Gas storage-based injection and production well test analysis method, device and equipment and medium

Abstract

The embodiment of the invention discloses an injection and production well test analysis method, device and equipment based on a gas storage and a medium. The method comprises the steps that the historical flow period and the analysis flow period of a target injection and production well are determined according to the life cycle of a target gas storage; target parameter information of the target injection and production well is determined, and a first seepage model of a historical flow period and a second seepage model of an analysis flow period are determined according to the target parameter information; solving the first percolation model to obtain historical formation pressure distribution at the end moment of the historical flow period, and solving the second percolation model based on the historical formation pressure distribution to obtain target bottom hole pressure at each moment in the analysis flow period; and determining a reference model plate of the analysis flow period according to the target bottom hole pressure, and determining target stratum parameters of the analysis flow period based on the reference model plate and the actually measured bottom hole pressure change of the analysis flow period. According to the technical scheme, the problem that reservoir parameters cannot be fitted under the special working condition of alternating injection and production of the gas storage can be effectively solved.

Description

Technical Field

[0001] The present invention relates to the technical field of gas storage operation, and in particular to a well testing analysis method, device, equipment and medium for injection and production wells based on a gas storage. Background Art

[0002] The operation of gas storage facilities differs significantly from conventional gas reservoirs, primarily characterized by variable flow rates, intense injection and production cycles, and a short equilibrium period. Due to significant interference from neighboring wells and peak-shaving requirements, achieving extended shut-in testing of all wells during the equilibrium period is challenging. Furthermore, due to the short equilibrium period, it is difficult for the gas storage reservoir to reach a stable pressure before the next round of injection (or production) begins, resulting in a complex pressure distribution within the reservoir. Therefore, relying solely on production data from a few monitoring wells within the reservoir makes it difficult to accurately assess the pressure dynamics of the entire reservoir. Therefore, it is necessary to refine the research focus to all production wells and conduct analysis on a single-well basis.

[0003] The emergence of production data analysis technology has provided a means for analyzing the storage and permeability characteristics of oil and gas wells. Production data analysis methods primarily include Arps, Fetkovich, Blasingame, and NPI. The Arps and Fetkovich methods require constant bottomhole flow pressure and, therefore, cannot be applied to gas storage facilities. The Blasingame and NPI methods can handle production with variable bottomhole flow and pressure, and are suitable for a single production period. However, they cannot be directly applied to alternating injection and production operations. Due to the high production rate and rapid flow pattern changes, when formation pressure varies within an acceptable range, reservoir parameters may be difficult to fit and interpret. Summary of the Invention

[0004] The present invention provides a well test analysis method, device, equipment and medium for injection and production wells based on a gas storage reservoir. A model chart is constructed based on the multi-cycle injection and production history of the gas storage reservoir. It can effectively solve the problem that reservoir parameters cannot be fitted and interpreted due to large fluctuations and uneven distribution of initial formation pressure under the special working conditions of alternating injection and production of the gas storage reservoir.

[0005] According to one aspect of the present invention, a well testing analysis method for injection and production wells based on a gas storage reservoir is provided, the method comprising:

[0006] Determine the historical flow period and analysis flow period of the target injection and production well based on the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well closure and storage construction period, and at least two injection and production cycles, the analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closure and storage construction period to the start moment of the analysis flow period;

[0007] Determining target parameter information of the target injection-production well, and determining a first seepage model for the historical flow period and a second seepage model for the analysis flow period based on the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type, and boundary shape;

[0008] Solving the first seepage model to obtain a historical formation pressure distribution at the end of the historical flow period, and solving the second seepage model based on the historical formation pressure distribution to obtain a target bottom hole pressure at each moment in the analysis flow period;

[0009] A reference model plate for the analysis flow period is determined based on the target bottom hole pressure, and target formation parameters for the analysis flow period are determined based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period; wherein the reference model plate is used to characterize the change characteristics of the target bottom hole pressure over time.

[0010] According to another aspect of the present invention, a well testing and analysis device for injection and production wells based on a gas storage reservoir is provided, comprising:

[0011] A flow period division module is used to determine the historical flow period and analysis flow period of the target injection and production well according to the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well closure and storage construction period, and at least two injection and production cycles, the analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closure and storage construction period to the start moment of the analysis flow period;

[0012] a seepage model determination module, configured to determine target parameter information of the target injection-production well, and determine a first seepage model for the historical flow period and a second seepage model for the analysis flow period based on the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type, and boundary shape;

[0013] a target bottom hole pressure determination module, configured to solve the first seepage model to obtain a historical formation pressure distribution at the end of the historical flow period, and solve the second seepage model based on the historical formation pressure distribution to obtain a target bottom hole pressure at each moment in the analysis flow period;

[0014] A target formation parameter determination module is used to determine a reference model plate for the analysis flow period according to the target bottom hole pressure, and to determine the target formation parameters for the analysis flow period based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period; wherein the reference model plate is used to characterize the change characteristics of the target bottom hole pressure over time.

[0015] According to another aspect of the present invention, an electronic device is provided, comprising:

[0016] at least one processor; and

[0017] a memory communicatively connected to the at least one processor; wherein,

[0018] The memory stores a computer program that can be executed 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 injection and production well testing analysis method based on a gas storage reservoir as described in any embodiment of the present invention.

[0019] According to another aspect of the present invention, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the gas storage-based injection and production well testing analysis method according to any embodiment of the present invention when executed.

[0020] The technical solution of the embodiment of the present invention determines the historical flow period and analysis flow period of the target injection and production well according to the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well closing and reservoir construction period and at least two injection and production cycles, the analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closing and reservoir construction period to the start moment of the analysis flow period; determines the target parameter information of the target injection and production well, and determines a first seepage model for the historical flow period and a second seepage model for the analysis flow period according to the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type and boundary shape; solves the first seepage model to obtain the historical formation pressure distribution at the end moment of the historical flow period, and solves the second seepage model based on the historical formation pressure distribution to obtain the target bottomhole pressure at each moment in the analysis flow period; determines a reference model plate for the analysis flow period according to the target bottomhole pressure, and determines the target formation parameters for the analysis flow period based on the reference model plate and the measured bottomhole pressure changes during the analysis flow period; wherein the reference model plate is used to characterize the change characteristics of the target bottomhole pressure over time. This technical solution constructs a model chart based on the multi-cycle injection and production history of the gas storage reservoir, which can effectively solve the problem of reservoir parameters being unable to be fitted and interpreted due to large fluctuations and uneven distribution of initial formation pressure under the special conditions of alternating injection and production of the gas storage reservoir.

[0021] 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

[0022] 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.

[0023] Figure 1 This is a flow chart of a well testing analysis method for injection and production wells based on a gas storage reservoir according to the first embodiment of the present invention;

[0024] Figure 2 Schematic diagram of a vertical well homogeneous circular boundary grid model provided according to the first embodiment of the present invention;

[0025] Figure 3 Schematic diagram of a homogeneous rectangular boundary grid model for a horizontal well provided according to the first embodiment of the present invention;

[0026] Figure 4 3D grid diagram of a homogeneous rectangular boundary grid model for a horizontal well provided in Example 1 of the present invention;

[0027] Figure 5A According to the first embodiment of the present invention, Figure 4 Schematic diagram of the mesh subdivision of the XOY plane of the 3D grid;

[0028] Figure 5B According to the first embodiment of the present invention, Figure 4 Schematic diagram of the mesh generation of the ZOX plane of the 3D grid;

[0029] Figure 6 This is a flow chart of a well testing analysis method for injection and production wells based on a gas storage reservoir according to the second embodiment of the present invention;

[0030] Figure 7 1 is a schematic diagram of a historical flow rate curve of a target injection-production well with a vertical well and a homogeneous circular boundary according to the second embodiment of the present invention;

[0031] Figure 8A According to the second embodiment of the present invention, Figure 7 Reference model plate for the first gas production period;

[0032] Figure 8B According to the second embodiment of the present invention, Figure 7 Reference model plate for the first gas injection period;

[0033] Figure 8C According to the second embodiment of the present invention, Figure 7 Reference model plate for the second gas production period;

[0034] Figure 9 1 is a schematic diagram of a historical flow rate curve of a target injection-production well with a homogeneous rectangular boundary of a horizontal well provided in accordance with the second embodiment of the present invention;

[0035] Figure 10A According to the second embodiment of the present invention, Figure 9 Reference model plate for the first gas production period;

[0036] Figure 10B According to the second embodiment of the present invention, Figure 9 Reference model plate for the first gas injection period;

[0037] Figure 10C According to the second embodiment of the present invention, Figure 9 Reference model plate for the second gas production period;

[0038] Figure 11 This is a schematic diagram of selecting a flow period for analyzing measured data according to the second embodiment of the present invention;

[0039] Figure 12 This is a schematic diagram of the fitting effect of a reference model chart for analyzing the flow period of measured data provided by the second embodiment of the present invention;

[0040] Figure 13 2 is a schematic diagram of the historical pressure fitting effect of the full injection-production cycle of measured data provided by the second embodiment of the present invention;

[0041] Figure 14 2 is a schematic structural diagram of a well testing and analysis device for injection and production wells based on a gas storage reservoir according to a third embodiment of the present invention;

[0042] Figure 15 The present invention is a schematic structural diagram of an electronic device for implementing a well testing analysis method for injection and production wells based on a gas storage reservoir according to an embodiment of the present invention. DETAILED DESCRIPTION

[0043] 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.

[0044] It should be noted that the terms "first", "second", "target", etc. 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.

[0045] Example 1

[0046] Figure 1 This is a flow chart of a gas storage-based injection and production well test analysis method provided in Example 1 of the present invention. This embodiment is applicable to the case of performing well test analysis on injection and production wells taking into account the multi-cycle injection and production history of the gas storage. The method can be executed by a gas storage-based injection and production well test analysis device. The gas storage-based injection and production well test analysis device can be implemented in the form of hardware and / or software. The gas storage-based injection and production well test analysis device can be configured in an electronic device with data processing capabilities. Figure 1 As shown, the method includes:

[0047] S110 , determining a historical flow period and an analysis flow period of a target injection and production well according to the life cycle of the target gas storage.

[0048] Among them, the life cycle includes the gas reservoir depletion development period, the well closure and reservoir construction period and at least two injection and production cycles. The analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closure and reservoir construction period to the starting moment of the analysis flow period.

[0049] It should be noted that the entire lifecycle of a gas storage facility includes the depletion development period of the gas reservoir, the well closure and construction period, and multiple injection and production cycles of the gas storage facility. Considering that the well closure and construction period is long and pressure can return to a stable state, the analysis begins with the construction equilibrium period. Furthermore, a target injection and production cycle (injection or production period) is selected from the gas storage's operating injection and production cycle as the analysis flow period. All injection and production cycles from the construction equilibrium point to the start of the analysis flow period are considered the historical flow period (including multiple different injection and production cycles).

[0050] S120, determining target parameter information of the target injection-production well, and determining a first seepage model for the historical flow period and a second seepage model for the analytical flow period based on the target parameter information.

[0051] The target parameter information includes fluid type, well type, reservoir type and boundary shape. Optionally, the fluid type includes oil, water and gas-phase fluid; the well type includes vertical well, horizontal well and fractured well; the reservoir type includes homogeneous reservoir, dual-porosity medium reservoir and radial composite reservoir; the boundary shape includes circular and rectangular. The boundary is a closed boundary. Exemplarily, the gas-phase fluid can be natural gas or carbon dioxide. The first seepage model and the second seepage model can refer to the seepage models corresponding to the historical flow period and the analysis flow period, respectively. The first seepage model is the same as the conventional seepage model, and the second seepage model is established based on the normalized pressure analysis method.

[0052] It should be noted that the primary characteristic parameters of the first and second seepage models corresponding to different target parameter information differ. For example, the primary characteristic parameters for a dual-porosity reservoir are the storage-volume ratio and crossflow coefficient; the primary characteristic parameters for a radial composite reservoir are the mobility ratio and pressure conductivity ratio; and the primary characteristic parameter for a rectangular closed boundary is the distance from the well to the four boundaries. When the fluid type is gas, the concepts of pseudo-pressure and pseudo-time are required to convert the gas-phase equation into a liquid-phase equation for solution.

[0053] For example, taking the homogeneous circular boundary of a vertical well as an example, it is assumed that the following conditions are met: 1. The gas storage reservoir has an alternating injection and production condition, with a positive flow rate during production and a negative flow rate during injection; 2. The reservoir is horizontally equithick and isotropic, the gas flows in a single phase and satisfies Darcy's law; 3. The formation pressure distribution is uniform and constant before the well is shut in and the reservoir is built. After the reservoir is built, the formation pressure distribution is uneven and is closely related to the injection and production history; 4. Considering that the gas compressibility coefficient and viscosity change with pressure, the gas compressibility coefficient and deviation factor are calculated using the DPR method, and the gas viscosity is calculated using the Lee method; 5. The influence of gravity and capillary force is ignored, and the influence of other factors such as wellbore storage effect and temperature on the flow is not considered.

[0054] The first seepage model can be expressed as the following formulas (1)-(4):

[0055] (1) Control equation: (2) Initial conditions: p D (r D ,0)=0; (3) Internal boundary conditions: (4) External boundary conditions:

[0056] Among them, r D represents dimensionless distance, t D represents dimensionless time, q D Represents dimensionless output.

[0057] The second seepage model can be expressed as the following formulas (5)-(8):

[0058] (5) Control equation: in, (6) Initial conditions: p D (r D ,0)=f(r D ), where f(r D ) is the historical formation pressure distribution at the end of the historical flow period; (7) Internal boundary conditions: (8) External boundary conditions:

[0059] For example, taking the homogeneous rectangular boundary of a horizontal well as an example, assuming that the above conditions 1-5 are met, the second seepage model can be expressed as the following formulas (9)-(14):

[0060] (9) (10)p D (r D ,0)=0;

[0061] (11)

[0062] (12) (13) (14)

[0063] in, T0 and T1 represent the dimensionless start and end time of the analysis flow period, respectively. D 、y D and z D Represents the dimensionless distance in the x, y, and z directions, respectively. eD and y eD denote the dimensionless boundary distances in the x-direction and y-direction, respectively, t Dd represents dimensionless decreasing time, r wD represents the dimensionless bottom hole distance, L a represents the length of the horizontal well section, and h represents the effective thickness of the reservoir.

[0064] S130, solving the first seepage model to obtain the historical formation pressure distribution at the end of the historical flow period, and solving the second seepage model based on the historical formation pressure distribution to obtain the target bottom hole pressure at each moment in the analysis flow period.

[0065] In this embodiment, after determining a first seepage model for the historical flow period and a second seepage model for the analysis flow period based on the target parameter information, the first seepage model can be solved to obtain the historical formation pressure distribution at the end of the historical flow period. Optionally, solving the first seepage model to obtain the historical formation pressure distribution at the end of the historical flow period includes: determining a target gridding model based on the target parameter information, discretizing the first seepage model based on the target gridding model; solving the discretized first seepage model based on the formation pressure at the equilibrium moment during the well shut-in and reservoir construction period to obtain the formation pressure distribution at each moment in the historical flow period; and determining the formation pressure distribution at the end of the historical flow period as the historical formation pressure distribution.

[0066] For example, the meshing model may include a vertical well circular boundary mesh model (e.g. Figure 2 As shown), vertical well rectangular boundary grid model, horizontal well circular boundary grid model, horizontal well rectangular boundary grid model (as shown Figure 3 As shown) or multi-stage fracture horizontal well grid model, etc. Among them, the vertical well circular boundary grid model adopts a two-dimensional radial unequal-distance grid, the vertical well rectangular boundary grid model adopts a two-dimensional plane rectangular unequal-distance grid, the horizontal well circular boundary grid model adopts a three-dimensional irregular grid, and the horizontal well rectangular boundary grid model adopts a three-dimensional rectangular unequal-distance grid (as shown). Figure 4 As shown in Figure 2, the grid model for multi-stage fractured horizontal wells uses an irregular unstructured grid. Figure 4 The meshing results of the XOY plane and ZOX plane of the 3D grid are shown in Figure 5A and Figure 5B .

[0067] In this embodiment, firstly, based on the correspondence between the injection and production well parameter information and the grid division model, the target grid division model corresponding to the target parameter information is determined, and then the first seepage model is discretized based on the target grid division model.

[0068] For example, taking the above formulas (1)-(4) as an example, after discretizing the first seepage model, formula (15) can be obtained: Writing formula (15) in matrix form yields formula (16):

[0069] in,

[0070] Then, the first seepage model after discretization can be solved based on the formation pressure at the equilibrium time during the well-closing and reservoir-building period to obtain the formation pressure distribution at each time during the historical flow period, and the formation pressure distribution at the end of the historical flow period can be determined as the historical formation pressure distribution. Among them, the formation pressure at the equilibrium time during the well-closing and reservoir-building period is dimensionless and is 0 on the left side of the equal sign in formula (2).

[0071] In this embodiment, after obtaining the historical formation pressure distribution at the end of the historical flow period, the second seepage model can be solved based on the historical formation pressure distribution to obtain the target bottomhole pressure at each time point in the analysis flow period. Optionally, solving the second seepage model based on the historical formation pressure distribution to obtain the target bottomhole pressure at each time point in the analysis flow period includes: discretizing the second seepage model based on the target grid subdivision model; and solving the discretized second seepage model based on the historical formation pressure distribution to obtain the target bottomhole pressure at each time point in the analysis flow period.

[0072] For example, taking the above formulas (5)-(8) as an example, after discretizing the second percolation model, formula (17) can be obtained: Writing formula (17) in matrix form yields formula (18): Cp D k+1 =D.

[0073] in,

[0074] For example, taking the above formulas (9)-(14) as an example, after discretizing the second percolation model, the following formulas (19)-(29) can be obtained:

[0075] Formula (19):

[0076]

[0077] Formula (20):

[0078]

[0079] Formula (21): p D (x Di ,y Dj ,z Dk ,t Dd1 )=0, i=1,2,3,...,I; j=1,2,3,...,J; k=1,2,3,...,K;

[0080] Formula (22):

[0081]

[0082] Formula (23): Formula (24): Formula (25): Formula (26):

[0083] Formula (27):

[0084] Formula (28):

[0085] Formula (29):

[0086] Then the historical formation pressure distribution f(r D ) is used as the initial formation pressure distribution during the flow period. Substituting this into the initial conditions of formula (6) solves the discretized second seepage model and obtains the target bottomhole pressure at each moment during the flow period. Since the coefficient matrices of formulas (19)-(29) are large and sparse, they can be solved using a numerical iteration method.

[0087] S140 , determining a reference model plate for the analysis flow period according to the target bottom hole pressure, and determining target formation parameters for the analysis flow period based on the reference model plate and the measured bottom hole pressure change during the analysis flow period.

[0088] The reference model chart is used to characterize the temporal variation of the target bottomhole pressure. The measured bottomhole pressure variation can refer to the temporal variation of the bottomhole pressure of the target injection and production well, as determined through actual measurements. For example, using a vertical well with a homogeneous circular boundary as an example, target formation parameters may include permeability, skin factor, well control radius, and well controlled reserves.

[0089] It should be noted that the reference model chart constructed for analyzing the flow period is related to historical production data and is therefore not typically representative in the conventional sense, but rather atypical. This solution considers the non-uniform initial formation pressure distribution during the flow period, specifically the influence of historical flow rates, and establishes a normalized pressure analysis chart for production data analysis and fitting. By incorporating material balance time, this solution can handle the problem of varying flow pressures with varying production rates.

[0090] In this embodiment, after obtaining the target bottom hole pressure at each time point during the analysis flow period, a reference model chart for the analysis flow period can be determined based on the target bottom hole pressure. For example, a time-varying curve of the target bottom hole pressure can be plotted based on the target bottom hole pressure at each time point during the analysis flow period, and this curve can be determined as the reference model chart for the analysis flow period.

[0091] After determining the reference model plate for the flow analysis period, the target formation parameters for the flow analysis period can be determined based on the reference model plate and the measured bottomhole pressure changes during the flow analysis period. Specifically, a corresponding measured bottomhole pressure change curve is first drawn based on the measured bottomhole pressure changes during the flow analysis period. The measured bottomhole pressure change curve is then fitted to the reference model plate, and an appropriate dimensionless radius is selected to achieve the best fit. The target formation parameters for the flow analysis period can then be determined based on the fitting results. The fitting process can combine automatic matching using a nonlinear regression algorithm and manual matching using drag-and-drop fitting.

[0092] The technical solution of the embodiment of the present invention determines the historical flow period and analysis flow period of the target injection and production well according to the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well closing and reservoir construction period and at least two injection and production cycles, the analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closing and reservoir construction period to the start moment of the analysis flow period; determines the target parameter information of the target injection and production well, and determines a first seepage model for the historical flow period and a second seepage model for the analysis flow period according to the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type and boundary shape; solves the first seepage model to obtain the historical formation pressure distribution at the end moment of the historical flow period, and solves the second seepage model based on the historical formation pressure distribution to obtain the target bottomhole pressure at each moment in the analysis flow period; determines a reference model plate for the analysis flow period according to the target bottomhole pressure, and determines the target formation parameters for the analysis flow period based on the reference model plate and the measured bottomhole pressure changes during the analysis flow period; wherein the reference model plate is used to characterize the change characteristics of the target bottomhole pressure over time. This technical solution constructs a model chart based on the multi-cycle injection and production history of the gas storage reservoir, which can effectively solve the problem of reservoir parameters being unable to be fitted and interpreted due to large fluctuations and uneven distribution of initial formation pressure under the special conditions of alternating injection and production of the gas storage reservoir.

[0093] Example 2

[0094] Figure 6 The flowchart of a well test analysis method for injection and production wells based on a gas storage reservoir is provided in the second embodiment of the present invention. This embodiment is optimized based on the above embodiment. The specific optimization is as follows: determining the reference model plate for the analysis flow period according to the target bottom hole pressure, including: determining the reference pressure curve for the analysis flow period according to the change of the target bottom hole pressure over time; integrating the reference pressure curve to obtain the reference pressure integral curve for the analysis flow period; derivatizing the reference pressure integral curve to obtain the reference pressure integral derivative curve for the analysis flow period; determining the reference model plate for the analysis flow period according to the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve.

[0095] like Figure 6 As shown, the method of this embodiment specifically includes the following steps:

[0096] S210: Determine a historical flow period and an analysis flow period of a target injection and production well according to the life cycle of the target gas storage.

[0097] Among them, the life cycle includes the gas reservoir depletion development period, the well closure and reservoir construction period and at least two injection and production cycles. The analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closure and reservoir construction period to the starting moment of the analysis flow period.

[0098] S220, determining target parameter information of the target injection-production well, and determining a first seepage model for the historical flow period and a second seepage model for the analytical flow period based on the target parameter information.

[0099] The target parameter information includes fluid type, well type, reservoir type and boundary shape.

[0100] S230 , solving the first seepage model to obtain the historical formation pressure distribution at the end of the historical flow period, and solving the second seepage model based on the historical formation pressure distribution to obtain the target bottom hole pressure at each moment in the analysis flow period.

[0101] The specific implementation of S210-S230 can be found in the detailed description of S110-S130, which will not be repeated here.

[0102] S240 , determining a reference pressure curve for analyzing the flow period according to the change of the target bottom hole pressure over time.

[0103] In this embodiment, a curve of target bottom hole pressure variation over time can be drawn based on the target bottom hole pressure at each moment in the analysis flow period, and the curve can be used as a reference pressure curve for the analysis flow period. For example, the reference pressure curve can be expressed as Among them, t DA represents dimensionless time, r eD Represents the dimensionless well control radius.

[0104] S250 , performing integration processing on the reference pressure curve to obtain a reference pressure integral curve for the analysis flow period.

[0105] In this embodiment, after obtaining the reference pressure curve of the analysis flow period, the reference pressure integral curve of the analysis flow period can be obtained by integrating the reference pressure curve. For example, the reference pressure integral curve can be expressed as In this scheme, based on the integral processing, a relatively reliable model plate that is not affected by data dispersion can be established.

[0106] S260 , performing derivative processing on the reference pressure integral curve to obtain a reference pressure integral derivative curve for the analysis flow period.

[0107] In this embodiment, after obtaining the reference pressure integral curve of the analysis flow period, the reference pressure integral derivative curve of the analysis flow period can be obtained by performing a derivative process on the reference pressure integral curve. For example, the reference pressure integral derivative curve can be expressed as

[0108] S270 , determining a reference model plate for analyzing the flow period according to the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve.

[0109] In this embodiment, after obtaining the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve, the three sets of curves can be superimposed together to obtain a reference model plate for analyzing the flow period.

[0110] Figure 7 This is a schematic diagram of a historical flow rate curve of a target injection-production well with a vertical well and homogeneous circular boundary provided in Example 2 of the present invention. Figures 8A-8C They are Figure 7 Reference model plates for the first gas production period, the first gas injection period and the second gas production period. Figure 9 A schematic diagram of a historical flow rate curve of a target injection-production well with a homogeneous rectangular boundary of a horizontal well provided in the second embodiment of the present invention. Figures 10A-10C They are Figure 9 Reference model diagrams for the first gas production period, the first gas injection period, and the second gas production period. wD represents the dimensionless eccentricity, and db represents the ratio of the distances between the four boundaries of the horizontal well (dimensionless).

[0111] S280: Determine target formation parameters during the analysis flow period based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period.

[0112] In this embodiment, optionally, the target formation parameters of the analysis flow period are determined based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period, including: determining the measured curve of the analysis flow period based on the measured bottom hole pressure changes during the analysis flow period; wherein the measured curve includes the measured pressure curve, the measured pressure integral curve and the measured pressure integral derivative curve; fitting and matching the measured curve with the reference model plate, and determining the target formation parameters of the analysis flow period according to the fitting and matching results.

[0113] In this embodiment, the measured pressure curve for the analysis flow period can be first determined based on the measured bottomhole pressure changes during the analysis flow period. The measured pressure curve is then integrated to obtain a measured pressure integral curve. The measured pressure integral curve is then differentiated to obtain a measured pressure integral derivative curve, thereby determining the measured curve for the analysis flow period. The three sets of measured curves are then fitted and matched with the three sets of reference curves in the reference model plate. The set with the best fitting effect is determined as the target fitting curve set. Finally, the target formation parameters for the analysis flow period are determined based on the fitting results of the target fitting curve set.

[0114] For example, the target injection and production well with a vertical homogeneous circular closed boundary is used as an example to verify this scheme. The target injection and production well is well X1, whose reservoir depth is 3553.8m, tubing radius is 0.0762m, porosity is 15.5%, effective reservoir thickness is 35m, wellhead temperature is 47.89℃, formation temperature is 84.78℃, and initial formation pressure is 24MPa. For well X1, the last production period is selected as the analysis flow period for analysis (e.g. Figure 11 The reference model plate and the measured bottom hole pressure change data can be drawn. The best fitting effect can be achieved by dragging the measured bottom hole pressure change data and the reference model plate and selecting an appropriate dimensionless radius (as shown in Figure 12 At the same time, the historical pressure fitting of the whole injection-production cycle of the well can be performed (as shown in Figure 13 As shown in Figure 2, a good fitting effect is also required, and the final fitting result can be obtained on this basis. Based on the good plate fitting effect and the good historical pressure fitting effect, it can be explained that the permeability of Well X1 is 7.31mD, the skin factor is 2.53, the well control radius is 351m, and the well controlled reserves are 4.51×10 8 m 3 .

[0115] The technical solution of the embodiment of the present invention determines the reference pressure curve for the analysis flow period according to the change of the target bottom hole pressure over time; integrates the reference pressure curve to obtain the reference pressure integral curve for the analysis flow period; derives the reference pressure integral curve to obtain the reference pressure integral derivative curve for the analysis flow period; and determines the reference model plate for the analysis flow period according to the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve. This technical solution constructs a model plate based on the multi-cycle injection and production history of the gas storage reservoir, which can effectively solve the problem that the reservoir parameters cannot be fitted and interpreted due to the large fluctuation and uneven distribution of the initial formation pressure under the special working conditions of the alternating injection and production of the gas storage reservoir. It can also construct a reference model plate for the analysis flow period based on the pressure curve, the pressure integral curve, and the pressure integral derivative curve, thereby improving the reliability and stability of the reference model plate and helping to better solve the problem that the reservoir parameters cannot be fitted and interpreted.

[0116] Example 3

[0117] Figure 14 This is a schematic diagram of the structure of a gas storage-based injection and production well test analysis device provided in the third embodiment of the present invention. The device can execute the gas storage-based injection and production well test analysis method provided in any embodiment of the present invention, and has the corresponding functional modules and beneficial effects of the execution method. Figure 14 As shown, the device includes:

[0118] The flow period division module 310 is configured to determine the historical flow period and analysis flow period of the target injection and production well based on the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well shut-in period, and at least two injection and production cycles; the analysis flow period is the target injection and production cycle; and the historical flow period is the life cycle from the equilibrium moment of the well shut-in period to the start moment of the analysis flow period.

[0119] A seepage model determination module 320 is configured to determine target parameter information of the target injection-production well, and determine a first seepage model for the historical flow period and a second seepage model for the analysis flow period based on the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type, and boundary shape;

[0120] a target bottom hole pressure determination module 330 for solving the first seepage model to obtain a historical formation pressure distribution at the end of the historical flow period, and solving the second seepage model based on the historical formation pressure distribution to obtain a target bottom hole pressure at each moment in the analyzed flow period;

[0121] The target formation parameter determination module 340 is used to determine the reference model plate of the analysis flow period according to the target bottom hole pressure, and to determine the target formation parameters of the analysis flow period based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period; wherein, the reference model plate is used to characterize the change characteristics of the target bottom hole pressure over time.

[0122] Optionally, the target bottom hole pressure determination module 330 is configured to:

[0123] determining a target grid division model according to the target parameter information, and discretizing the first seepage model based on the target grid division model;

[0124] Solving the first seepage model after discretization based on the formation pressure at the equilibrium moment during the well shut-in period to obtain the formation pressure distribution at each moment during the historical flow period;

[0125] The formation pressure distribution at the end of the historical flow period is determined as the historical formation pressure distribution.

[0126] Optionally, the target bottom hole pressure determination module 330 is further configured to:

[0127] Discretize the second seepage model based on the target grid division model;

[0128] The second seepage model after discretization is solved based on the historical formation pressure distribution to obtain the target bottom hole pressure at each moment in the analyzed flow period.

[0129] Optionally, the target formation parameter determination module 340 is configured to:

[0130] determining a reference pressure curve for the flow analysis period according to a change in the target bottom hole pressure over time;

[0131] performing integration processing on the reference pressure curve to obtain a reference pressure integral curve of the analysis flow period;

[0132] performing a derivative process on the reference pressure integral curve to obtain a reference pressure integral derivative curve of the analysis flow period;

[0133] A reference model plate for the analysis flow period is determined according to the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve.

[0134] Optionally, the target formation parameter determination module 340 is further configured to:

[0135] Determining a measured curve for the analysis flow period based on the measured bottom hole pressure change during the analysis flow period; wherein the measured curve includes a measured pressure curve, a measured pressure integral curve, and a measured pressure integral derivative curve;

[0136] The measured curve is fitted and matched with the reference model plate, and the target formation parameters of the analysis flow period are determined according to the fitting and matching results.

[0137] Optionally, the fluid types include oil, water and gas-phase fluids; the well types include vertical wells, horizontal wells and fracturing wells; the reservoir types include homogeneous reservoirs, dual-porosity medium reservoirs and radial composite reservoirs; and the boundary shapes include circular and rectangular.

[0138] A gas storage-based injection and production well testing analysis device provided in an embodiment of the present invention can execute a gas storage-based injection and production well testing analysis method provided in any embodiment of the present invention, and has corresponding functional modules and beneficial effects of the execution method.

[0139] Example 4

[0140] Figure 15 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.

[0141] like Figure 15 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.

[0142] 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.

[0143] 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 the well test analysis method for injection and production wells based on a gas storage reservoir.

[0144] In some embodiments, the gas storage-based injection and production well testing analysis method can be implemented as a computer program, which is tangibly contained 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 gas storage-based injection and production well testing analysis method described above can be performed. Alternatively, in other embodiments, the processor 11 can be configured to execute the gas storage-based injection and production well testing analysis method by any other appropriate means (e.g., by means of firmware).

[0145] 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), systems on chips (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.

[0146] 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.

[0147] 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.

[0148] 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).

[0149] 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.

[0150] 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.

[0151] 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.

[0152] 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. A well testing analysis method for injection and production wells based on a gas storage reservoir, characterized in that: The method comprises: Determine the historical flow period and analysis flow period of the target injection and production well based on the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well closure and storage construction period, and at least two injection and production cycles, the analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closure and storage construction period to the start moment of the analysis flow period; Determining target parameter information of the target injection-production well, and determining a first seepage model for the historical flow period and a second seepage model for the analysis flow period based on the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type, and boundary shape; Solving the first seepage model to obtain a historical formation pressure distribution at the end of the historical flow period, and solving the second seepage model based on the historical formation pressure distribution to obtain a target bottom hole pressure at each moment in the analysis flow period; A reference model plate for the analysis flow period is determined based on the target bottom hole pressure, and target formation parameters for the analysis flow period are determined based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period; wherein the reference model plate is used to characterize the change characteristics of the target bottom hole pressure over time.

2. The method according to claim 1, characterized in that Solving the first seepage model to obtain the historical formation pressure distribution at the end of the historical flow period includes: determining a target grid division model according to the target parameter information, and discretizing the first seepage model based on the target grid division model; Solving the first seepage model after discretization based on the formation pressure at the equilibrium moment during the well shut-in period to obtain the formation pressure distribution at each moment during the historical flow period; The formation pressure distribution at the end of the historical flow period is determined as the historical formation pressure distribution.

3. The method according to claim 2, characterized in that Solving the second seepage model based on the historical formation pressure distribution to obtain target bottom hole pressures at each moment in the analyzed flow period includes: Discretize the second seepage model based on the target grid division model; The second seepage model after discretization is solved based on the historical formation pressure distribution to obtain the target bottom hole pressure at each moment in the analyzed flow period.

4. The method according to any one of claims 1 to 3, characterized in that: Determining a reference model plate for analyzing the flow period according to the target bottom hole pressure includes: determining a reference pressure curve for the flow analysis period according to a change in the target bottom hole pressure over time; performing integration processing on the reference pressure curve to obtain a reference pressure integral curve of the analysis flow period; performing a derivative process on the reference pressure integral curve to obtain a reference pressure integral derivative curve of the analysis flow period; A reference model plate for the analysis flow period is determined according to the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve.

5. The method according to claim 4, characterized in that Determining target formation parameters during the analysis flow period based on the reference model plate and the measured bottom hole pressure change during the analysis flow period includes: Determining a measured curve for the analysis flow period based on the measured bottom hole pressure change during the analysis flow period; wherein the measured curve includes a measured pressure curve, a measured pressure integral curve, and a measured pressure integral derivative curve; The measured curve is fitted and matched with the reference model plate, and the target formation parameters of the analysis flow period are determined according to the fitting and matching results.

6. The method according to claim 1, characterized in that The fluid types include oil, water and gas-phase fluids; the well types include vertical wells, horizontal wells and fractured wells; the reservoir types include homogeneous reservoirs, dual-porosity medium reservoirs and radial composite reservoirs; and the boundary shapes include circular and rectangular.

7. A well testing and analysis device for injection and production wells based on a gas storage reservoir, characterized in that: The device comprises: A flow period division module is used to determine the historical flow period and analysis flow period of the target injection and production well according to the life cycle of the target gas storage reservoir; wherein the life cycle includes the gas reservoir depletion development period, the well closure and storage construction period, and at least two injection and production cycles, the analysis flow period is the target injection and production cycle, and the historical flow period is the life cycle from the equilibrium moment of the well closure and storage construction period to the start moment of the analysis flow period; a seepage model determination module, configured to determine target parameter information of the target injection-production well, and determine a first seepage model for the historical flow period and a second seepage model for the analysis flow period based on the target parameter information; wherein the target parameter information includes fluid type, well type, reservoir type, and boundary shape; a target bottom hole pressure determination module, configured to solve the first seepage model to obtain a historical formation pressure distribution at the end of the historical flow period, and solve the second seepage model based on the historical formation pressure distribution to obtain a target bottom hole pressure at each moment in the analysis flow period; A target formation parameter determination module is used to determine a reference model plate for the analysis flow period according to the target bottom hole pressure, and to determine the target formation parameters for the analysis flow period based on the reference model plate and the measured bottom hole pressure changes during the analysis flow period; wherein the reference model plate is used to characterize the change characteristics of the target bottom hole pressure over time.

8. The device according to claim 7, characterized in that The target bottom hole pressure determination module is used to: determining a target grid division model according to the target parameter information, and discretizing the first seepage model based on the target grid division model; Solving the first seepage model after discretization based on the formation pressure at the equilibrium moment during the well shut-in period to obtain the formation pressure distribution at each moment during the historical flow period; The formation pressure distribution at the end of the historical flow period is determined as the historical formation pressure distribution.

9. The device according to claim 8, characterized in that The target bottom hole pressure determination module is further configured to: Discretize the second seepage model based on the target grid division model; The second seepage model after discretization is solved based on the historical formation pressure distribution to obtain the target bottom hole pressure at each moment in the analyzed flow period.

10. The device according to any one of claims 7 to 9, characterized in that: The target formation parameter determination module is used to: determining a reference pressure curve for the flow analysis period according to a change in the target bottom hole pressure over time; performing integration processing on the reference pressure curve to obtain a reference pressure integral curve of the analysis flow period; performing a derivative process on the reference pressure integral curve to obtain a reference pressure integral derivative curve of the analysis flow period; A reference model plate for the analysis flow period is determined according to the reference pressure curve, the reference pressure integral curve, and the reference pressure integral derivative curve.

11. The device according to claim 10, characterized in that The target formation parameter determination module is further configured to: Determining a measured curve for the analysis flow period based on the measured bottom hole pressure change during the analysis flow period; wherein the measured curve includes a measured pressure curve, a measured pressure integral curve, and a measured pressure integral derivative curve; The measured curve is fitted and matched with the reference model plate, and the target formation parameters of the analysis flow period are determined according to the fitting and matching results.

12. The device according to claim 7, characterized in that The fluid types include oil, water and gas-phase fluids; the well types include vertical wells, horizontal wells and fractured wells; the reservoir types include homogeneous reservoirs, dual-porosity medium reservoirs and radial composite reservoirs; and the boundary shapes include circular and rectangular.

13. 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 that can be executed by the at least one processor, and the computer program is executed by the at least one processor to enable the at least one processor to execute the gas storage-based injection and production well testing analysis method according to any one of claims 1 to 6.

14. A computer-readable storage medium, characterized in that The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the gas storage-based injection and production well testing analysis method according to any one of claims 1 to 6 when executed.

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