeability of the water phase under the normalized saturation, the relative permeability of the oil phase corresponding to the core saturation and the relative permeability of the water phase corresponding to the core saturation are constructed. For example, Figure 5 is a schematic diagram of the relative permeability curves of the oil phase and the water phase corresponding to the core saturation provided by the embodiment of the present invention, as Figure 5 shown, as the water saturation of the core increases, the relative permeability of the water phase increases, and the relative permeability of the oil phase decreases, which is consistent with the actual situation.

[0125] In the embodiment of the present invention, through the above method for determining the oil-water relative permeability information of the medium-high permeability oil reservoir, the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve can be solved, and the accuracy of the obtained relative permeability curve can be improved.

[0126] In the embodiment of the present invention, a device for determining the oil-water relative permeability information of a medium-high permeability oil reservoir is also provided, as described in the following embodiments. Since the principle of the device for solving the problem is similar to the method for determining the oil-water relative permeability information of a medium-high permeability oil reservoir, the implementation of the device can refer to the implementation of the method for determining the oil-water relative permeability information of a medium-high permeability oil reservoir, and the repeated parts will not be described again.

[0127] As Figure 6 shown, it is a schematic diagram of a device for determining the oil-water relative permeability information of a medium-high permeability oil reservoir provided by the embodiment of the present invention. The device may include:

[0128] An acquisition module 601, configured to acquire nuclear magnetic resonance T2 spectrum information of a medium-high permeability oil reservoir in multiple states; the nuclear magnetic resonance T2 spectrum information in multiple states includes: nuclear magnetic resonance T2 spectrum information under the saturated oil state, nuclear magnetic resonance T2 spectrum information under the irreducible water state, and nuclear magnetic resonance T2 spectrum information under the residual oil state; the nuclear magnetic resonance T2 spectrum information includes the correspondence between T2 values and signal intensities;

[0129] An information determination module 602, configured to determine pore distribution information and oil phase distribution information of a medium-high permeability oil reservoir according to nuclear magnetic resonance T2 spectrum information in multiple states;

[0130] A partitioning module 603, configured to partition the oil-water movable space in the nuclear magnetic resonance T2 spectrum information in multiple states by using the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir and combining the wetting type of the core of the medium-high permeability oil reservoir;

[0131] A first processing module 604, configured to determine 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 in multiple states;

[0132] A second processing module 605, configured 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 correspondence between the normalized saturation of the oil-water movable space and the T2 value.

[0133] In one embodiment, the acquisition module may specifically be configured to:

[0134] Acquire nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the oil-saturated state;

[0135] According to the nuclear magnetic resonance transverse relaxation theory, use tritiated water or manganese ion water to shield the signals of the aqueous fluid in the medium-high permeability oil reservoir, and acquire nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the irreducible water state and nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the residual oil state.

[0136] In one embodiment, the information determination module may specifically be configured to:

[0137] Determine 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 oil-saturated state;

[0138] Determine 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 of the medium-high permeability oil reservoir in the residual oil state.

[0139] 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 represents a space where both oil and water can flow;

[0140] The partitioning module may specifically be configured to:

[0141] Determine the pore space according to the pore distribution information of the medium-high permeability oil reservoir;

[0142] When the wetting type of the core in the medium-high permeability oil reservoir is water-wet, the oil-phase space in the irreducible water state is determined as the movable water space, and after subtracting the oil-phase space in the irreducible water state from the oil-phase space in the residual oil state, it is determined as the movable oil space;

[0143] When the wetting type of the core in the medium-high permeability oil reservoir is oil-wet, after subtracting the oil-phase space in the residual oil state from the oil-phase space in the irreducible water state, it is determined as the movable water space, and the oil-phase space in the irreducible water state is determined as the movable oil space.

[0144] In one embodiment, the first processing module may specifically be used for:

[0145] According to the correspondence between the T2 value and the signal intensity in the oil-saturated state, determine the oil-water movable signal intensity corresponding to different T2 values in the pore space;

[0146] 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, determine 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;

[0147] According to 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, 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.

[0148] In one embodiment, the first processing module may further be used for:

[0149] Determine 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 through the following formula:

[0150] I w =I wc

[0151] I nw =I wc -I or

[0152] wherein, I w represents the wetting-phase movable signal intensity, I wc represents the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information in the irreducible water state, I nw represents the non-wetting-phase movable signal intensity, I orRepresents the signal intensity corresponding to the T2 value in the nuclear magnetic resonance T2 spectrum information in the residual oil state;

[0153] Wherein, when the wetting phase is an aqueous phase, the non-wetting phase is an oil phase; when the wetting phase is an oil phase, the non-wetting phase is an aqueous phase.

[0154] In one embodiment, the first processing module may further be configured to:

[0155] Normalize the oil-water movable signal intensity corresponding to different T2 values in the pore space, the aqueous 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, respectively, to obtain the normalized oil-water movable signal intensity corresponding to different T2 values in the pore space, the normalized aqueous 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;

[0156] 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 value;

[0157] Use the normalized aqueous 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 value;

[0158] 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 value.

[0159] In one embodiment, the second processing module may specifically be configured to:

[0160] According to the corresponding relationship between the normalized saturation and the T2 value in the oil-water movable space 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;

[0161] Convert the normalized saturation to 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.

[0162] In one embodiment, the second processing module may further be configured to:

[0163] According to the correspondence 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 effective oil-phase permeability formula corresponding to the normalized saturation and the effective permeability corresponding to the normalized saturation.

[0164] According to the absolute permeability formula based on the transverse relaxation time, the effective oil-phase permeability corresponding to the normalized saturation, and the effective permeability corresponding to the normalized saturation, determine the relative oil-phase permeability corresponding to different normalized saturations and the relative water-phase permeability corresponding to different normalized saturations.

[0165] An embodiment of the present invention also provides a computer device, as Figure 7 shown, which is a schematic diagram of the computer device in the embodiment of the present invention. The computer device 700 includes a memory 710, a processor 720, and a computer program 730 stored on the memory 710 and executable on the processor 720. When the processor 720 executes the computer program 730, it implements the method for determining the oil-water relative permeability information of the above medium-high permeability reservoir.

[0166] An embodiment of the present invention also provides a computer-readable storage medium. The computer-readable storage medium stores a computer program, and when the computer program is executed by a processor, it implements the method for determining the oil-water relative permeability information of the above medium-high permeability reservoir.

[0167] An embodiment of the present invention also provides a computer program product. The computer program product includes a computer program, and when the computer program is executed by a processor, it implements the method for determining the oil-water relative permeability information of the above medium-high permeability reservoir.

[0168] In an embodiment of the present invention, nuclear magnetic resonance T2 spectrum information of a medium-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 an irreducible water state, and nuclear magnetic resonance T2 spectrum information in a residual oil state; the nuclear magnetic resonance T2 spectrum information includes the correspondence between T2 values and signal intensities; according to the nuclear magnetic resonance T2 spectrum information in multiple states, pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir are determined; 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, the oil-water movable space is divided in the nuclear magnetic resonance T2 spectrum information in multiple states; according to the nuclear magnetic resonance T2 spectrum information of the medium-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; according to 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-high permeability oil reservoir are determined. Compared with the existing solution for determining the oil-water relative permeability of a medium-high permeability oil reservoir, the problem that the oil-water flow law cannot be considered when determining the existing relative permeability curve can be solved, and the accuracy of the obtained relative permeability curve can be improved.

[0169] Those skilled in the art should understand that the embodiments of the present invention can be provided as a method, a system, or a computer program product. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Moreover, the present invention can take the form of a computer program product implemented on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0170] The present invention is described with reference to the flowcharts and / or block diagrams of methods, apparatuses (systems), and computer program products according to embodiments of the present invention. It should be understood that each flow and / or block in the flowcharts and / or block diagrams, and the combination of flows and / or blocks in the flowcharts and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to the processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing devices to generate a machine, such that the instructions executed by the processor of the computer or other programmable data processing devices generate means for implementing the functions specified in Figure 1 one flow or multiple flows and / or blocks Figure 1 one block or multiple blocks.

[0171] These computer program instructions can also be stored in a computer-readable memory capable of guiding a computer or other programmable data processing devices to work in a specific manner, such that the instructions stored in the computer-readable memory generate a manufactured article including instruction means, and the instruction means implements the functions in the flow Figure 1One or more processes and / or boxes Figure 1 The functions specified in one box or more boxes.

[0172] These computer program instructions can also be loaded onto a computer or other programmable data processing device, so that a series of operation steps are executed on the computer or other programmable device to generate a computer-implemented process. Thus, the instructions executed on the computer or other programmable device provide steps for implementing the functions specified in one process Figure 1 One or more processes and / or boxes Figure 1 The steps of the functions specified in one box or more boxes.

[0173] In the specific embodiments described above, the purpose, technical solutions, and beneficial effects of the present invention have been further described in detail. It should be understood that the above are only specific embodiments of the present invention and are not used to limit the protection scope of the present invention. Any modifications, equivalent replacements, improvements, etc. made within the spirit and principles of the present invention shall be included in the protection scope of the present invention.

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 multiple states; Utilizing the pore distribution information and oil phase distribution information of the medium-high permeability oil reservoir, and combining with the wetting 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 multiple states; Determining the correspondence between the normalized saturation and T2 values of the oil-water movable space according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states; Determining the oil phase relative permeability curve and water phase relative permeability curve of the medium-high permeability oil reservoir according to the correspondence between the normalized saturation and T2 values of the oil-water movable space.

2. The method according to claim 1, wherein Obtaining the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states, including: Obtaining the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the saturated oil state; 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 multiple states, including: 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; 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 wetting 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 multiple states, including: Determining the pore space according to the pore distribution information of the medium-high permeability oil reservoir; When the wetting 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; When the wetting 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, characterized in that Determining the correspondence between the normalized saturation and T2 values of the oil-water movable space according to the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir under multiple states, including: Determining the oil-water movable signal intensities corresponding to different T2 values of the pore space according to the correspondence between the T2 values and 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 bound water state and the correspondence between the T2 values and the signal intensities in the residual oil state; 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, characterized in that 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 bound 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, 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.

7. The method according to claim 5, characterized in that, 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: Perform normalization processing on 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; Take 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; Take 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; Take 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, characterized in that Determine the oil-phase relative permeability curve and the water-phase relative permeability curve of the medium-high permeability oil reservoir according to the correspondence between the normalized saturation and the T2 value in the movable oil-water space, 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; Convert the normalized saturation to the core saturation. 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, and 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; 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 nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in multiple states; The nuclear magnetic resonance T2 spectrum information in the multiple states includes: nuclear magnetic resonance T2 spectrum information in the oil-saturated 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 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 in multiple states; A division module for dividing the oil-water movable space in the nuclear magnetic resonance T2 spectrum information in 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 in multiple states; 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, wherein The acquisition module is specifically used for: Acquiring the nuclear magnetic resonance T2 spectrum information of the medium-high permeability oil reservoir in the oil-saturated state; According to the nuclear magnetic resonance transverse relaxation theory, use tritiated water or manganese ion water to shield the signal of the water-phase fluid in the medium-high permeability oil reservoir, and acquire 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.

12. The device according to claim 10, wherein The information determination module is specifically used for: Determine 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; Determine 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 of the residual oil state.

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

14. The device according to claim 13, characterized in that, The first processing module is specifically configured to: Determine the oil-water mobile 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 water-phase mobile signal intensities corresponding to different T2 values in the mobile water space and the oil-phase mobile signal intensities corresponding to different T2 values in the mobile 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; 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 mobile water space, and the correspondence between the normalized saturation and the T2 value in the mobile oil space according to the oil-water mobile signal intensities corresponding to different T2 values in the pore space, the water-phase mobile signal intensities corresponding to different T2 values in the mobile water space, and the oil-phase mobile signal intensities corresponding to different T2 values in the mobile oil space.

15. The device according to claim 14, wherein The first processing module is further configured to: Determine the water-phase mobile signal intensities corresponding to different T2 values in the mobile water space and the oil-phase mobile signal intensities corresponding to different T2 values in the mobile 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.

16. The device according to claim 14, characterized in that, The first processing module is further configured to: Perform normalization processing on the oil-water mobile signal intensities corresponding to different T2 values in the pore space, the water-phase mobile signal intensities corresponding to different T2 values in the mobile water space, and the oil-phase mobile signal intensities corresponding to different T2 values in the mobile oil space respectively, to obtain the normalized oil-water mobile signal intensities corresponding to different T2 values in the pore space, the normalized water-phase mobile signal intensities corresponding to different T2 values in the mobile water space, and the normalized oil-phase mobile signal intensities corresponding to different T2 values in the mobile oil space; Use the normalized oil-water mobile 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; Taking the normalized mobile signal intensity of the aqueous phase corresponding to different T2 values in the mobile water space as the normalized saturation corresponding to different T2 values, the corresponding relationship between the normalized saturation of the mobile water space and the T2 value is obtained; Taking the normalized mobile signal intensity of the oil phase corresponding to different T2 values in the mobile oil space as the normalized saturation corresponding to different T2 values, the corresponding relationship between the normalized saturation of the mobile oil space and the T2 value is obtained.

17. The device according to claim 16, wherein The second processing module is specifically configured to: According to the corresponding relationship between the normalized saturation of the oil-water mobile 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; 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, and 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 configured to: According to the corresponding relationship between the normalized saturation of the oil-water mobile 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; 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, the method according to any one of claims 1 to 9 is implemented.

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, the method according to any one of claims 1 to 9 is implemented.

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, the method according to any one of claims 1 to 9 is implemented.

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