VHSD steam chamber and yield parameter prediction method and device, electronic equipment and medium

Abstract

The invention discloses a VHSD steam chamber and yield parameter prediction method and device, electronic equipment and a medium. The method comprises the steps that the horizontal well huff and puff oil layer production height and the horizontal distance between an injection-production communication initial position and a production well are determined; calculating the initial time of the stable gravity oil drainage stage by utilizing the horizontal distance from the injection-production communication initial position to the production well and the viscosity-temperature coefficient of crude oil, the kinematic viscosity of crude oil at the saturated steam temperature, the porosity, the movable oil saturation, the thickness of an oil layer, the permeability, the relative permeability of an oil phase and the heat conduction coefficient of a horizontal well length rock in the data; and according to the initial time of the stable gravity oil drainage stage, the horizontal distance between the injection-production communication initial position and the production well and data, the steam cavity front edge expansion speed, the steam cavity horizontal expansion distance and the total oil drainage yield are obtained. According to the technical scheme, quantitative characterization of the steam cavity form and the expansion rule in the steam cavity transverse expansion stage and the steam cavity descending stage can be achieved, yield prediction can be achieved, and the prediction precision is high.

Description

Technical Field

[0001] The present invention relates to the field of steam injection development technology, and in particular to a method, device, electronic equipment and medium for predicting a VHSD steam chamber and production parameters. Background Art

[0002] Thermal recovery is the most widely used method for heavy oil development. It includes steam stimulation, steam flooding, steam-assisted gravity drainage, and fire flooding. Currently, almost all old heavy oil fields use steam stimulation in the early stages of development. However, the control range of a single well of steam stimulation is limited, with an effective radius of generally 20-30m, and the recovery rate can only reach about 20%. The efficient follow-up development method after steam stimulation has always been the most important technical direction in the field of heavy oil development.

[0003] VHSD is a technology developed based on the concepts of steam flooding and steam-assisted gravity drainage, combining the characteristics of geological reservoirs and heavy oil development methods. It adopts a well pattern that combines steam injection and horizontal wells. Vertical wells serve as injection wells to continuously inject high-dryness steam into the oil layer, and horizontal wells are arranged at the bottom of the oil layer as production wells to achieve gravity drainage development. It has become the most effective follow-up development technology in the later stage of steam stimulation.

[0004] Current theoretical research on VHSD development technology is still immature. The special well pattern combination of vertical and horizontal wells leads to complex steam chamber development patterns and development and production rules. Production predictions are mostly based on numerical simulation methods. The existing production prediction models can only realize the production capacity evaluation of specific oil reservoirs, and cannot achieve quantitative characterization of steam chambers. There is a lack of fast and accurate production prediction models. Summary of the Invention

[0005] The present invention provides a method, device, electronic equipment and medium for predicting VHSD steam chamber and yield parameters, which can achieve quantitative characterization of the steam chamber morphology and expansion law during the steam chamber lateral expansion and steam chamber descent stages, and can achieve yield prediction during the steam chamber lateral expansion and descent stages with high prediction accuracy.

[0006] According to one aspect of the present invention, a method for predicting VHSD steam chamber and production parameters is provided, the method comprising:

[0007] Acquire data on the target block; wherein the data consists of reservoir geological data and reservoir development and production dynamic data;

[0008] Based on the data, determine the production height of the horizontal well and the horizontal distance between the initial injection-production connection point and the production well;

[0009] Calculate the initial time of the stable gravity drainage stage using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, and horizontal well length rock thermal conductivity coefficient in the data;

[0010] Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and other data, the VHSD steam chamber and production parameters were predicted to obtain the steam chamber front expansion velocity, the horizontal expansion distance of the steam chamber, and the total drainage production.

[0011] According to another aspect of the present invention, a VHSD steam chamber and production parameter prediction device is provided, the device comprising:

[0012] A data acquisition module is used to acquire data of the target block; wherein the data is composed of reservoir geological data and reservoir development and production dynamic data;

[0013] A height and distance calculation module is used to determine the production height of the horizontal well and the horizontal distance between the initial injection-production connection position and the production well based on the data;

[0014] a module for calculating the initial time of the stable gravity drainage phase, for calculating the initial time of the stable gravity drainage phase using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data;

[0015] The VHSD parameter prediction module is used to predict the VHSD steam chamber and production parameters based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and other data, to obtain the steam chamber front expansion speed, the horizontal expansion distance of the steam chamber, and the total drainage production.

[0016] According to another aspect of the present invention, an electronic device is provided, comprising:

[0017] at least one processor; and

[0018] a memory communicatively connected to the at least one processor; wherein,

[0019] The memory stores a computer program executable by the at least one processor. The computer program is executed by the at least one processor so that the at least one processor can execute the VHSD steam chamber and production parameter prediction method according to any embodiment of the present invention.

[0020] According to another aspect of the present invention, a computer-readable medium is provided, wherein the computer-readable medium stores computer instructions, and wherein the computer instructions are configured to cause a processor to implement the VHSD steam chamber and yield parameter prediction method according to any embodiment of the present invention when executed.

[0021] The technical solution of the embodiment of the present invention obtains data from the target block and, based on the data, determines the horizontal well throughput oil layer production height and the horizontal distance between the initial injection-production connection point and the production well. Using the horizontal distance between the initial injection-production connection point and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, and horizontal well length rock thermal conductivity in the data, the initial time of the stable gravity drainage phase is calculated. Based on the initial time of the stable gravity drainage phase, the horizontal distance between the initial injection-production connection point and the production well, and the data, the VHSD steam chamber and production parameters are predicted to obtain the steam chamber front expansion velocity, steam chamber horizontal expansion distance, and total drainage production. This technical solution can quantitatively characterize the steam chamber morphology and expansion patterns during the steam chamber lateral expansion and steam chamber decline phases, and can predict the production during the steam chamber lateral expansion and decline phases with high prediction accuracy.

[0022] It should be understood that the content described in this section is not intended to identify the key or important features of the embodiments of the present invention, nor is it intended to limit the scope of the present invention. Other features of the present invention will become readily understood through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0024] Figure 1 This is a flow chart of a method for predicting VHSD steam chamber and production parameters according to the first embodiment of the present invention;

[0025] Figure 2 This is a schematic diagram of a steam chamber in a cross section of an injection-production well provided in Example 1 of the present application;

[0026] Figure 3 This is a schematic diagram of the expansion of the steam chamber interface provided in Example 1 of the present application;

[0027] Figure 4 This is a daily oil production comparison curve provided in Example 1 of the present application;

[0028] Figure 5A schematic structural diagram of a VHSD steam chamber and a production parameter prediction device provided in Example 2 of the present invention;

[0029] Figure 6 The present invention is a schematic structural diagram of an electronic device for implementing a VHSD steam chamber and a yield parameter prediction method according to an embodiment of the present invention. DETAILED DESCRIPTION

[0030] In order to enable those skilled in the art to better understand the solutions of the present invention, the technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the embodiments described are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative efforts should fall within the scope of protection of the present invention.

[0031] It should be noted that the terms "object" and "target" in the description and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that the numbers used in this way can be interchanged where appropriate so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions. For example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0032] Example 1

[0033] Figure 1 This is a flow chart of a method for predicting VHSD steam chamber and production parameters according to the first embodiment of the present invention. This embodiment is applicable to the production prediction of VHSD development of heavy oil reservoirs. The method can be executed by a VHSD parameter prediction device. The VHSD parameter prediction device can be implemented in the form of hardware and / or software. The VHSD parameter prediction device can be configured in an electronic device. Figure 1 As shown, the method includes:

[0034] S110, obtaining data of the target block; wherein the data consists of reservoir geological data and reservoir development and production dynamic data.

[0035] In this plan, VHSD, also known as vertical-horizontal SAGD, refers to a heavy oil development method that uses a well pattern that combines vertical and horizontal wells. Vertical wells serve as injection wells to continuously inject high-dryness steam into the oil layer, and horizontal wells are arranged at the bottom of the oil layer as production wells. This is an effective successor development method for heavy oil in the later stage of steam stimulation.

[0036] The target block data include oil layer thickness H, initial oil saturation S oi , porosity Permeability k, original formation temperature T R , viscosity-temperature curve, relative permeability curve, vertical-horizontal well spacing L, horizontal well length, rock thermal conductivity coefficient α, horizontal well throughput cumulative oil production C oil , VHSD oil drainage stage operating pressure p, oil phase relative permeability k ro , residual oil saturation S or .

[0037] In this embodiment, reservoir geological data and reservoir development and production dynamic data can be obtained during the development of the target block reservoir.

[0038] S120. Determine, based on the data, the oil layer producing height of the horizontal well and the horizontal distance between the initial injection-production connection position and the production well.

[0039] In this scheme, the various data in the data can be combined and calculated to determine the horizontal well throughput oil layer production height H0 and the horizontal distance W between the initial position of the injection-production connection and the production well.

[0040] Optionally, determining the production height of the horizontal well's oil reservoir and the horizontal distance between the initial injection-production connection position and the production well based on the data includes:

[0041] Calculate the producing height of the oil layer during the horizontal well huff and puff according to the cumulative oil production, porosity, initial oil saturation and residual oil saturation of the horizontal well in the data;

[0042] The horizontal distance between the initial injection-production connection position and the production well is calculated based on the oil layer production height of the horizontal well and the oil layer thickness and the vertical-horizontal well spacing in the data.

[0043] Specifically, the following formula is used to calculate the production height of the horizontal well reservoir:

[0044]

[0045] Among them, H0 represents the oil layer producing height of horizontal well throughput, cOil represents the cumulative oil production of horizontal well throughput, Represents porosity, S oi Indicates the original oil saturation, S orIndicates residual oil saturation.

[0046] Furthermore, after calculating the horizontal well throughput oil layer production height, the horizontal well throughput oil layer production height and the oil layer thickness and vertical well spacing in the data can be combined to calculate the horizontal distance between the initial position of the injection and production connection and the production well.

[0047] Specifically, the horizontal distance between the initial injection-production connection position and the production well is calculated using the following formula:

[0048]

[0049] Where W represents the horizontal distance between the initial injection-production connection position and the production well, H0 represents the reservoir production height of the horizontal well, H represents the reservoir thickness, and L represents the vertical well spacing.

[0050] By calculating the production height of the horizontal well's oil layer and the horizontal distance between the initial position of the injection-production connection and the production well, it is possible to quantitatively characterize the steam chamber morphology and expansion law during the lateral expansion and decline stages of the steam chamber, and to predict the production during the lateral expansion and decline stages of the steam chamber with high prediction accuracy.

[0051] S130. Calculate the initial time of the stable gravity drainage phase using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, and horizontal well length rock thermal conductivity coefficient in the data.

[0052] In this embodiment, Figure 2 This is a schematic diagram of the steam chamber of the injection and production well provided in Example 1 of the present application, as shown in FIG. Figure 2 As shown in the figure, based on the VHSD operation mode and steam chamber development patterns, VHSD can be divided into three development stages: steam stimulation, steam flooding, and gravity drainage. The gravity drainage stage is further subdivided into the steam chamber lateral expansion and steam chamber decline stages. This allows the injection and production well profile to be determined at the initial time t0 of gravity drainage. The steam chamber development pattern includes three stages: formation, lateral expansion, and downward expansion.

[0053] In this scheme, after calculating the horizontal distance between the initial injection-production connection position and the production well, the horizontal distance between the initial injection-production connection position and the production well can be combined with the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data to calculate the initial time of the stable gravity drainage stage.

[0054] Optionally, the initial time of the stable gravity drainage stage is calculated using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, and horizontal well length rock thermal conductivity in the data, including:

[0055] The initial time of the stable gravity drainage stage is calculated according to a predetermined formula for calculating the initial time of the stable gravity drainage stage by combining the horizontal distance between the initial injection-production connection point and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data.

[0056] Specifically, the initial time of the stable gravity drainage stage can be calculated using the following formula:

[0057]

[0058] Among them, t0 represents the initial time of the stable gravity drainage stage, H0 represents the oil layer production height of the horizontal well, H represents the oil layer thickness, L represents the vertical well spacing, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o represents, k represents permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, and α represents the thermal diffusivity.

[0059] By calculating the initial time of the stable gravity drainage stage, it is possible to quantitatively characterize the morphology and expansion law of the steam chamber during the lateral expansion and descent stages of the steam chamber based on the initial time of the stable gravity drainage stage, and to predict the production during the lateral expansion and descent stages of the steam chamber with high prediction accuracy.

[0060] S140. Predict the VHSD steam chamber and production parameters based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and the data to obtain the steam chamber front expansion speed, the steam chamber horizontal expansion distance, and the total drainage production.

[0061] In this plan, Figure 3 This is a schematic diagram of the steam chamber interface expansion provided in Example 1 of the present application. Figure 3 As shown, the range of t is t0-t n By simplifying the lateral expansion pattern of the steam chamber, the expansion speed and expansion distance of the steam chamber front at different distances between the injection and production wells can be determined.

[0062] In this embodiment, the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and various data in the data can be combined and calculated to predict the VHSD parameters, thereby obtaining the steam chamber front expansion speed, the horizontal expansion distance of the steam chamber, and the total drainage production.

[0063] Optionally, based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and the data, the VHSD steam chamber and production parameters are predicted to obtain the steam chamber front expansion speed, including

[0064] The following formula is used to calculate the expansion velocity of the steam chamber front edge;

[0065]

[0066] Among them, U x represents the expansion velocity of the steam chamber front, k represents the permeability, and k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. W represents the horizontal distance between the initial injection-production connection position and the production well, t0 represents the initial time of the stable gravity drainage stage, and L represents the distance between the straight and horizontal wells.

[0067]

[0068] Optionally, the horizontal expansion distance of the steam chamber includes the horizontal expansion distance of the steam chamber in the area near the horizontal well and the horizontal expansion distance of the steam chamber in the area near the vertical well steam injection well;

[0069] Accordingly, based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and the data, the VHSD steam chamber and production parameters are predicted to obtain the horizontal expansion distance of the steam chamber, including:

[0070] The horizontal expansion distance of the steam chamber near the horizontal well area is calculated using the following formula:

[0071]

[0072] Where, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v sIt represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. W represents the horizontal distance between the initial position of injection and production connection and the production well. t0 represents the initial time of the stable gravity drainage stage. L represents the distance between the straight and horizontal wells. 0≤x≤W,

[0073] The horizontal expansion distance of the steam chamber in the near-vertical steam injection well area is calculated using the following formula:

[0074]

[0075] Where, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i The shape coefficient is a coefficient determined by the angle between the streamline on the inclined drainage interface and the horizontal well, which is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage, L represents the vertical well spacing, W represents the horizontal distance between the initial injection-production connection position and the production well, and W <x≤L,

[0076] By determining the expansion velocity of the steam chamber front and the horizontal expansion distance of the steam chamber, the development pattern of the complex steam chamber in VHSD is simplified, the quantitative characterization of the VHSD steam chamber is achieved, and the expansion velocity and expansion distance of the steam chamber at different distances between injection and production wells are accurately predicted.

[0077] Optionally, based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and other data, the VHSD steam chamber and production parameters are predicted to obtain the total drainage production, including:

[0078] Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and the data, the VHSD parameters are predicted to obtain the oil leakage rate near the production well area and the oil leakage rate near the injection well area during the lateral expansion stage of the steam chamber;

[0079] The total oil leakage production is obtained by adding the oil leakage in the area near the production well and the oil leakage in the area near the steam injection well during the lateral expansion stage of the steam chamber.

[0080] Optional, including:

[0081] The following formula is used to calculate the oil leakage rate in the area near the production well during the lateral expansion stage of the steam chamber:

[0082]

[0083] Among them, q p represents the oil leakage rate near the production well during the lateral expansion stage of the steam chamber, k represents the permeability, and k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the thermal conductivity of the rock along the horizontal well length, represents porosity, ΔS o Indicates, H represents the oil layer thickness, m represents the viscosity-temperature coefficient of crude oil, v s represents the kinematic viscosity of crude oil at saturated steam temperature, W represents the horizontal distance from the initial injection-production connection position to the production well, and λ i The shape coefficient is a coefficient determined by the angle between the streamline on the inclined drainage interface and the horizontal well, which is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage.

[0084]

[0085] The following formula is used to calculate the oil leakage rate in the area near the steam injection well;

[0086]

[0087] Among them, q i represents the oil leakage rate in the area near the steam injection well, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the thermal conductivity of the rock along the horizontal well length, represents porosity, ΔS o Indicates, H represents the oil layer thickness, m represents the viscosity-temperature coefficient of crude oil, v s represents the kinematic viscosity of crude oil at saturated steam temperature, L represents the vertical well distance, W represents the horizontal distance from the initial injection-production connection position to the production well, and λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage.

[0088] The total oil leakage production is calculated using the following formula:

[0089] q=q p +q i ;

[0090] Where q represents the total oil leakage production.

[0091] By calculating the oil leakage in the area near the production well and the oil leakage in the area near the steam injection well during the lateral expansion stage of the steam chamber, and adding the oil leakage in the area near the production well and the oil leakage in the area near the steam injection well during the lateral expansion stage of the steam chamber, the total oil leakage production is obtained. The calculation speed is fast and the prediction accuracy is high.

[0092] This solution can be used for both extra-heavy oil and ultra-heavy oil reservoirs developed using the VHSD method, and can realize production prediction in the steam chamber lateral expansion stage and steam chamber decline stage of this type of development method.

[0093] Furthermore, the Z reservoir can be selected for VHSD development. The reservoir geological data are shown in Table 1.

[0094] Table 1

[0095]

[0096]

[0097] Furthermore, a homogeneous injection-production model was established to conduct numerical simulations, simulating the complete VHSD development process. This prediction model formula can be used to predict daily oil production during the steam chamber lateral expansion phase and the steam chamber drawdown phase, respectively, and the total oil drainage production can be calculated using the above formula.

[0098] In this embodiment, Figure 4 This is a daily oil production comparison curve provided in Example 1 of this application. Figure 4 As shown in the figure, by comparing the numerical simulation results with the calculation results of this prediction model, the fitting accuracy of the daily oil production prediction in the steam chamber lateral expansion stage and the steam chamber decline stage reaches more than 90%.

[0099] The technical solution of the embodiment of the present invention obtains data of the target block, determines the horizontal well throughput oil layer production height and the horizontal distance between the initial injection-production connection position and the production well based on the data, and uses the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length and rock thermal conductivity coefficient in the data to calculate the initial time of the stable gravity drainage stage. Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and the data, the VHSD parameters are predicted to obtain the steam chamber front expansion velocity, the steam chamber horizontal expansion distance, and the total drainage production. By implementing this technical solution, based on the understanding of the characteristics and production laws of the VHSD steam chamber development stage, the steam chamber development model of VHSD development has been clarified. Based on the heat conduction theory, conservation of matter and oil and gas seepage theory, the quantitative characterization of the steam chamber morphology and expansion law in the gravity drainage stage is achieved. The steam chamber interface and steam chamber lateral expansion model are constructed, and the rapid and accurate prediction of the production in the VHSD steam chamber lateral expansion and decline stages is achieved. This technical solution has broad application prospects.

[0100] Example 2

[0101] Figure 5 This is a schematic diagram of the structure of a steam chamber and a production VHSD parameter prediction device provided in Example 2 of the present invention. Figure 5 As shown, the device includes:

[0102] The data acquisition module 510 is used to acquire data of the target block; wherein the data is composed of reservoir geological data and reservoir development and production dynamic data;

[0103] The height and distance calculation module 520 is used to determine the production height of the horizontal well and the horizontal distance between the initial injection-production connection position and the production well based on the data;

[0104] The module 530 for calculating the initial time of the stable gravity drainage phase is configured to calculate the initial time of the stable gravity drainage phase using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data.

[0105] The VHSD parameter prediction module 540 is used to predict the VHSD steam chamber and production parameters based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and other data to obtain the steam chamber front expansion speed, the horizontal expansion distance of the steam chamber, and the total drainage production.

[0106] Optionally, the height and distance calculation module 520 is specifically configured to:

[0107] Calculate the producing height of the oil layer during the horizontal well huff and puff according to the cumulative oil production, porosity, initial oil saturation and residual oil saturation of the horizontal well in the data;

[0108] The horizontal distance between the initial injection-production connection position and the production well is calculated based on the oil layer production height of the horizontal well and the oil layer thickness and the vertical-horizontal well spacing in the data.

[0109] Optionally, the module 530 for calculating the initial time of the stable gravity drainage phase is specifically configured to:

[0110] The initial time of the stable gravity drainage stage is calculated according to a predetermined formula for calculating the initial time of the stable gravity drainage stage by combining the horizontal distance between the initial injection-production connection point and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data.

[0111] Optionally, the VHSD parameter prediction module 540 is specifically configured to:

[0112] The following formula is used to calculate the expansion velocity of the steam chamber front edge;

[0113]

[0114] Among them, U x represents the expansion velocity of the steam chamber front, k represents the permeability, and k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. W represents the horizontal distance between the initial injection-production connection position and the production well, t0 represents the initial time of the stable gravity drainage stage, and L represents the distance between the straight and horizontal wells.

[0115]

[0116] Optionally, the horizontal expansion distance of the steam chamber includes the horizontal expansion distance of the steam chamber in the area near the horizontal well and the horizontal expansion distance of the steam chamber in the area near the vertical well steam injection well;

[0117] Accordingly, the VHSD parameter prediction module 540 is further configured to:

[0118] The horizontal expansion distance of the steam chamber near the horizontal well area is calculated using the following formula:

[0119]

[0120] Where, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. W represents the horizontal distance between the initial position of injection and production connection and the production well. t0 represents the initial time of the stable gravity drainage stage. L represents the distance between the straight and horizontal wells. 0≤x≤W,

[0121] The horizontal expansion distance of the steam chamber in the near-vertical steam injection well area is calculated using the following formula:

[0122] Where, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage, L represents the vertical well spacing, W represents the horizontal distance between the initial injection-production connection position and the production well, and W <x≤L,

[0123] Optionally, the VHSD parameter prediction module 540 is further configured to:

[0124] Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and the data, the VHSD parameters are predicted to obtain the oil leakage rate near the production well area and the oil leakage rate near the injection well area during the lateral expansion stage of the steam chamber;

[0125] The total oil leakage production is obtained by adding the oil leakage in the area near the production well and the oil leakage in the area near the steam injection well during the lateral expansion stage of the steam chamber.

[0126] Optionally, the VHSD parameter prediction module 540 is further configured to:

[0127] The following formula is used to calculate the oil leakage rate in the area near the production well during the lateral expansion stage of the steam chamber:

[0128]

[0129] Among them, q p represents the oil leakage rate near the production well during the lateral expansion stage of the steam chamber, k represents the permeability, and k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the thermal conductivity of the rock along the horizontal well length, represents porosity, ΔS o Indicates, H represents the oil layer thickness, m represents the viscosity-temperature coefficient of crude oil, v s represents the kinematic viscosity of crude oil at saturated steam temperature, W represents the horizontal distance from the initial injection-production connection position to the production well, and λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage.

[0130] The following formula is used to calculate the oil leakage rate in the area near the steam injection well;

[0131]

[0132] Among them, q i represents the oil leakage rate in the area near the steam injection well, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the thermal conductivity of the rock along the horizontal well length, represents porosity, ΔS o Indicates, H represents the oil layer thickness, m represents the viscosity-temperature coefficient of crude oil, v s represents the kinematic viscosity of crude oil at saturated steam temperature, L represents the vertical well distance, W represents the horizontal distance from the initial injection-production connection position to the production well, and λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage.

[0133] The total oil leakage production is calculated using the following formula:

[0134] q=q p +q i ;

[0135] Where q represents the total oil leakage production.

[0136] A VHSD parameter prediction device provided by an embodiment of the present invention can execute a VHSD parameter prediction method provided by any embodiment of the present invention, and has corresponding functional modules and beneficial effects of executing the method.

[0137] Example 3

[0138] Figure 6 A schematic diagram of the structure of an electronic device 10 that can be used to implement an embodiment of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the present invention described and / or claimed herein.

[0139] like Figure 6 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., which is communicatively connected to the at least one processor 11. The memory stores a computer program that can be executed by the at least one processor. The processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 into the random access memory (RAM) 13. Various programs and data required for the operation of the electronic device 10 can also be stored in the RAM 13. The processor 11, ROM 12, and RAM 13 are connected to each other via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0140] Multiple components in the electronic device 10 are connected to the I / O interface 15, including an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a magnetic disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices via a computer network such as the Internet and / or various telecommunication networks.

[0141] The processor 11 can be any general-purpose and / or specialized processing component with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various specialized artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any other suitable processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as a VHSD parameter prediction method.

[0142] In some embodiments, a VHSD parameter prediction method can be implemented as a computer program tangibly embodied in a computer-readable storage medium, such as the storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the VHSD parameter prediction method described above can be performed. Alternatively, in other embodiments, the processor 11 can be configured to perform a VHSD parameter prediction method in any other suitable manner (e.g., via firmware).

[0143] Various embodiments of the systems and techniques described herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), system-on-chip systems (SOCs), programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments can include being implemented in one or more computer programs that are executable and / or interpreted on a programmable system that includes at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0144] Computer programs for implementing the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, such that when the computer program is executed by the processor, the functions / operations specified in the flowcharts and / or block diagrams are implemented. The computer program may be executed entirely on the machine, partially on the machine, as a stand-alone software package, partially on the machine and partially on a remote machine, or entirely on a remote machine or server.

[0145] In the context of the present invention, computer-readable storage media can be tangible media that can contain or store a computer program for use with an instruction execution system, device or equipment or used in combination with an instruction execution system, device or equipment. Computer-readable storage media can include but are not limited to electronic, magnetic, optical, electromagnetic, infrared or semiconductor systems, devices or equipment, or any suitable combination of the foregoing. Alternatively, computer-readable storage media can be machine-readable signal media. More specific examples of machine-readable storage media can include electrical connections based on one or more lines, portable computer disks, hard disks, random access memories (RAM), read-only memories (ROM), erasable programmable read-only memories (EPROM or flash memory), optical fibers, portable compact disk read-only memories (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination of the foregoing.

[0146] To provide interaction with a user, the systems and techniques described herein can be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, the feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including acoustic input, voice input, or tactile input).

[0147] The systems and techniques described herein can be implemented in a computing system that includes back-end components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes front-end components (e.g., a user computer with a graphical user interface or web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such back-end components, middleware components, or front-end components. The components of the system can be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0148] A computing system may include clients and servers. The clients and servers are typically remote from each other and typically interact via a communication network. This client-server relationship arises through computer programs running on the respective computers, creating a client-server relationship. The server may be a cloud server, also known as a cloud computing server or cloud host. This server is a hosting product within the cloud computing service ecosystem that addresses the management difficulties and limited scalability of traditional physical hosting and VPS services.

[0149] It should be understood that the various forms of the processes shown above can be used to reorder, add, or delete steps. For example, the steps described in the present invention can be performed in parallel, sequentially, or in a different order, as long as the desired results of the technical solution of the present invention can be achieved. This is not limited herein.

[0150] The above specific embodiments do not limit the scope of protection of the present invention. Those skilled in the art will appreciate that various modifications, combinations, sub-combinations, and substitutions may be made based on design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of the present invention are intended to be included within the scope of protection of the present invention.

Claims

1. VHSD steam chamber and production parameter prediction method, characterized in that: include: Acquire data on the target block; wherein the data consists of reservoir geological data and reservoir development and production dynamic data; Based on the data, determine the production height of the horizontal well and the horizontal distance between the initial injection-production connection point and the production well; Calculate the initial time of the stable gravity drainage stage using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, and horizontal well length rock thermal conductivity coefficient in the data; Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and other data, the VHSD steam chamber and production parameters were predicted to obtain the steam chamber front expansion velocity, the horizontal expansion distance of the steam chamber, and the total drainage production.

2. The method according to claim 1, characterized in that Based on the data, determine the production height of the horizontal well and the horizontal distance between the initial injection-production connection point and the production well, including: Calculate the producing height of the oil layer during horizontal well huff and puff based on the cumulative oil production, porosity, initial oil saturation and residual oil saturation of the horizontal well in the data; The horizontal distance between the initial injection-production connection position and the production well is calculated based on the oil layer production height of the horizontal well and the oil layer thickness and the vertical-horizontal well spacing in the data.

3. The method according to claim 1, characterized in that The initial time of the stable gravity drainage stage is calculated using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, and horizontal well length rock thermal conductivity coefficient in the data, including: The initial time of the stable gravity drainage stage is calculated according to a predetermined formula for calculating the initial time of the stable gravity drainage stage by combining the horizontal distance between the initial injection-production connection point and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data.

4. The method according to claim 1, wherein Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and other data, the VHSD steam chamber and production parameters are predicted to obtain the steam chamber front expansion speed, including: The following formula is used to calculate the expansion velocity of the steam chamber front edge; Among them, U x represents the expansion velocity of the steam chamber front, k represents the permeability, and k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. W represents the horizontal distance between the initial injection-production connection position and the production well, t0 represents the initial time of the stable gravity drainage stage, and L represents the distance between the straight and horizontal wells.

5. The method according to claim 1, wherein The horizontal expansion distance of the steam chamber includes the horizontal expansion distance of the steam chamber in the area near the horizontal well and the horizontal expansion distance of the steam chamber in the area near the vertical well steam injection well; Accordingly, based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and the data, the VHSD steam chamber and production parameters are predicted to obtain the horizontal expansion distance of the steam chamber, including: The horizontal expansion distance of the steam chamber near the horizontal well area is calculated using the following formula: Where, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. W represents the horizontal distance between the initial position of injection and production connection and the production well. t0 represents the initial time of the stable gravity drainage stage. L represents the distance between the straight and horizontal wells. 0≤x≤W, The horizontal expansion distance of the steam chamber in the near-vertical steam injection well area is calculated using the following formula: Where, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the rock thermal conductivity coefficient of the horizontal well length, m represents the viscosity-temperature coefficient of crude oil, and v s It represents the kinematic viscosity of crude oil at saturated steam temperature. represents porosity, ΔS o Indicates, H represents the oil layer thickness, λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage, L represents the vertical well spacing, W represents the horizontal distance between the initial injection-production connection position and the production well, and W <x≤L, 6. The method according to claim 1, characterized in that Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and other data, the VHSD steam chamber and production parameters are predicted to obtain the total drainage production, including: Based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection point and the production well, and the data, the VHSD parameters are predicted to obtain the oil leakage rate near the production well area and the oil leakage rate near the injection well area during the lateral expansion stage of the steam chamber; The total oil leakage production is obtained by adding the oil leakage in the area near the production well and the oil leakage in the area near the steam injection well during the lateral expansion stage of the steam chamber.

7. The method according to claim 6, characterized in that include: The following formula is used to calculate the oil leakage rate in the area near the production well during the lateral expansion stage of the steam chamber: Among them, q p represents the oil leakage rate near the production well during the lateral expansion stage of the steam chamber, k represents the permeability, and k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the thermal conductivity of the rock along the horizontal well length, represents porosity, ΔS o Indicates, H represents the oil layer thickness, m represents the viscosity-temperature coefficient of crude oil, v s represents the kinematic viscosity of crude oil at saturated steam temperature, W represents the horizontal distance from the initial injection-production connection position to the production well, and λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage. The following formula is used to calculate the oil leakage rate in the area near the steam injection well; Among them, q i represents the oil leakage rate in the area near the steam injection well, k represents the permeability, k ro represents the relative permeability of the oil phase, g represents the acceleration of gravity, α represents the thermal conductivity of the rock along the horizontal well length, represents porosity, ΔS o Indicates, H represents the oil layer thickness, m represents the viscosity-temperature coefficient of crude oil, v s represents the kinematic viscosity of crude oil at saturated steam temperature, L represents the vertical well distance, W represents the horizontal distance from the initial injection-production connection position to the production well, and λ i is the shape coefficient, which is determined by the angle between the streamline on the inclined drainage interface and the horizontal well, and is between 0 and 1. t0 represents the initial time of the stable gravity drainage stage. The total oil leakage production is calculated using the following formula: q=q p +q i ; Where q represents the total oil leakage production.

8. VHSD steam chamber and production parameter prediction device, characterized in that: include: A data acquisition module is used to acquire data of the target block; wherein the data is composed of reservoir geological data and reservoir development and production dynamic data; A height and distance calculation module is used to determine the production height of the horizontal well and the horizontal distance between the initial injection-production connection position and the production well based on the data; a module for calculating the initial time of the stable gravity drainage phase, for calculating the initial time of the stable gravity drainage phase using the horizontal distance between the initial injection-production connection position and the production well and the crude oil viscosity-temperature coefficient, crude oil kinematic viscosity at saturated steam temperature, porosity, movable oil saturation, oil layer thickness, permeability, oil phase relative permeability, horizontal well length, and rock thermal conductivity coefficient in the data; The VHSD parameter prediction module is used to predict the VHSD steam chamber and production parameters based on the initial time of the stable gravity drainage stage, the horizontal distance between the initial injection-production connection position and the production well, and other data, to obtain the steam chamber front expansion speed, the horizontal expansion distance of the steam chamber, and the total drainage production.

9. An electronic device, characterized in that: The electronic device comprises: at least one processor; and a memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute the VHSD steam chamber and production parameter prediction method according to any one of claims 1 to 7.

10. A computer-readable medium, characterized in that The computer-readable medium stores computer instructions, and the computer instructions are used to enable a processor to implement the VHSD steam chamber and production parameter prediction method according to any one of claims 1 to 7 when executed.

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