Gas field gathering pipeline network working condition adjusting method and device for coupling reciprocating compressor characteristics

Abstract

The present application relates to the field of oil and gas field development engineering, and particularly relates to a gas field gathering pipeline network working condition adjusting method and device coupled with reciprocating compressor characteristics. The method comprises the following steps: adding auxiliary nodes and auxiliary pipelines in the gas field gathering pipeline network according to the structure of the gas field gathering pipeline network, and generating a pipe section node correlation matrix of the pipeline network; performing hydraulic and thermal coupling iteration according to the pipeline network basic parameters, the set pipeline flow initial value, the set node temperature initial value, the natural gas physical property parameters and the set compressor rotating speed, until the pipeline flow and the node temperature converge; and judging whether the converged pipeline flow and node temperature meet the requirements, if not, adjusting the set compressor rotating speed to perform coupling iteration again until the obtained pipeline flow and node temperature meet the requirements, and using the current set compressor rotating speed to guide the gas reservoir exploitation of the actual formation.

Description

Technical Field

[0001] This article relates to the field of oil and gas field development engineering, and in particular to a method and device for regulating the operating conditions of gas field gathering and transmission pipelines that couples the characteristics of reciprocating compressors. Background Technology

[0002] Gas field gathering and transportation systems are crucial facilities for gas field development. Their pipeline networks are characterized by large scale, numerous energy-consuming nodes, and complex network structures. Furthermore, their production and operating parameters are characterized by a large number of parameters, rapid changes, complex patterns, and poor controllability. Simultaneously, as gas field production progresses, the development landscape changes, with multiple development methods coexisting. In the mid-to-late stages of development, most gas fields experience an increase in pressurization projects, leading to a year-on-year rise in energy consumption, with compressors being the primary energy-consuming components. Therefore, to optimize and reduce energy consumption in gas field gathering and transportation systems, steady-state simulation analysis must be conducted jointly on the gathering and transportation pipeline network and compressors.

[0003] Reciprocating compressors are the preferred choice for gas field boosting projects due to their advantages such as high exhaust pressure, stable exhaust, and ability to achieve high pressure operation with small gas volumes, making them suitable for actual gas field production. However, existing simulation models are mostly designed for centrifugal compressors, lacking models and calculation methods applicable to gas field gathering and transmission pipeline boosting projects. Furthermore, existing steady-state simulation techniques suffer from weak computational stability and sensitivity to initial iteration values ​​in pipeline hydraulic calculations. They also tend to simplify the handling of equipment control equations, limiting calculations to fixed inlet and outlet pressures or pressure ratios, and are unsuitable for adjusting compressor speed, exhaust volume, and other operating conditions. Moreover, research on the coupled calculation of reciprocating compressors and gathering and transmission pipelines is lacking, failing to meet the needs of optimizing various operating conditions in gas field gathering and transmission pipelines.

[0004] There is an urgent need for a method to regulate the operating conditions of gas field gathering and transmission pipelines that couples the characteristics of reciprocating compressors, so as to solve the problem that the existing technology lacks research on the coupling calculation of reciprocating compressors and gathering and transmission pipelines, and cannot meet the needs of regulating and optimizing various operating conditions of gas field gathering and transmission pipelines. Summary of the Invention

[0005] To address the problems in existing technologies, this paper presents a method and device for adjusting the operating conditions of gas field gathering and transmission pipelines by coupling the characteristics of reciprocating compressors. This method is applicable to the general node numbering method for solving the characteristic equations of pipelines and reciprocating compressors, which greatly reduces the difficulty of preprocessing for pipeline simulation, improves efficiency, improves the linear approximation method for pipeline simulation, expands the constraints of reciprocating compressors, and realizes operating condition adjustment in various ways such as variable speed and variable discharge volume. This provides a powerful analytical tool for optimizing energy consumption in gas field gathering and transmission systems.

[0006] To solve the above-mentioned technical problems, the specific technical solution presented in this paper is as follows:

[0007] On the one hand, the embodiments in this paper provide a method for adjusting the operating conditions of a gas field gathering and transmission pipeline network coupled with the characteristics of a reciprocating compressor, including,

[0008] Based on the structure of the gas field gathering and transmission pipeline network, auxiliary nodes and auxiliary pipelines are added to the gas field gathering and transmission pipeline network;

[0009] A pipe segment node association matrix is ​​generated based on all nodes in the gas field gathering and transmission pipeline network. The pipe segment node association matrix includes information on the interconnections between pipelines and nodes.

[0010] The pipeline friction and admittance matrices are calculated based on the basic parameters of the pipeline network, including the pipeline segment node correlation matrix, as well as the set initial values ​​of pipeline flow, node temperature, and natural gas physical properties, and a coefficient matrix is ​​generated.

[0011] The nodal pressure and pipeline flow rate are obtained based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix.

[0012] The node temperature is obtained by performing thermal calculations on the gas field gathering and transmission pipeline network based on the pipeline flow rate.

[0013] The natural gas physical properties were recalculated based on the BWRS equation of state and the node pressure and node temperature.

[0014] Determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold;

[0015] If not, the pipeline flow rate is used as the initial value of the pipeline flow rate, the node temperature is used as the initial value of the node temperature, and the steps of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the initial value of the pipeline flow rate, the initial value of the node temperature, and the recalculated natural gas physical property parameters are performed, and the coefficient matrix is ​​generated.

[0016] If so, based on the predetermined standard values ​​for pipeline flow rate and node temperature, determine whether the pipeline flow rate and node temperature meet the requirements. If not, change the set compressor speed, reset the set initial values ​​for pipeline flow rate, node temperature, and natural gas properties, and return to the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the set initial values ​​for pipeline flow rate, node temperature, and natural gas properties, and generating the coefficient matrix, until the pipeline flow rate and node temperature meet the requirements, so as to adjust the operating conditions of the gas field basic pipeline network according to the corresponding set speed.

[0017] Furthermore, the steps of adding auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission network include,

[0018] The auxiliary node is added between two devices in the gas field gathering and transmission pipeline network, and the auxiliary pipeline is added between the original node of the device and the auxiliary node corresponding to the device.

[0019] Furthermore, the basic parameters of the pipeline network also include pipe diameter D, pipe length L, and pipe friction coefficient λ; the physical properties of natural gas include natural gas compressibility factor Z, natural gas relative density Δ, and natural gas average temperature T, wherein the natural gas average temperature T is calculated based on the set initial node temperature value and the pipe segment node correlation matrix;

[0020] The steps of calculating the pipeline friction and admittance matrix and generating the coefficient matrix based on the pipeline network basic parameters including the pipeline segment node correlation matrix, the set initial values ​​of pipeline flow rate, the set initial values ​​of node temperature, and natural gas physical properties include:

[0021] According to the formula Calculate the pipe friction, where S is the pipe friction and C is a constant;

[0022] According to the formula Calculate the admittance matrix, where G is the admittance matrix, Q is the set initial value of pipeline flow rate, and α is the flow index;

[0023] According to the formula Y=A×G×A T Calculate the coefficient matrix, where Y is the coefficient matrix, A is the pipe segment node association matrix, and T is the matrix transpose.

[0024] Furthermore, the natural gas physical properties also include the compressibility factor of the natural gas at the compressor inlet, the natural gas density, the specific heat capacity of the gas flowing into the inlet node, and the specific heat capacity of the gas at the compressor outlet.

[0025] Further, the steps of obtaining the nodal pressure and pipeline flow rate based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix include:

[0026] Generate an association matrix K between compressor nodes and pipelines based on all nodes in the gas field gathering and transmission pipeline network;

[0027] According to the formula:

[0028]

[0029] Calculate the node pressure and pipeline flow rate, where Y 11 Y 12 Y 21 Y 22The elements in the coefficient matrix are represented by C1, C2, C3, and D, which represent the coefficients of the compressor control equations. K1 and K2 represent the elements in the correlation matrix between the compressor nodes and the pipeline. P1 is the unknown node pressure, and P2 is the known node pressure. The known node pressure P2 is obtained based on the structure of the gas field gathering and transmission pipeline network. The unknown node pressure P1 and the known node pressure P2 are used as the node pressures. F is the compressor flow rate. q1 is the known flow rate input for each node, and q2 is the unknown flow rate output for each node. The known flow rate input q1 and the unknown flow rate output q2 for each node are used as the pipeline flow rate. Where T1 represents the compressor inlet temperature, T0 represents the pressure and temperature under standard conditions, p0 represents the pressure under standard conditions, p1 represents the compressor inlet pressure, Z1 represents the compressibility factor of the natural gas inlet to the compressor, and λ p Indicates the pressure coefficient, λ T Represents the temperature coefficient, λ l The leakage coefficient is represented by α, the relative clearance volume is α, p2 is the compressor outlet pressure, m is the polytropic coefficient, and V is the leakage coefficient. h is the theoretical intake volume per revolution of the compressor, and n is the set compressor speed.

[0030] Furthermore, based on the pipeline flow rate, thermal calculations are performed on the gas field gathering and transmission network to obtain the node temperature, which further includes...

[0031] Construct an association matrix between the pipe end and the nodes based on the pipe segment node association matrix and the pipe flow rate;

[0032] Based on the correlation matrix between the pipe end and the node, and the pipe flow rate, using the formula:

[0033]

[0034] Calculate the node temperature, where T i For node temperature, b in,ij m is an element of a pipe end node in the association matrix between pipe ends and nodes. in,j c represents the mass flow rate flowing into the node at the end of the pipeline. in,j T represents the specific heat capacity of the gas flowing into the node. in,j The temperature at the inflow node at the end of the pipe, m f,k Let c be the mass flow rate through the pipeline and the k-th compressor. f,k Let T be the specific heat capacity of the outlet gas of the k-th compressor. f,k Let m be the outlet temperature of the k-th compressor. out,i Let m be the outflow flow from the node, where m is the mass flow rate m flowing into the node from the end of the pipe. in,jThe outflow node flow rate m is calculated based on the pipeline flow rate and the density of the natural gas in the pipeline. out,i T is calculated based on the mass flow rate into the terminal node of the pipeline and the number of pipelines. in,j The inflow temperature at the end of the pipeline includes a set known node temperature and an unknown node temperature, wherein the unknown node temperature is the initial value of the set node temperature.

[0035] Further, the step of constructing the correlation matrix between the pipe end and the nodes based on the pipe segment node correlation matrix and the pipe flow rate includes,

[0036] The flow rate of the pipeline in the gas field gathering and transmission network is determined to be less than 0.

[0037] If so, then the element of the pipeline in the pipe segment node association matrix shall be used as the element of the pipeline in the association matrix between the pipeline end and the node;

[0038] If not, then the opposite of the elements of the pipe in the pipe segment node association matrix shall be used as the elements of the pipe in the pipe end and node association matrix.

[0039] Based on the structure of the gas field gathering and transmission pipeline network, the value of the element corresponding to the inlet pipeline in the correlation matrix of the pipeline and node is set to 1.

[0040] On the other hand, this embodiment also provides a gas field gathering and transmission pipeline operating condition regulation device coupled with the characteristics of a reciprocating compressor, including,

[0041] An auxiliary node adding unit is used to add auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission pipeline network according to the structure of the gas field gathering and transmission pipeline network.

[0042] The pipe segment node association matrix generation unit is used to generate a pipe segment node association matrix based on all nodes in the gas field gathering and transmission pipeline network. The pipe segment node association matrix includes information on the interconnection between pipelines and nodes.

[0043] The iterative parameter calculation unit is used to calculate the pipeline friction and admittance matrix based on the basic parameters of the pipeline network including the pipeline node association matrix, as well as the set initial values ​​of pipeline flow, set initial values ​​of node temperature, and natural gas physical property parameters, and to generate a coefficient matrix.

[0044] The pipeline flow calculation unit is used to obtain the nodal pressure and pipeline flow rate based on the pipeline friction, admittance matrix, set compressor speed and coefficient matrix;

[0045] The node temperature calculation unit is used to perform thermal calculations on the gas field gathering and transmission pipeline network based on the pipeline flow rate to obtain the node temperature.

[0046] A natural gas physical property parameter calculation unit is used to recalculate the natural gas physical property parameters based on the BWRS state equation and the node pressure and node temperature.

[0047] The result verification unit is used to determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold. If not, the pipeline flow rate is used as the initial value of the pipeline flow rate, the node temperature is used as the initial value of the node temperature, and the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the initial value of the pipeline flow rate, the initial value of the node temperature, and the recalculated natural gas physical property parameters, and generating the coefficient matrix is ​​executed. If yes, the pipeline flow rate and node temperature are determined to meet the requirements based on the predetermined standard values ​​of the pipeline flow rate and node temperature. If not, the set compressor speed is changed, the set initial value of the pipeline flow rate, the set initial value of the node temperature, and the natural gas physical property parameters are reset, and the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the set initial value of the pipeline flow rate, the set initial value of the node temperature, and the natural gas physical property parameters, and generating the coefficient matrix is ​​returned, until the pipeline flow rate and node temperature meet the requirements, so as to adjust the operating conditions of the gas field basic pipeline network according to the corresponding set speed.

[0048] On the other hand, embodiments of the present invention also provide a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the above-described method.

[0049] On the other hand, embodiments of the present invention also provide a computer-readable storage medium storing a computer program that, when executed by a processor, implements the above-described method.

[0050] Using the embodiments described in this paper, firstly, based on the characteristics of the complex network topology of the gas field gathering and transmission pipeline network, auxiliary nodes and auxiliary pipelines are added to the gas field gathering and transmission pipeline network. This solves the defect in the prior art where reference nodes and non-reference nodes overlap and there is no solution, and avoids two or more compressors sharing a single node. Then, a pipe segment node association matrix is ​​generated based on all nodes in the gas field gathering and transmission pipeline network. This pipe segment node association matrix includes information on the interconnections between pipelines and nodes, so as to facilitate hydraulic and thermal calculations of the gas field gathering and transmission pipeline network based on the pipe segment node association matrix. Then, based on the basic parameters of the pipeline network, including the pipeline node association matrix, as well as the set initial values ​​of pipeline flow rate, node temperature, and natural gas physical properties, the pipeline friction and admittance matrix are calculated, and a coefficient matrix is ​​generated. Then, the compressor speed is introduced when calculating the node pressure and pipeline flow rate. Based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix, the node pressure and pipeline flow rate are obtained. This realizes the coupled calculation of reciprocating compressors and the gathering and transmission pipeline network in the gas field. Compared with the existing technology, which is limited to fixed equipment inlet and outlet pressure or pressure ratio during calculation, this lays the calculation foundation for adjusting the operating conditions of the compressor speed. Then, based on the pipeline flow rate, thermal calculations are performed on the gas field gathering and transmission network to obtain the node temperatures, realizing the coupled hydraulic and thermal calculations of the gas field gathering and transmission network. Furthermore, the natural gas physical properties are recalculated based on the BWRS state equations and the node pressures and temperatures. Then, when the difference between the pipeline flow rate and its initial value is less than a first threshold and the difference between the node temperature and its initial value is less than a second threshold, a coupled hydraulic and thermal iteration is performed at a set compressor speed. Finally, the pipeline flow rate and node temperature at that set compressor speed are obtained. Finally, the calculated pipeline flow rate and temperature are judged. If the node temperature does not meet the requirements, it means that the current compressor speed cannot reach the optimal level. Therefore, the set compressor speed is adjusted and the set initial values ​​of pipeline flow, node temperature, and natural gas physical properties are reset. Hydraulic and thermal coupling calculations are performed on the gas field gathering and transmission network until the calculated pipeline flow and node temperature meet the requirements. Based on the compressor speed corresponding to the calculated pipeline flow and node temperature meeting the requirements, the operating conditions of the gas field gathering and transmission network are adjusted. This can meet the needs of rapid simulation and optimization of operating parameters caused by the changing operating conditions of gas field production, thereby guiding the actual gas reservoir development in the formation. Attached Figure Description

[0051] To more clearly illustrate the technical solutions in the embodiments or prior art described herein, the accompanying drawings used in the description of the embodiments or prior art will be briefly introduced below. Obviously, the accompanying drawings described below are only some embodiments of this article. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort.

[0052] Figure 1 This is a schematic diagram of the implementation system of a gas field gathering and transmission pipeline network operating condition adjustment method coupled with the characteristics of a reciprocating compressor, as described in the embodiments of this paper.

[0053] Figure 2 The diagram shown is a schematic flowchart of a gas field gathering and transmission pipeline operating condition adjustment method coupled with the characteristics of a reciprocating compressor, according to an embodiment of this paper.

[0054] Figure 3 The diagram shown is a structural schematic of the gas field gathering and transmission pipeline network in the embodiment of this article;

[0055] Figure 4 The diagram shown is a schematic of the structure of the gas field gathering and transmission pipeline network after general node sorting and numbering.

[0056] Figure 5 The diagram shown is a structural schematic of a gas field gathering and transmission pipeline operating condition regulation device coupled with the characteristics of a reciprocating compressor, according to an embodiment of this paper.

[0057] Figure 6 The diagram shown is a structural schematic of the computer device in the embodiment of this article.

[0058] [Explanation of Figure Markers]:

[0059] 101. Terminal;

[0060] 102. Server;

[0061] 501. Adding units to auxiliary nodes;

[0062] 502. Pipe segment node association matrix generation unit;

[0063] 503. Iteration Parameter Calculation Unit;

[0064] 504. Pipeline flow calculation unit;

[0065] 505. Node temperature calculation unit;

[0066] 506. Natural Gas Physical Property Parameter Calculation Unit;

[0067] 507. Result Verification Unit;

[0068] 602. Computer equipment;

[0069] 604, Processor;

[0070] 606. Memory;

[0071] 608. Drive mechanism;

[0072] 610. Input / output module;

[0073] 612. Input devices;

[0074] 614. Output devices;

[0075] 616. Presentation equipment;

[0076] 618. Graphical User Interface;

[0077] 620. Network interface;

[0078] 622. Communication link;

[0079] 624. Communication bus. Detailed Implementation

[0080] The technical solutions in the embodiments described below will be clearly and completely described with reference to the accompanying drawings. Obviously, the described embodiments are only a part of the embodiments described herein, and not all of the embodiments. Based on the embodiments described herein, all other embodiments obtained by those skilled in the art without creative effort are within the scope of protection of this document.

[0081] It should be noted that the terms "first," "second," etc., used in the specification, claims, and accompanying drawings herein are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover a non-exclusive inclusion; for example, a process, method, apparatus, product, or device that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or devices.

[0082] like Figure 1The diagram shows a schematic of an implementation system for a gas field gathering and transmission pipeline operating condition adjustment method coupled with the characteristics of a reciprocating compressor according to an embodiment of the present invention. It may include a terminal 101 and a server 102. A communication connection is established between the terminal 101 and the server 102 to enable data interaction. The terminal 101 can input parameters such as the structure of the gas field gathering and transmission pipeline network, basic pipeline parameters, initial values ​​of pipeline flow rate, initial values ​​of node temperature, and set compressor speed into the server 102. It can also input threshold values ​​required for judgment. The server 102 iteratively calculates the pipeline flow rate and node temperature of the gas field gathering and transmission pipeline network based on the basic pipeline parameters, initial values ​​of pipeline flow rate, initial values ​​of node temperature, and set compressor speed. It judges whether the calculated pipeline flow rate and node temperature meet the requirements based on the corresponding threshold values, thereby determining whether the set compressor speed meets the requirements. If the set compressor speed does not meet the requirements, the server can adjust the compressor speed and re-perform iterative calculations based on the basic pipeline parameters, initial values ​​of pipeline flow rate, and initial values ​​of node temperature until the pipeline flow rate and node temperature obtained by the iterative calculation meet the corresponding threshold values. The corresponding compressor speed is then taken as the optimal value, thereby providing the optimal compressor speed to the terminal so that the staff can adjust the operating conditions of the gas field gathering and transmission pipeline network according to the optimal compressor speed.

[0083] In the embodiments of this specification, the server 102 may be an independent physical server, a server cluster or distributed system composed of multiple physical servers, or a cloud server that provides basic cloud computing services such as cloud services, cloud databases, cloud computing, cloud functions, cloud storage, network services, cloud communication, middleware services, domain name services, security services, content delivery networks (CDN), and big data and artificial intelligence platforms.

[0084] In one optional embodiment, terminal 101 may be an electronic device, including but not limited to desktop computers, tablets, laptops, etc. Optionally, the operating system running on the electronic device may include, but is not limited to, Android, iOS, Linux, Windows, etc.

[0085] In addition, it should be noted that, Figure 1 The example shown is merely one application environment provided by this disclosure. In practical applications, other application environments may also be included, and this specification does not impose any limitations.

[0086] To address the problems existing in the prior art, this paper presents a method for adjusting the operating conditions of gas field gathering and transmission pipelines by coupling the characteristics of reciprocating compressors. This method is applicable to the general node numbering method for solving the characteristic equations of pipelines and reciprocating compressors, which greatly reduces the difficulty of pipeline simulation preprocessing, improves efficiency, improves the linear approximation method for pipeline simulation, expands the constraints of reciprocating compressors, and realizes operating condition adjustment in various ways such as variable speed and variable discharge volume. This provides a powerful analytical tool for optimizing energy consumption in gas field gathering and transmission systems. Figure 2 The diagram illustrates a flow chart of a gas field gathering and transmission pipeline network operating condition adjustment method coupled with the characteristics of a reciprocating compressor, as described in this embodiment. This diagram depicts the process of adjusting the operating conditions of the gas field gathering and transmission pipeline network; however, based on conventional or non-creative labor, it may include more or fewer operational steps. The order of steps listed in the embodiment is merely one possible execution order among many and does not represent the only possible order. In actual system or device products, the methods shown in the embodiment or the accompanying drawings can be executed sequentially or in parallel. Specifically, as shown... Figure 2 As shown, the method, which can be executed by a processing unit on a server, may include:

[0087] Step 201: Based on the structure of the gas field gathering and transmission pipeline network, add auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission pipeline network;

[0088] In this step, the structure of the gas field gathering and transmission pipeline network includes multiple components, which can be compressors, valves or pipelines. In the prior art, in order to facilitate iterative calculation of pipeline flow in the gas field gathering and transmission pipeline network, a node is set between the components, that is, each node connects two components. Each node can be regarded as a boundary condition, that is, different components belong to different calculation units, and there is a calculation boundary between two components.

[0089] For example, the structure of a gas field gathering and transmission network consisting of pipelines, compressors, and valves can be as follows: Figure 3 As shown, the natural gas in the gas field gathering and transmission pipeline network flows in the direction indicated by the arrow. Node 5 represents both the compressor outlet and the valve inlet, which are two different boundary conditions. Treating node 5 as a single node in the calculation might affect the accuracy of the calculation. Therefore, in this embodiment, auxiliary nodes and auxiliary pipelines are added to the gas field gathering and transmission pipeline network so that each node represents a boundary condition. Specifically, auxiliary nodes and pipelines are added between the nodes of the original components. For example, continuing as follows... Figure 3As shown, auxiliary node 3 is added at the compressor inlet, auxiliary node 4 at the compressor outlet, auxiliary node 6 at the valve inlet, and auxiliary node 7 at the valve outlet. An auxiliary pipe ② is added between the original node 2 and the added auxiliary node 3, an auxiliary pipe ③ is added between auxiliary node 4 and the original node 5, an auxiliary pipe ④ is added between the original node 5 and the added auxiliary node 6, and an auxiliary pipe ⑤ is added between auxiliary node 7 and the original node 8. This ensures that each node belongs to a boundary condition, facilitating calculation.

[0090] To distinguish the meaning represented by the nodes, Figure 3 The nodes in the network are named as a basis for node sorting. Specifically, all nodes in the network can be named according to the type of boundary conditions, such as which are non-reference nodes and which are reference nodes. For example, as shown in Table 1:

[0091] Table 1 Node Number and Name

[0092] Node number Node Name Reference Node Non-reference node 1 Constant load flow node no yes 2 Compressor inlet node no yes 3 Compressor input auxiliary node yes no 4 Compressor output auxiliary node no yes 5 Compressor outlet and valve inlet nodes no yes 6 Valve input auxiliary node yes no 7 Valve output auxiliary node no yes 8 Valve outlet node no yes 9 Constant pressure node yes no

[0093] Then, the nodes can be sorted according to certain rules and assigned a common node number for easier calculation. Specifically, all nodes in the pipeline network can be sorted based on the principle that non-reference nodes precede reference nodes, where non-reference nodes represent nodes with known flow and reference nodes represent nodes with unknown flow. This facilitates the block-based solution of the coefficient matrix. For example, for... Figure 3 After sorting and numbering the nodes shown, the resulting node graph is as follows: Figure 4 As shown in Table 2, a table showing the correspondence between node names and numbers after general node sorting and numbering can be used.

[0094] Table 2 General Node Numbering Sequence

[0095]

[0096] Step 202: Generate a pipe segment node association matrix based on all nodes in the gas field gathering and transmission pipeline network;

[0097] In this step, the pipe segment node association matrix includes information on the interconnections between pipes and nodes.

[0098] Computer representation of pipeline diagrams is an important preparatory step for automatically identifying the pipeline topology before pipeline simulation. It is typically expressed in matrix form, showing the connection information of nodes and branches in the pipeline network. If a pipeline network has n pipe segments and m nodes, then its corresponding directed graph has n branches and m nodes. The connection relationship between branches and nodes in the directed graph can be represented by an m×n node incidence matrix A = [a...]. ij ] n×mRepresenting it is one of the simplest and most common methods for inputting network graphical information. Each node and pipe in the directed network graph is numbered; the node numbered i is recorded in row i of the matrix, the pipe numbered j is recorded in column j, and so on. ij The definition is as follows:

[0099]

[0100] Step 203: Calculate the pipeline friction and admittance matrix based on the basic parameters of the pipeline network including the pipeline segment node association matrix, the set initial values ​​of pipeline flow rate, the set initial values ​​of node temperature, and natural gas physical property parameters, and generate a coefficient matrix;

[0101] In this step, the basic parameters of the pipeline network also include pipe diameter D, pipe length L, and pipe friction coefficient λ; the physical properties of natural gas include natural gas compressibility factor Z, natural gas relative density Δ, and natural gas average temperature T. The natural gas average temperature T is calculated based on the set initial node temperature value and the pipe segment node correlation matrix. The set initial pipe flow rate value and the set initial node temperature value can be set based on actual experience.

[0102] The steps of calculating the pipeline friction and admittance matrix and generating the coefficient matrix based on the pipeline network basic parameters including the pipeline segment node correlation matrix, the set initial values ​​of pipeline flow rate, the set initial values ​​of node temperature, and natural gas physical properties include:

[0103] Calculate the pipe friction according to formula (1):

[0104]

[0105] Where S is the pipe friction and C is a constant;

[0106] Calculate the admittance matrix according to formula (2):

[0107]

[0108] Wherein, G is the admittance matrix, Q is the set initial value of pipeline flow, and α is the flow index;

[0109] Calculate the coefficient matrix according to formula (3):

[0110] Y = A × G × A T (3)

[0111] Where Y is the coefficient matrix, A is the pipe segment node association matrix, and T is the matrix transpose.

[0112] The natural gas physical properties parameters also include the compressibility factor of the natural gas at the compressor inlet, the natural gas density, the specific heat capacity of the gas flowing into the inlet node, and the specific heat capacity of the gas at the compressor outlet.

[0113] Step 204: Obtain the nodal pressure and pipeline flow rate based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix;

[0114] The relationship between the pipeline node pressure P, the coefficient matrix Y, and the node load flow vector q is shown in equation (4):

[0115] YP = -q (4)

[0116] If the compressor is considered, the nodal equation model of formula (4) needs to be improved. The flow rate through the compressor is treated as the nodal load, and the input nodal flow rate is defined as positive and the output nodal flow rate is negative. Formula (4) is then rewritten as:

[0117] YP=-q-KF (5)

[0118] Where F is the flow rate through the compressor, and K is the correlation matrix between the compressor node and the pipeline.

[0119] Specifically, an association matrix K between compressor nodes and pipelines is generated based on all nodes in the gas field gathering and transmission pipeline network;

[0120] The association matrix K between compressor nodes and pipelines is defined as follows: node i is defined as positive at the inlet of the equipment component, and node i is defined as negative at the outlet of the equipment component. The information of node i is recorded in row i of the matrix, and the information of non-pipeline components numbered j is recorded in column j. ij The definition is as follows:

[0121]

[0122] The initial flow direction of the equipment elements in the K matrix is ​​assumed. If the calculated flow rate is negative, it is opposite to the assumed direction, and vice versa. The K matrix also contains a large number of zero elements. The more equipment elements there are in the pipeline network, the more zero elements there will be. Similarly, the relationship between equipment elements and node numbers can be represented by a peak matrix.

[0123] The compression control equation is shown in equation (6):

[0124] C1P1 + C2P2 + C3F = D (6)

[0125] Where P1 is the inlet pressure of the equipment component, P2 is the outlet pressure of the equipment component, and C1, C2, and C3 are the coefficients of the control equation of the equipment component. Changing the coefficients can realize the calculation of various constraints of the equipment component.

[0126] According to formula (7):

[0127]

[0128] Calculate the node pressure and pipeline flow rate, where Y 11 Y 12 Y 21 Y 22 The elements in the coefficient matrix are represented by C1, C2, C3, and D, which represent the coefficients of the compressor control equation. K1 and K2 represent the elements in the correlation matrix between the compressor nodes and the pipeline. P1 is the unknown node pressure, and P2 is the known node pressure. The known node pressure P2 is obtained based on the structure of the gas field gathering and transmission pipeline network. The unknown node pressure P1 and the known node pressure P2 are used as the node pressure. F is the compressor flow rate. q1 is the known flow rate input for each node, and q2 is the unknown flow rate output for each node. The known flow rate input q1 and the unknown flow rate output q2 for each node are used as the pipeline flow rate. The definition of F is shown in formula (8).

[0129]

[0130] Where T1 represents the compressor inlet temperature, T0 is the pressure and temperature under standard conditions (T0 = 293.15 K), p0 is the pressure under standard conditions (p0 = 1.10325 kPa), p1 is the compressor inlet pressure, Z1 represents the compressibility factor of the natural gas inlet to the compressor, and λ p Indicates the pressure coefficient, λ T Represents the temperature coefficient, λ l The leakage coefficient is represented by α, the relative clearance volume is represented by p2, the compressor outlet pressure is represented by m, the polytropic coefficient is represented by Vh, the theoretical intake volume per compressor revolution is represented by Vh, and the set compressor speed is represented by n.

[0131] In the hydraulic and thermal calculations of gas field gathering and transmission pipeline networks, hydraulic and thermal calculations are inseparable. Due to the complex pipeline structure, significant and interdependent temperature and pressure variations at pipeline connections and within the pipeline, hydrates may form within the gathering and transmission pipeline network under certain temperature and pressure conditions. Therefore, to ensure the accuracy of the calculations, it is necessary to use a coupled iterative solution of hydraulic and thermal calculations.

[0132] Step 205: Perform thermal calculations on the gas field gathering and transmission network based on the pipeline flow rate to obtain the node temperature;

[0133] The inlet and outlet temperatures of a node differ. The inlet temperature primarily depends on the end temperature of the pipe, calculated using the Sukhov temperature drop formula. The outlet temperature is the temperature resulting from the mixing of several pipe end temperatures, which is also the node temperature. Therefore, to solve for the temperature of a specific node, the temperatures of the nodes into which it flows must first be determined; that is, the solution for the node temperatures in a pipe network has an order. For branched pipe networks, the flow direction of the pipes is fixed, so the assumed initial flow direction is consistent with the actual flow direction, and temperature calculations can be performed directly. However, for ring-shaped pipe networks, the actual flow direction of the pipes within the loop changes during the iteration process. Therefore, before calculating the temperature, it is necessary to ensure that the initially assumed flow direction of the pipes is consistent with the actual flow direction during the iterative calculation process. First, an association matrix between the pipe end and the node is constructed based on the pipe segment node association matrix and the pipe flow rate.

[0134] Specifically, the step of constructing the correlation matrix between the pipe end and the nodes based on the pipe segment node correlation matrix and the pipe flow rate includes:

[0135] The flow rate of the pipeline in the gas field gathering and transmission network is determined to be less than 0.

[0136] If so, then the element of the pipeline in the pipe segment node association matrix shall be used as the element of the pipeline in the association matrix between the pipeline end and the node;

[0137] If not, then the opposite of the elements of the pipe in the pipe segment node association matrix shall be used as the elements of the pipe in the pipe end and node association matrix.

[0138] Based on the structure of the gas field gathering and transmission pipeline network, the value of the element corresponding to the inlet pipeline in the correlation matrix of the pipeline and node is set to 1.

[0139] Based on the correlation matrix between the pipe end and the node and the pipe flow rate, using formula (9):

[0140]

[0141] Calculate the node temperature, where T i For node temperature, b in,ij m is an element of a pipe end node in the association matrix between pipe ends and nodes. in,j c represents the mass flow rate flowing into the node at the end of the pipeline. in,j T represents the specific heat capacity of the gas flowing into the node. in,j The temperature at the inflow node at the end of the pipe, m f,k Let c be the mass flow rate through the pipeline and the k-th compressor. f,k Let T be the specific heat capacity of the outlet gas of the k-th compressor. f,k Let m be the outlet temperature of the k-th compressor. out,iLet m be the outflow flow from the node, where m is the mass flow rate m flowing into the node from the end of the pipe. in,j The outflow node flow rate m is calculated based on the pipeline flow rate and the density of the natural gas in the pipeline. out,i T is calculated based on the mass flow rate into the terminal node of the pipeline and the number of pipelines. in,j The inflow temperature at the end of the pipeline includes a set known node temperature and an unknown node temperature, wherein the unknown node temperature is the initial value of the set node temperature.

[0142] Step 206: Recalculate the natural gas physical properties based on the BWRS equation of state and the node pressure and node temperature;

[0143] It should be noted that the calculation method of the BWRS state equation described in this step is a well-known common knowledge in the field, and will not be repeated in the embodiments of this specification.

[0144] Step 207: Determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold;

[0145] In this embodiment, if the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and the difference between the node temperature and the initial value of the node temperature is less than a second threshold, it indicates that the iterative calculation has converged, and the pipeline flow rate and node temperature at the currently set compressor speed can be obtained; otherwise, it indicates that the iterative calculation has not yet converged.

[0146] In this step, if not, proceed to step 208; otherwise, proceed to step 209.

[0147] Step 208: Using the pipeline flow rate as the initial value of the pipeline flow rate and the node temperature as the initial value of the node temperature, repeat step 203 to iteratively calculate the pipeline flow rate and node temperature;

[0148] It should be noted that, in this step, in addition to using the calculated pipeline flow rate as the initial value of the pipeline flow rate and the calculated node temperature as the initial value of the node temperature in step 203, it is also necessary to replace the natural gas physical property parameters recalculated in step 206 with the natural gas physical property parameters in step 203. That is, during the iteration process, only the basic parameters of the pipeline network remain unchanged in step 203; the initial values ​​of the pipeline flow rate, the initial values ​​of the node temperature, and the natural gas physical property parameters all change with each iteration. Then, based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix calculated iteratively, the node pressure and pipeline flow rate are obtained. Thermodynamic calculations are performed on the gas field gathering and transmission network based on the pipeline flow rate to obtain the node temperature. The natural gas physical property parameters are recalculated based on the BWRS state equation and the node pressure and node temperature. Then, step 207 is executed to determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold.

[0149] Step 209: Determine whether the pipeline flow rate and node temperature meet the requirements based on the predetermined pipeline flow rate standard value and node temperature standard value;

[0150] In this step, the pipeline flow rate and node temperature obtained by iterative calculation are based on the currently set compressor speed. If the pipeline flow rate and node temperature meet the requirements, it means that the currently set compressor speed can make the pipeline flow rate and node temperature of the pipeline network meet the requirements, and the currently set compressor speed can be used to guide the actual formation gas reservoir exploitation. Otherwise, it means that the currently set compressor speed cannot make the pipeline flow rate and node temperature in the pipeline network meet the requirements, and the compressor speed needs to be adjusted and iterative calculations need to be performed again.

[0151] If the requirements are not met in this step, proceed to step 210; otherwise, proceed to step 211.

[0152] Step 210: Change the set compressor speed, reset the set initial value of pipeline flow, the set initial value of node temperature and natural gas physical parameters, and repeat step 203.

[0153] In this step, when the iteration converges (i.e., whether the difference between the pipeline flow rate obtained in the iteration and the pipeline flow rate obtained in the previous iteration is less than a first threshold and whether the difference between the node temperature obtained in the iteration and the node temperature obtained in the previous iteration is less than a second threshold), if the pipeline flow rate and node temperature do not meet the requirements, the compressor speed needs to be changed and the iteration calculation needs to be repeated. When the iteration calculation is repeated, the initial values ​​of pipeline flow rate and node temperature used in the first iteration are not the pipeline flow rate and node temperature obtained when the iteration converges, but the pipeline flow rate and node temperature set when the previous iteration calculation was performed at the set compressor speed. It can be understood that when simulating each compressor speed, the basic parameters of the pipeline network, the set pipeline flow rate, the set node temperature, and the natural gas physical properties at the set pipeline flow rate and node temperature are all the same, only the compressor speed is different, thus realizing the simulation calculation of the compressor speed.

[0154] Step 211: Output the set compressor speed so that the staff can adjust the working conditions of the gas field basic pipeline network according to the set speed.

[0155] The method described in this embodiment first adds auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission pipeline network based on the characteristics of the complex network topology. This solves the problem of overlapping reference nodes and non-reference nodes in the prior art, which prevents the solution from being obtained. It also avoids two or more compressors sharing a single node. Then, a pipe segment node association matrix is ​​generated based on all nodes in the gas field gathering and transmission pipeline network. This pipe segment node association matrix includes information on the interconnections between pipelines and nodes, so as to facilitate hydraulic and thermal calculations of the gas field gathering and transmission pipeline network based on the pipe segment node association matrix. Then, based on the basic parameters of the pipeline network, including the pipeline node association matrix, as well as the set initial values ​​of pipeline flow rate, node temperature, and natural gas physical properties, the pipeline friction and admittance matrix are calculated, and a coefficient matrix is ​​generated. Then, the compressor speed is introduced when calculating the node pressure and pipeline flow rate. Based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix, the node pressure and pipeline flow rate are obtained. This realizes the coupled calculation of reciprocating compressors and the gathering and transmission pipeline network in the gas field. Compared with the existing technology, which is limited to fixed equipment inlet and outlet pressure or pressure ratio during calculation, this lays the calculation foundation for adjusting the operating conditions of the compressor speed. Then, based on the pipeline flow rate, thermal calculations are performed on the gas field gathering and transmission network to obtain the node temperatures, realizing the coupled hydraulic and thermal calculations of the gas field gathering and transmission network. Furthermore, the natural gas physical properties are recalculated based on the BWRS state equations and the node pressures and temperatures. Then, when the difference between the pipeline flow rate and its initial value is less than a first threshold and the difference between the node temperature and its initial value is less than a second threshold, a coupled hydraulic and thermal iteration is performed at a set compressor speed. Finally, the pipeline flow rate and node temperature at that set compressor speed are obtained. Finally, the calculated pipeline flow rate and temperature are judged. If the node temperature does not meet the requirements, it means that the current compressor speed cannot reach the optimal level. Therefore, the set compressor speed is adjusted and the set initial values ​​of pipeline flow, node temperature, and natural gas physical properties are reset. Hydraulic and thermal coupling calculations are performed on the gas field gathering and transmission network until the calculated pipeline flow and node temperature meet the requirements. Based on the compressor speed corresponding to the calculated pipeline flow and node temperature meeting the requirements, the operating conditions of the gas field gathering and transmission network are adjusted. This can meet the needs of rapid simulation and optimization of operating parameters caused by the changing operating conditions of gas field production, thereby guiding the actual gas reservoir development in the formation.

[0156] Based on the same inventive concept, embodiments of the present invention also provide a gas field gathering and transmission pipeline operating condition adjustment device with the characteristics of a compound compressor, such as... Figure 5 As shown, including,

[0157] The auxiliary node adding unit 501 is used to add auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission pipeline network according to the structure of the gas field gathering and transmission pipeline network.

[0158] Pipeline segment node association matrix generation unit 502 is used to generate a pipeline segment node association matrix based on all nodes in the gas field gathering and transmission pipeline network. The pipeline segment node association matrix includes information on the interconnection between pipelines and nodes.

[0159] The iterative parameter calculation unit 503 is used to calculate the pipeline friction and admittance matrix based on the basic parameters of the pipeline network including the pipeline node association matrix, as well as the set initial values ​​of pipeline flow, the set initial values ​​of node temperature, and natural gas physical property parameters, and to generate a coefficient matrix.

[0160] The pipeline flow calculation unit 504 is used to obtain the node pressure and pipeline flow based on the pipeline friction, admittance matrix, set compressor speed and coefficient matrix;

[0161] The node temperature calculation unit 505 is used to perform thermal calculations on the gas field gathering and transmission pipeline network based on the pipeline flow rate to obtain the node temperature.

[0162] Natural gas physical property parameter calculation unit 506 is used to recalculate the natural gas physical property parameters according to the BWRS state equation and the node pressure and node temperature;

[0163] The result verification unit 507 is used to determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold. If not, the pipeline flow rate is used as the initial value of the pipeline flow rate, the node temperature is used as the initial value of the node temperature, and the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the initial value of the pipeline flow rate, the initial value of the node temperature, and the recalculated natural gas physical property parameters, and generating the coefficient matrix is ​​executed. If yes, the pipeline flow rate and node temperature are determined to meet the requirements based on the predetermined standard values ​​of the pipeline flow rate and node temperature. If not, the set compressor speed is changed, the set initial value of the pipeline flow rate, the set initial value of the node temperature, and the natural gas physical property parameters are reset, and the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the set initial value of the pipeline flow rate, the set initial value of the node temperature, and the natural gas physical property parameters, and generating the coefficient matrix is ​​returned, until the pipeline flow rate and node temperature meet the requirements, so as to adjust the operating conditions of the gas field basic pipeline network according to the corresponding set speed.

[0164] Since the principle of the above-mentioned device in solving the problem is similar to that of the above-mentioned method, the implementation of the above-mentioned device can refer to the implementation of the above-mentioned method, and the repeated parts will not be described again.

[0165] like Figure 6As shown, a computer device provided in this embodiment is described. The apparatus described herein can be the computer device in this embodiment, performing the methods described above. The computer device 602 may include one or more processors 604, such as one or more central processing units (CPUs), each of which can implement one or more hardware threads. The computer device 602 may also include any memory 606 for storing information of any kind, such as code, settings, data, etc. Without limitation, for example, memory 606 may include any type of RAM, any type of ROM, flash memory device, hard disk, optical disk, etc. More generally, any memory can use any technology to store information. Further, any memory can provide volatile or non-volatile retention of information. Further, any memory may represent a fixed or removable component of the computer device 602. In one case, when processor 604 executes associated instructions stored in any memory or combination of memories, the computer device 602 can perform any operation of the associated instructions. The computer device 602 also includes one or more drive mechanisms 608 for interacting with any memory, such as hard disk drive mechanisms, optical disk drive mechanisms, etc.

[0166] Computer device 602 may also include an input / output module 610 (I / O) for receiving various inputs (via input device 612) and providing various outputs (via output device 614). A specific output mechanism may include a presentation device 616 and an associated graphical user interface (GUI) 618. In other embodiments, the input / output module 610 (I / O), input device 612, and output device 614 may be omitted, and the device may function solely as a computer device within a network. Computer device 602 may also include one or more network interfaces 620 for exchanging data with other devices via one or more communication links 622. One or more communication buses 624 couple the components described above together.

[0167] Communication link 622 can be implemented in any way, such as via a local area network, a wide area network (e.g., the Internet), a point-to-point connection, or any combination thereof. Communication link 622 may include any combination of hardwired links, wireless links, routers, gateway functions, name servers, etc., governed by any protocol or combination of protocols.

[0168] Corresponding to Figure 2 In addition to the above method, this embodiment also provides a computer-readable storage medium storing a computer program that is executed by a processor to perform the above steps.

[0169] This embodiment also provides a computer-readable instruction, wherein when a processor executes the instruction, the program therein causes the processor to perform the following: Figure 2 The method shown.

[0170] It should be understood that in the various embodiments of this document, the sequence number of each process does not imply the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of this document.

[0171] It should also be understood that, in the embodiments herein, the term "and / or" is merely a description of the relationship between associated objects, indicating that three relationships can exist. For example, A and / or B can represent: A existing alone, A and B existing simultaneously, and B existing alone. Additionally, the character " / " in this document generally indicates that the preceding and following associated objects have an "or" relationship.

[0172] Those skilled in the art will recognize that the units and algorithm steps of the various examples described in conjunction with the embodiments disclosed herein can be implemented in electronic hardware, computer software, or a combination of both. To clearly illustrate the interchangeability of hardware and software, the components and steps of the various examples have been generally described in terms of functionality in the foregoing description. Whether these functions are implemented in hardware or software depends on the specific application and design constraints of the technical solution. Those skilled in the art can use different methods to implement the described functions for each specific application, but such implementation should not be considered beyond the scope of this document.

[0173] Those skilled in the art will clearly understand that, for the sake of convenience and brevity, the specific working processes of the systems, devices, and units described above can be referred to the corresponding processes in the foregoing method embodiments, and will not be repeated here.

[0174] In the embodiments provided herein, it should be understood that the disclosed systems, apparatuses, and methods can be implemented in other ways. For example, the apparatus embodiments described above are merely illustrative; for instance, the division of units is only a logical functional division, and in actual implementation, there may be other division methods. For example, multiple units or components may be combined or integrated into another system, or some features may be ignored or not executed. Furthermore, the couplings or direct couplings or communication connections shown or discussed may be indirect couplings or communication connections through some interfaces, devices, or units, or they may be electrical, mechanical, or other forms of connection.

[0175] The units described as separate components may or may not be physically separate. The components shown as units may or may not be physical units; that is, they may be located in one place or distributed across multiple network units. Some or all of the units can be selected to achieve the purpose of the embodiments described herein, depending on actual needs.

[0176] Furthermore, the functional units in the various embodiments of this document can be integrated into one processing unit, or each unit can exist physically separately, or two or more units can be integrated into one unit. The integrated unit can be implemented in hardware or as a software functional unit.

[0177] If the integrated unit is implemented as a software functional unit and sold or used as an independent product, it can be stored in a computer-readable storage medium. Based on this understanding, the technical solution of this paper, in essence, or the part that contributes to the prior art, or all or part of the technical solution, can be embodied in the form of a software product. This computer software product is stored in a storage medium and includes several instructions to cause a computer device (which may be a personal computer, server, or network device, etc.) to execute all or part of the steps of the methods described in the various embodiments of this paper. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0178] This document uses specific embodiments to illustrate the principles and implementation methods of this document. The descriptions of the embodiments above are only for the purpose of helping to understand the methods and core ideas of this document. At the same time, for those skilled in the art, there will be changes in the specific implementation methods and application scope based on the ideas of this document. Therefore, the content of this specification should not be construed as a limitation of this document.

Claims

1. A method for adjusting the operating conditions of a gas field gathering and transmission pipeline network coupled with the characteristics of a reciprocating compressor, characterized in that, include: Based on the structure of the gas field gathering and transmission pipeline network, auxiliary nodes and auxiliary pipelines are added to the gas field gathering and transmission pipeline network; A pipe segment node association matrix is ​​generated based on all nodes in the gas field gathering and transmission pipeline network. The pipe segment node association matrix includes information on the interconnections between pipelines and nodes. The pipeline friction and admittance matrices are calculated based on the basic parameters of the pipeline network, including the pipeline segment node correlation matrix, as well as the set initial values ​​of pipeline flow, node temperature, and natural gas physical properties, and a coefficient matrix is ​​generated. The nodal pressure and pipeline flow rate are obtained based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix. The node temperature is obtained by performing thermal calculations on the gas field gathering and transmission pipeline network based on the pipeline flow rate. The natural gas physical properties were recalculated based on the BWRS equation of state and the node pressure and node temperature. Determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold; If not, the pipeline flow rate is used as the initial value of the pipeline flow rate, the node temperature is used as the initial value of the node temperature, and the steps of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the initial value of the pipeline flow rate, the initial value of the node temperature, and the recalculated natural gas physical property parameters are performed, and the coefficient matrix is ​​generated. If so, based on the predetermined standard values ​​for pipeline flow rate and node temperature, determine whether the pipeline flow rate and node temperature meet the requirements. If not, change the set compressor speed, reset the set initial values ​​for pipeline flow rate, node temperature, and natural gas properties, and return to the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the set initial values ​​for pipeline flow rate, node temperature, and natural gas properties, and generating the coefficient matrix, until the pipeline flow rate and node temperature meet the requirements, so as to adjust the operating conditions of the gas field basic pipeline network according to the corresponding set speed.

2. The method according to claim 1, characterized in that, Based on the structure of the gas field gathering and transmission pipeline network, the steps for adding auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission pipeline network include: The auxiliary node is added between two devices in the gas field gathering and transmission pipeline network, and the auxiliary pipeline is added between the original node of the device and the auxiliary node corresponding to the device.

3. The method according to claim 1, characterized in that, The basic parameters of the pipeline network also include pipe diameter D, pipe length L, and pipe friction coefficient λ; the physical properties of natural gas include natural gas compressibility factor Z, natural gas relative density Δ, and natural gas average temperature T, wherein the natural gas average temperature T is calculated based on the set initial node temperature value and the pipe segment node correlation matrix; The steps of calculating the pipeline friction and admittance matrix and generating the coefficient matrix based on the pipeline network basic parameters including the pipeline segment node correlation matrix, the set initial values ​​of pipeline flow rate, the set initial values ​​of node temperature, and natural gas physical properties include: According to the formula Calculate the pipe friction, where S is the pipe friction and C is a constant; According to the formula Calculate the admittance matrix, where G is the admittance matrix, Q is the set initial value of pipeline flow rate, and α is the flow index; According to the formula Y=A×G×A T Calculate the coefficient matrix, where Y is the coefficient matrix, A is the pipe segment node association matrix, and T is the matrix transpose.

4. The method according to claim 3, characterized in that, The natural gas physical properties also include the compressibility factor of the natural gas at the compressor inlet, the natural gas density, the specific heat capacity of the gas flowing into the inlet node, and the specific heat capacity of the gas at the compressor outlet.

5. The method according to claim 4, characterized in that, The steps for obtaining the nodal pressure and pipeline flow rate based on the pipeline friction, admittance matrix, set compressor speed, and coefficient matrix include: Generate an association matrix K between compressor nodes and pipelines based on all nodes in the gas field gathering and transmission pipeline network; According to the formula: Calculate the node pressure and pipeline flow rate, where Y 11 Y 12 Y 21 Y 22 The elements in the coefficient matrix are represented by C1, C2, C3, and D, which represent the coefficients of the compressor control equations. K1 and K2 represent the elements in the correlation matrix between the compressor nodes and the pipeline. P1 is the unknown node pressure, and P2 is the known node pressure. The known node pressure P2 is obtained based on the structure of the gas field gathering and transmission pipeline network. The unknown node pressure P1 and the known node pressure P2 are used as the node pressures. F is the compressor flow rate. q1 is the known flow rate input for each node, and q2 is the unknown flow rate output for each node. The known flow rate input q1 and the unknown flow rate output q2 for each node are used as the pipeline flow rate. Where T1 represents the compressor inlet temperature, T0 represents the pressure and temperature under standard conditions, p0 represents the pressure under standard conditions, p1 represents the compressor inlet pressure, Z1 represents the compressibility factor of the natural gas inlet to the compressor, and λ p Indicates the pressure coefficient, λ T Represents the temperature coefficient, λ l The leakage coefficient is represented by α, the relative clearance volume is α, p2 is the compressor outlet pressure, m is the polytropic coefficient, and V is the leakage coefficient. h is the theoretical intake volume per revolution of the compressor, and n is the set compressor speed.

6. The method according to claim 5, characterized in that, Thermodynamic calculations are performed on the gas field gathering and transmission network based on the pipeline flow rate to obtain the node temperature, which further includes... Construct an association matrix between the pipe end and the nodes based on the pipe segment node association matrix and the pipe flow rate; Based on the correlation matrix between the pipe end and the node, and the pipe flow rate, using the formula: Calculate the node temperature, where T i For node temperature, b in,ij m is an element of a pipe end node in the association matrix between pipe ends and nodes. in,j c represents the mass flow rate flowing into the node at the end of the pipeline. in,j T represents the specific heat capacity of the gas flowing into the node. in,j The temperature at the inflow node at the end of the pipe, m f,k Let c be the mass flow rate through the pipeline and the k-th compressor. f,k Let T be the specific heat capacity of the outlet gas of the k-th compressor. f,k Let m be the outlet temperature of the k-th compressor. out,i Let m be the outflow flow from the node, where m is the mass flow rate m flowing into the node from the end of the pipe. in,j The outflow node flow rate m is calculated based on the pipeline flow rate and the density of the natural gas in the pipeline. out,i T is calculated based on the mass flow rate into the terminal node of the pipeline and the number of pipelines. in,j The inflow temperature at the end of the pipeline includes a set known node temperature and an unknown node temperature, wherein the unknown node temperature is the initial value of the set node temperature.

7. The method according to claim 6, characterized in that, The steps of constructing the correlation matrix between the pipe end and the nodes based on the pipe segment node correlation matrix and the pipe flow rate include: The flow rate of the pipeline in the gas field gathering and transmission network is determined to be less than 0. If so, then the element of the pipeline in the pipe segment node association matrix shall be used as the element of the pipeline in the association matrix between the pipeline end and the node; If not, then the opposite of the elements of the pipe in the pipe segment node association matrix shall be used as the elements of the pipe in the pipe end and node association matrix. Based on the structure of the gas field gathering and transmission pipeline network, the value of the element corresponding to the inlet pipeline in the correlation matrix of the pipeline and node is set to 1.

8. A gas field gathering and transmission pipeline operating condition regulation device coupled with the characteristics of a reciprocating compressor, characterized in that, include: An auxiliary node adding unit is used to add auxiliary nodes and auxiliary pipelines to the gas field gathering and transmission pipeline network according to the structure of the gas field gathering and transmission pipeline network. The pipe segment node association matrix generation unit is used to generate a pipe segment node association matrix based on all nodes in the gas field gathering and transmission pipeline network. The pipe segment node association matrix includes information on the interconnection between pipelines and nodes. The iterative parameter calculation unit is used to calculate the pipeline friction and admittance matrix based on the basic parameters of the pipeline network including the pipeline node association matrix, as well as the set initial values ​​of pipeline flow, set initial values ​​of node temperature, and natural gas physical property parameters, and to generate a coefficient matrix. The pipeline flow calculation unit is used to obtain the nodal pressure and pipeline flow rate based on the pipeline friction, admittance matrix, set compressor speed and coefficient matrix; The node temperature calculation unit is used to perform thermal calculations on the gas field gathering and transmission pipeline network based on the pipeline flow rate to obtain the node temperature. A natural gas physical property parameter calculation unit is used to recalculate the natural gas physical property parameters based on the BWRS state equation and the node pressure and node temperature. The result verification unit is used to determine whether the difference between the pipeline flow rate and the initial value of the pipeline flow rate is less than a first threshold and whether the difference between the node temperature and the initial value of the node temperature is less than a second threshold. If not, the pipeline flow rate is used as the initial value of the pipeline flow rate, the node temperature is used as the initial value of the node temperature, and the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the initial value of the pipeline flow rate, the initial value of the node temperature, and the recalculated natural gas physical property parameters, and generating the coefficient matrix is ​​executed. If yes, the pipeline flow rate and node temperature are determined to meet the requirements based on the predetermined standard values ​​of the pipeline flow rate and node temperature. If not, the set compressor speed is changed, the set initial value of the pipeline flow rate, the set initial value of the node temperature, and the natural gas physical property parameters are reset, and the step of calculating the pipeline friction and admittance matrix based on the pipeline network basic parameters, the set initial value of the pipeline flow rate, the set initial value of the node temperature, and the natural gas physical property parameters, and generating the coefficient matrix is ​​returned, until the pipeline flow rate and node temperature meet the requirements, so as to adjust the operating conditions of the gas field basic pipeline network according to the corresponding set speed.

9. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the method of any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that, when executed by a processor, implements the method of any one of claims 1 to 7.

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