Pump set operation strategy optimization method, device and equipment of oilfield water injection system and medium

Abstract

The invention relates to the technical field of oil field water injection, and discloses a pump set operation strategy optimization method, device, equipment and medium of an oil field water injection system, which can divide a target operation time period of the oil field water injection system into a plurality of sub-time periods, and construct a pump set variable set corresponding to each sub-time period according to each sub-time period; according to the operation coupling characteristics of the main pump and the booster pump in the sub-time period, a pump set parameter coupling relation, a pump set energy consumption objective function and pump set operation constraint conditions of the oilfield water injection system are constructed, and the pump set parameter coupling relation, the pump set energy consumption objective function and the pump set operation constraint conditions are calculated based on the pump set parameter coupling relation, the pump set energy consumption objective function and the pump set operation constraint conditions; and performing particle swarm optimization iteration on the pump set variable set corresponding to each sub-period to determine an optimal pump set operation strategy. According to the optimal pump set operation strategy determined by the method, the pump set energy consumption of the oil field water injection system in the target operation time period can be reduced under the condition that different wellhead differentiation requirements are met, and the energy utilization efficiency of the oil field water injection system is effectively improved.

Description

Technical Field

[0001] The present invention relates to the technical field of oilfield water injection, and particularly to a method, device, equipment and medium for optimizing the operation strategy of a pump unit in an oilfield water injection system. Background Art

[0002] In the field of oilfield exploitation, whether it is an offshore oilfield or an onshore oilfield, the water injection system is a key means to improve the recovery rate, maintain the reservoir pressure and ensure the stable production and increased production of old oilfields.

[0003] In the oilfield water injection system of the related art, a plurality of parallel water injection pumps are provided, and water is injected into the target oilfield through the plurality of parallel water injection pumps to realize oilfield exploitation.

[0004] In the related art, the energy consumption of the water injection pump is large, resulting in a large energy consumption of the water injection system. In addition, the water injection system of the related art is difficult to flexibly adapt to the different demands of different wellheads. The low-demand wellheads need to throttle and reduce pressure through valves, causing a large amount of energy waste, while the high-demand wellheads force the system to increase the water supply pressure as a whole, further increasing the unnecessary energy consumption. There is a problem of low energy utilization efficiency in the oilfield water injection system of the related art. Summary of the Invention

[0005] The present invention provides a method, device, equipment and medium for optimizing the operation strategy of a pump unit in an oilfield water injection system, so as to solve the defect of low energy utilization efficiency of the pump unit in the oilfield water injection system in the related art and improve the energy utilization efficiency of the pump unit in the oilfield water injection system.

[0006] In a first aspect, the present invention provides a method for optimizing the operation strategy of a pump unit in an oilfield water injection system, including:

[0007] Dividing the target operation period of the oilfield water injection system into a plurality of sub-periods; wherein, the oilfield water injection system includes a plurality of parallel main pumps and a plurality of booster pumps on the first wellhead branch line;

[0008] Respectively constructing a pump unit variable set corresponding to each sub-period according to each sub-period, where the pump unit variable set corresponding to the sub-period includes the operation parameter variables of each main pump and each booster pump in the sub-period;

[0009] According to the operation coupling characteristics of the main pump and the booster pump in the sub-period, constructing a pump unit parameter coupling relationship, a pump unit energy consumption objective function and a pump unit operation constraint condition of the oilfield water injection system;

[0010] Based on the pump unit parameter coupling relationship, the pump unit energy consumption objective function and the pump unit operation constraint condition, performing particle swarm optimization iteration on the pump unit variable set corresponding to each sub-period to determine the optimal pump unit operation strategy.

[0011] Optionally, constructing the coupling relationship of pump set parameters, the pump set energy consumption objective function, and the pump set operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump during the sub-period, includes:

[0012] Based on the similarity principle of fluid machinery, constructing a relationship model between the flow rate variable, head variable, power variable, and rotational speed variable of a single pump, and using it as the coupling relationship of pump set parameters; wherein, the single pump is the main pump or the booster pump;

[0013] Constructing the pump set energy consumption objective function of the oilfield water injection system according to the operation parameter variables of each main pump and each booster pump during each sub-period;

[0014] Constructing the pump set operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump during the sub-period.

[0015] Optionally, constructing the pump set operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump during the sub-period, includes:

[0016] Constructing the flow coupling constraint between the main pump and the booster pump according to the operation coupling characteristics of each main pump and each booster pump during the sub-period, and constructing the first pressure demand constraint of each first wellhead branch line, the second pressure demand constraint of each second wellhead branch line, and the pressure constraint before the regulating valve on each wellhead branch line; wherein, the second wellhead branch line is the wellhead branch line without the booster pump in the oilfield water injection system;

[0017] Setting the rotational speed coordination constraint of each main pump and each booster pump based on the safety requirements of the single pump rotational speed;

[0018] Overall determining the flow coupling constraint between the main pump and the booster pump, each first pressure demand constraint, the second pressure demand constraint, the pressure constraint before the regulating valve, and the rotational speed coordination constraint as the pump set operation constraint conditions of the oilfield water injection system.

[0019] Optionally, performing particle swarm optimization iteration on the pump set variable set corresponding to each sub-period based on the pump set parameter coupling relationship, the pump set energy consumption objective function, and the pump set operation constraint conditions to determine the optimal pump set operation strategy, includes:

[0020] Overall taking the pump set variable set corresponding to each sub-period as the particle to be optimized in the constructed particle swarm optimization model;

[0021] Input the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions into the particle swarm optimization model, so that the particle swarm optimization model iteratively optimizes the particles to be optimized according to the set particle swarm size, maximum number of iterations, inertia weight, and learning factor until the optimal pump group operation strategy is obtained.

[0022] Optionally, the duration of each sub-period is equal.

[0023] Optionally, the pump group variable set corresponding to the sub-period includes the start-stop state variable and the rotational speed percentage variable of each main pump in the sub-period, and the start-stop state variable and the rotational speed percentage variable of each booster pump in the sub-period.

[0024] Optionally, the optimal pump group operation strategy includes the pump group operation parameter values corresponding to each sub-period, and the pump group operation parameter values corresponding to the sub-period include the start-stop state identifier and the rotational speed percentage of each main pump and each booster pump in the sub-period;

[0025] After determining the optimal pump group operation strategy, the method further includes:

[0026] For any one of the sub-periods, control the start-stop state and rotational speed of each main pump and each booster pump in the sub-period according to the pump group operation parameter values corresponding to the sub-period.

[0027] In a second aspect, the present invention provides a device for optimizing the operation strategy of a pump group in an oilfield water injection system, including:

[0028] A splitting unit for splitting the target operation period of the oilfield water injection system into multiple sub-periods; wherein, the oilfield water injection system includes a plurality of parallel main pumps and a plurality of booster pumps on the first wellhead branch line;

[0029] A first construction unit for respectively constructing a pump group variable set corresponding to each sub-period according to each sub-period, and the pump group variable set corresponding to the sub-period includes the operation parameter variables of each main pump and each booster pump in the sub-period;

[0030] A second construction unit for constructing the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump in the sub-period;

[0031] An iteration unit for performing particle swarm optimization iteration on the pump group variable set corresponding to each sub-period based on the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions to determine the optimal pump group operation strategy.

[0032] In a third aspect, the present invention provides a computer device, comprising: a memory and a processor, which are communicatively connected to each other. The memory stores computer instructions, and the processor executes the computer instructions to execute the pump group operation strategy optimization method for the oilfield water injection system according to the first aspect or any corresponding embodiment thereof.

[0033] In a fourth aspect, the present invention provides a computer-readable storage medium, on which computer instructions are stored, and the computer instructions are used to cause a computer to execute the pump group operation strategy optimization method for the oilfield water injection system according to the first aspect or any corresponding embodiment thereof.

[0034] The pump group operation strategy optimization method, device, equipment and medium provided by the present invention can divide the target operation period of the oilfield water injection system into multiple sub-periods, construct the pump group variable set corresponding to each sub-period according to each sub-period respectively, construct the pump group parameter coupling relationship, the pump group energy consumption objective function and the pump group operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump in the sub-period, and perform particle swarm optimization iteration on the pump group variable set corresponding to each sub-period based on the pump group parameter coupling relationship, the pump group energy consumption objective function and the pump group operation constraint conditions to determine the optimal pump group operation strategy. The optimal pump group operation strategy determined by the present invention can reduce the pump group energy consumption of the oilfield water injection system during the target operation period and effectively improve the energy utilization efficiency of the oilfield water injection system while meeting the different wellhead differential requirements. BRIEF DESCRIPTION OF THE DRAWINGS

[0035] In order to more clearly illustrate the technical solutions in the present invention or related technologies, the following will briefly introduce the drawings required for use in the embodiments or related technology descriptions. Obviously, the drawings in the following description are some embodiments of the present invention, and those of ordinary skill in the art can also obtain other drawings based on these drawings without creative efforts.

[0036] Figure 1 It is a flowchart of a pump group operation strategy optimization method for an oilfield water injection system provided by an embodiment of the present invention;

[0037] Figure 2 It is a flowchart of another pump group operation strategy optimization method for an oilfield water injection system provided by an embodiment of the present invention;

[0038] Figure 3 It is a structural schematic diagram of a pump group operation strategy optimization device for an oilfield water injection system provided by an embodiment of the present invention;

[0039] Figure 4 It is a structural schematic diagram of a computer device provided by an embodiment of the present invention. Specific Embodiments

[0040] To make the objectives, technical solutions, and advantages of the present invention clearer, the technical solutions in the present invention will be clearly and completely described below with reference to the accompanying drawings in the present invention. Apparently, the described embodiments are some, but not all, of the embodiments of the present invention. All other embodiments obtained by those of ordinary skill in the art based on the embodiments in the present invention without making creative efforts belong to the scope of protection of the present invention.

[0041] The following will describe Figure 1 - Figure 2 the method for optimizing the operation strategy of the pump unit in the oilfield water injection system of the present invention.

[0042] As Figure 1 shown, the first method for optimizing the operation strategy of the pump unit in the oilfield water injection system is proposed in this embodiment. The method may include the following steps:

[0043] S101. Divide the target operation period of the oilfield water injection system into multiple sub-periods; wherein, the oilfield water injection system includes multiple parallel main pumps and multiple booster pumps on the first wellhead branch lines;

[0044] Among them, the target operation period may be a certain operation period for which the operation strategy of the pump unit in the oilfield water injection system needs to be optimized. The target operation period may be a certain future operation period of the oilfield water injection system. For example, the target operation period may be the day after the day when the oilfield water injection system operates.

[0045] Optionally, the target operation period may be one hour, multiple hours, half a day, one day, or multiple days. The specific duration of the target operation period is not limited in this embodiment.

[0046] Specifically, the sub-period may be a period obtained by dividing the target operation period. Each sub-period does not overlap.

[0047] Optionally, in the method for optimizing the operation strategy of the pump unit in the oilfield water injection system proposed in this embodiment, the duration of each sub-period is equal.

[0048] Specifically, this embodiment may evenly divide the target operation period of the oilfield water injection system into multiple sub-periods with equal durations.

[0049] Optionally, this embodiment may also divide the target operation period of the oilfield water injection system into multiple sub-periods with not completely equal durations. Of course, this embodiment may also divide the target operation period of the oilfield water injection system into multiple sub-periods with unequal durations.

[0050] Among them, the main pump can be set in the central water injection station or the combined station in the oilfield water injection system, and is used to pressurize the qualified water to the high pressure required by the system (such as 5-15 MPa), and then distribute it to each water distribution room and injection well through the main pipeline network.

[0051] It should be noted that some wells in the oilfield water injection system (such as deep wells or low-permeability reservoirs) may have a high-pressure demand for the main pipeline network. At this time, in this embodiment, a booster pump can be added at the corresponding water distribution room or wellhead for these wells to perform secondary pressurization on the water coming from the main pump to meet the high-pressure demand of these wells.

[0052] Specifically, the first wellhead branch line is the wellhead branch line in the oilfield water injection system where a booster pump is added. The wellhead branch line is a pipeline configured for a single well in the oilfield water injection system to inject water into the single well. By setting the booster pump in this embodiment, the flexible control of the oilfield water injection pressure can be enhanced to meet the different pressure demands of multiple wells, that is, the refined demand of oilfield water injection can be met.

[0053] S102. Construct a pump group variable set corresponding to each sub-period according to each sub-period, and the pump group variable set corresponding to the sub-period includes the operation parameter variables of each main pump and each booster pump within the sub-period.

[0054] Specifically, in this embodiment, a pump group variable set corresponding to any sub-period can be constructed according to the sub-period.

[0055] Among them, the operation parameter variables can include variables corresponding to one or more operation parameters of the pump. For example, they can include the rotation speed variable and the start-stop state variable of the pump.

[0056] Among them, in the pump group variable set corresponding to any sub-period, the operation parameter variables of all main pumps and all booster pumps within the sub-period can be included.

[0057] Optionally, the pump group variable set corresponding to the sub-period includes the start-stop state variable and the rotation speed percentage variable of each main pump within the sub-period, and also includes the start-stop state variable and the rotation speed percentage variable of each booster pump within the sub-period.

[0058] Specifically, in the pump group variable set corresponding to any sub-period, the start-stop state variable and the rotation speed percentage variable of all main pumps within the sub-period, and the start-stop state variable and the rotation speed percentage variable of all booster pumps within the sub-period can be included.

[0059] S103. Construct the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period.

[0060] It is understandable that during the operation of the oilfield water injection system, the operating parameters of the main pump and the booster pump affect each other. In this embodiment, based on the operating characteristics of the main pump and the booster pump and the operating coupling characteristics between them, the parameter coupling relationship of the pump group in the oilfield water injection system, the pump group energy consumption objective function, and the pump group operation constraint conditions can be constructed.

[0061] Optionally, step S103 may include:

[0062] Based on the similarity principle of fluid machinery, construct a relationship model between the flow rate variable, head variable, power variable, and rotational speed variable of a single pump, and use it as the parameter coupling relationship of the pump group; where the single pump is the main pump or the booster pump;

[0063] Construct the pump group energy consumption objective function of the oilfield water injection system according to the operating parameter variables of each main pump and each booster pump in each sub-period;

[0064] Construct the pump group operation constraint conditions of the oilfield water injection system according to the operating coupling characteristics of the main pump and the booster pump in the sub-period.

[0065] Specifically, in this embodiment, based on the similarity principle of fluid machinery, a relationship model between the flow rate variable, head variable, power variable, and rotational speed variable of the main pump can be constructed, and a relationship model between the flow rate variable, head variable, power variable, and rotational speed variable of the booster pump can be constructed, and the constructed relationship models are used as a whole as the parameter coupling relationship of the pump group.

[0066] Among them, the pump group energy consumption objective function can be an objective function aiming to optimize the pump group energy consumption.

[0067] Among them, the pump group operation constraint conditions include the constraint range of the parameter values of some operating parameters of the main pump and the booster pump during the operation of the oilfield water injection system.

[0068] Optionally, the above-mentioned construction of the pump group operation constraint conditions of the oilfield water injection system according to the operating coupling characteristics of the main pump and the booster pump in the sub-period includes:

[0069] Construct the flow coupling constraint between the main pump and the booster pump according to the operating coupling characteristics of each main pump and each booster pump in the sub-period, and construct the first pressure demand constraint of each first wellhead branch line, the second pressure demand constraint of each second wellhead branch line, and the pressure constraint in front of the regulating valve on each wellhead branch line; where the second wellhead branch line is the wellhead branch line without a booster pump in the oilfield water injection system;

[0070] Based on the safety requirements of the single pump rotational speed, set the rotational speed coordination constraint of each main pump and each booster pump;

[0071] The flow coupling constraint between the main pump and the booster pump, each first pressure demand constraint, the second pressure demand constraint, the pressure constraint before the regulating valve, and the speed coordination constraint are collectively determined as the operating constraint conditions of the pump set in the oilfield water injection system.

[0072] Among them, the second wellhead branch line is the branch line where a single well in the oilfield water injection system that does not have a high-pressure demand and does not add a booster pump is located.

[0073] Specifically, the operating constraint conditions of the pump set include the flow coupling constraint between the main pump and the booster pump, the first pressure demand constraint of each first wellhead branch line, the second pressure demand constraint of each second wellhead branch line, and the pressure constraint before the regulating valve on each wellhead branch line.

[0074] S104. Based on the pump set parameter coupling relationship, the pump set energy consumption objective function, and the pump set operating constraint conditions, perform particle swarm optimization iteration on the pump set variable set corresponding to each sub-period to determine the optimal pump set operating strategy.

[0075] Specifically, in this embodiment, the pump set parameter coupling relationship, the pump set energy consumption objective function, and the pump set operating constraint conditions of the oilfield water injection system can be input into the particle swarm optimization algorithm, so that the particle swarm optimization algorithm performs particle swarm optimization iteration on the pump set variable set corresponding to each sub-period until the optimal pump set operating strategy is determined.

[0076] Optionally, step S104 may include:

[0077] Take the pump set variable set corresponding to each sub-period as a whole as the particle to be optimized in the constructed particle swarm optimization model;

[0078] Input the pump set parameter coupling relationship, the pump set energy consumption objective function, and the pump set operating constraint conditions into the particle swarm optimization model, so that the particle swarm optimization model performs iterative optimization on the particle to be optimized according to the set particle swarm size, maximum number of iterations, inertia weight, and learning factor until the optimal pump set operating strategy is obtained.

[0079] Specifically, in this embodiment, the pump set variable sets corresponding to all sub-periods can be taken as a whole as a particle to be optimized, and the particle swarm optimization algorithm is used to perform optimization iteration on the particle to be optimized with the goal of minimizing the function value of the pump set energy consumption objective function until the optimal particle is obtained. It should be noted that the optimal particle may include the pump set parameter values corresponding to each sub-period. In this embodiment, the pump set parameter values corresponding to each sub-period in the optimal particle can be taken as a whole as the optimal pump set operating strategy.

[0080] Optionally, in the method for optimizing the operation strategy of the pump unit in other oilfield water injection systems proposed in this embodiment, when the pump unit variable set corresponding to a sub-period includes the start-stop state variables and speed percentage variables of each main pump within the sub-period, and the start-stop state variables and speed percentage variables of each booster pump within the sub-period, the optimal pump unit operation strategy includes the pump unit operation parameter values corresponding to each sub-period. The pump unit operation parameter values corresponding to a sub-period include the start-stop state identifiers and speed percentages of each main pump and each booster pump within the sub-period. At this time, after step S106, the method may further include:

[0081] For any sub-period, according to the pump unit operation parameter values corresponding to the sub-period, control the start-stop states and speeds of each main pump and each booster pump within the sub-period.

[0082] It can be understood that this embodiment can control and adjust the operation parameter values of the main pump and the booster pump in different sub-periods according to the pump unit operation parameter values corresponding to different sub-periods in the optimal pump unit operation strategy, so as to control the main pump and the booster pump according to the optimal pump unit operation strategy, optimize the pump unit control, and effectively reduce the energy consumption of the pump unit.

[0083] The method for optimizing the operation strategy of the pump unit in the oilfield water injection system proposed in this embodiment can divide the target operation period of the oilfield water injection system into multiple sub-periods, respectively construct the pump unit variable set corresponding to each sub-period according to each sub-period, construct the pump unit parameter coupling relationship, the pump unit energy consumption objective function and the pump unit operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period, and perform particle swarm optimization iteration on the pump unit variable set corresponding to each sub-period based on the pump unit parameter coupling relationship, the pump unit energy consumption objective function and the pump unit operation constraint conditions to determine the optimal pump unit operation strategy, which can reduce the energy consumption of the pump unit in the target operation period of the oilfield water injection system and effectively improve the energy utilization efficiency of the oilfield water injection system while meeting the different wellhead differential requirements.

[0084] To better illustrate the construction process of the pump unit parameter coupling relationship, the pump unit energy consumption objective function and the pump unit operation constraint conditions of the oilfield water injection system, this embodiment proposes the following Example 1 and introduces it in combination with Example 1.

[0085] Example 1: This embodiment can adopt the time discretization method to divide the continuous target operation period into several sub-periods of fixed length. Let the target operation period be T, which is evenly divided into Z periods, and the length of each period is Δt. Within each sub-period, it is assumed that the wellhead demand is constant, and the start-stop states and speeds of the injection pump and the booster pump remain unchanged.

[0086] Optimize the operation strategy of the variable-frequency pump group by jointly optimizing the operation status and adjustment parameters of the equipment. Specifically, according to the physical characteristics and time-scale differences of the control objects, the decision variables are divided into the following categories:

[0087] (1) Control variables of the main pump:

[0088] Start-stop status (discrete integer variable): Define x i,t ∈{0, 1}, where x represents the start-stop status variable, i = 1, 2, …, N. i represents the main pump number, t = 1, 2, …, Z, t represents the sub-period number, and x i,t represents the start-stop status of the i-th main pump in the sub-period t. x i,t can be 0 or 1. 0 is used to identify the running state, and 1 is used to identify the shutdown state.

[0089] Speed setting (continuous variable): Define s i,t ∈[s min , s max , indicating the speed percentage of the running main pump in the sub-period t.

[0090] (2) Control variables of the booster pump:

[0091] Start-stop status (discrete integer variable): Define y j,t ∈{0, 1}, where j ∈ J represents the branch line number equipped with a booster pump. Assume there are M branch lines in total (including the branch lines equipped with booster pumps and those without booster pumps).

[0092] Speed setting (continuous variable): Define m j,t ∈[m min , m max , indicating the speed percentage of the booster pump on the branch line j in the sub-period t.

[0093] (3) Variable coupling characteristics:

[0094] Status-speed dependence constraint: When the equipment is in the shutdown state (x i,t = 0 or y j,t = 0), the corresponding speed variable automatically fails, that is:

[0095]

[0096] The control variables of the main pump and the booster pump form a two-way coupling through the pipeline network pressure equation, and the coordinated cooperation of the two-stage pump group is achieved through global optimization.

[0097] Based on the similarity principle of fluid machinery, the relationships between the flow rate (Q), head (H), power (P) and speed (n) of the variable-frequency pump are:

[0098]

[0099] Among them, Q rated 、H rated and P rated are respectively the flow rate, head, and power at the rated speed. η Q (n), η H (n), and η P (n) are respectively the efficiency correction functions dependent on the rotational speed, used to characterize the deviation between the actual pump characteristics and the ideal similarity law. To facilitate the optimization of model solution, the above relationships are transformed into explicit function forms, and the following simplified model is established:

[0100] Q i =α i s i -β i s i 2 ;

[0101] H i =γ i s i 2 -δ i Q i 2 ;

[0102] P i =o i s i 3 +ζ i Q i H i .

[0103] Among them, Q i 、H i and P i respectively represent the flow rate, head, and power of the i-th main pump. α i and β i are flow rate characteristic coefficients, reflecting the linear and non-linear components of the influence of rotational speed on the flow rate. γ i represents the rotational speed squared gain coefficient of the head, δ i represents the head loss coefficient caused by pipeline impedance, o i represents the cubic term coefficient of mechanical friction loss. ζ i represents the hydraulic power conversion efficiency coefficient.

[0104] Similarly, for the booster pump:

[0105] Q j =α j m j -β j m j 2 ;

[0106] H j =γ j m j 2 -δ j Q j 2 ;

[0107] P j =o j m j 3 +ζ j Q j H j .

[0108] Among them, Q j 、H j and P j Respectively represent the flow rate, head and power of the j-th booster pump, α j and β j γ is the flow characteristic coefficient, which reflects the linear and nonlinear components of the influence of speed on flow. j The square gain coefficient of the speed representing the lift, δ j Indicates the head loss coefficient caused by pipeline impedance, o j Represents the cubic coefficient of mechanical friction loss. ζ j Represents the hydraulic power conversion efficiency coefficient.

[0109] For parallel main pumps, the overall system characteristics need to consider the following coupling effects:

[0110]

[0111] H sys =H1(Q1)=H2(q2)=…=H N (Q N ).

[0112] Among them, q N is the total flow rate of the main pipe after the parallel pumps, h sys is the main pipe pressure, h1(q1) is the pressure after the main pump No. 1, H N (Q N ) is the pump outlet pressure of the main pump numbered N.

[0113] By dynamically adjusting the start / stop status and speed of the parallel main pump and booster pump, the system energy consumption is minimized while meeting the wellhead demand. The total energy consumption is divided into two parts: the main pump energy consumption and the booster pump energy consumption. The following relationship is established:

[0114] Pump group energy consumption objective function:

[0115]

[0116] P i,t ==o i s i,t 3 +ζ i Q i,t H i,t ;

[0117] P j,t =o i m j,t 3 +ζ j Q j,t H j,t 。

[0118] Pump group operation constraint conditions:

[0119] (1) Flow continuity constraint

[0120]

[0121] Among them, k is the branch line number, and Q k,t represents the inlet flow of the branch line numbered k within the sub-period t, represents any sub-period. This constraint means that for any sub-period, the sum of the flows of each branch line is equal to the sum of the flows of each main pump.

[0122] (2) When the branch line regulating valve changes from fully open to fully closed, the valve front pressure range is:

[0123] H k,t ∈[H sys,t , H sys,t +ρgh k .

[0124] Among them, H k,t represents the valve front pressure of the branch line regulating valve numbered k within the sub-period t. H sys,t represents the main pipe pressure within the sub-period t, ρ represents the medium density, g represents the acceleration due to gravity, and h k represents the vertical height of the branch line numbered k.

[0125] (3) Pressure balance constraint:

[0126] Pressure demand for the branch line with a booster pump:

[0127]

[0128] Among them, H k,t represents the main pipe pressure, r j represents the pipe resistance coefficient of the j-th branch line, Q j,t represents the flow of the j-th branch line within the sub-period t, Denote the frictional pressure loss of the j-th branch line during the sub-period t, y j,t H j,t Denote the pressure provided by the booster pump on the j-th branch line during the sub-period t. Denote the wellhead demand pressure of the j-th branch line during the sub-period t. This constraint means that if there is a booster pump on the branch line, the main pipe pressure minus the frictional pressure loss of the branch line plus the pressure provided by the booster pump should be greater than this wellhead demand pressure.

[0129] If there is no booster pump on the branch line, it must be naturally satisfied by the main pipe pressure:

[0130] k ∈ M and

[0131] where, Denote the frictional pressure loss of the branch line, Denote the wellhead demand pressure. This constraint means that if there is no booster pump on the branch line, the main pipe pressure minus the frictional pressure loss of the branch line should be greater than this wellhead demand pressure.

[0132] (4) Equipment operation constraints:

[0133] Speed range constraint:

[0134] s i,t ∈ [s min , s max , x i,t = 1;

[0135] s i,t = 0, x i,t = 0.

[0136] m j,t ∈ [m min , m max , y j,t = 1;

[0137] m j,t = 0, y j,t = 0.

[0138] The pumps in operation need to be adjusted within the safe speed range, and the speed is forced to zero when stopped.

[0139] Speed coordination constraint:

[0140] (i ∈ N, θ is an empirical coefficient).

[0141] Such as Figure 2As shown in the figure, this embodiment can adopt an improved particle swarm optimization algorithm (Modified Particle Swarm Optimization, MPSO), and optimize the operation strategy of the pump group through mechanisms such as dynamic inertia weight, Gaussian mutation, Cauchy perturbation, and probability position adjustment.

[0142] Specifically, in this embodiment, the particle swarm size and the maximum number of iterations can be set, the positions and velocities of each particle can be randomly initialized, the inertia weight and learning factors can be set, the fitness of each particle can be calculated according to the objective function, the historical optimal position of each particle can be updated, the global optimal position of the particle swarm can be updated, the particle velocity and position can be updated, Gaussian mutation can be performed on the particles with relatively poor fitness rankings, the fitness ranking can be calculated, and the particle probability position adjustment factor can be determined. Then, it is judged whether to randomly adjust the particle position according to the probability, Cauchy perturbation is performed on the current optimal particle, it is judged whether the number of iterations reaches the set maximum number of iterations, and whether the objective function value meets the convergence accuracy requirement. If either is satisfied, the current optimal solution can be output. Otherwise, return to execute the steps of updating the historical optimal position of each particle and updating the global optimal position of the particle swarm.

[0143] It should be noted that in the application scenario of optimizing the operation strategy of the pump group in the oilfield water injection system of this embodiment, Figure 2 a particle can represent an operation strategy of a pump group (including the operation parameter values of each main pump and each booster pump in each sub-period). The particle swarm size can represent the number of pump group operation strategies explored in parallel during each iteration. The particle fitness can represent the pump group energy consumption corresponding to the pump group operation strategy. The particle position can represent the operation parameter values in the pump group operation strategy, and the particle velocity can represent the adjustment direction and amplitude of the operation parameter values in the pump group operation strategy, which is used to update the position at the next moment. The particle historical optimal position can represent the optimal pump group operation strategy explored in history. The global optimal position of the particle swarm represents the current optimal pump group operation strategy. The particle fitness ranking represents the quality ranking of the pump group operation strategy, which is used to dynamically adjust the search weights (for example, particles with higher rankings are more inclined to local development, and those with lower rankings are more inclined to global exploration). The particle probability position represents a new strategy randomly generated through a probability distribution (such as Gaussian mutation, Cauchy perturbation), which is used to jump out of the local optimum.

[0144] The inventor of the present invention has set the following pseudocode:

[0145] The pseudocode is as follows:

[0146]

[0147]

[0148]

[0149] As shown Figure 3 in the figure, this embodiment provides an optimization device for the pump group operation strategy of an oilfield water injection system. The device may include:

[0150] A splitting unit 301, configured to split the target operation period of the oilfield water injection system into multiple sub-periods; wherein, the oilfield water injection system includes multiple parallel main pumps and multiple booster pumps on the first wellhead branch line;

[0151] A first construction unit 302, configured to construct a pump group variable set corresponding to each sub-period respectively according to each sub-period. The pump group variable set corresponding to the sub-period includes the operation parameter variables of each main pump and each booster pump within the sub-period;

[0152] A second construction unit 303, configured to construct the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period;

[0153] An iteration unit 304, configured to perform particle swarm optimization iteration on the pump group variable set corresponding to each sub-period based on the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions to determine the optimal pump group operation strategy.

[0154] It should be noted that the processing procedures and the beneficial effects brought by the splitting unit 301, the first construction unit 302, the second construction unit 303, and the iteration unit 304 can respectively refer to Figure 1 steps S101 to S104 therein, and will not be elaborated herein.

[0155] Optionally, the second construction unit 303 is further configured to:

[0156] Based on the fluid machinery similarity principle, construct a relationship model between the flow rate variable, the head variable, the power variable, and the rotational speed variable of a single pump, and use it as the pump group parameter coupling relationship; wherein, the single pump is a main pump or a booster pump;

[0157] Construct the pump group energy consumption objective function of the oilfield water injection system according to the operation parameter variables of each main pump and each booster pump within each sub-period;

[0158] Construct the pump group operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period.

[0159] Optionally, the second construction unit 303 is further configured to:

[0160] According to the operating coupling characteristics of each main pump and each booster pump within a sub-period, construct the flow coupling constraint between the main pump and the booster pump, and construct the first pressure demand constraint for each first wellhead branch line, the second pressure demand constraint for each second wellhead branch line, and the pressure constraint in front of the regulating valve on each wellhead branch line; wherein, the second wellhead branch line is the wellhead branch line without a booster pump in the oilfield water injection system.

[0161] Based on the safety requirements of the single-pump speed, set the speed coordination constraint for each main pump and each booster pump.

[0162] Overall determine the flow coupling constraint between the main pump and the booster pump, each first pressure demand constraint, the second pressure demand constraint, the pressure constraint in front of the regulating valve, and the speed coordination constraint as the pump group operation constraint conditions of the oilfield water injection system.

[0163] Optionally, the iteration unit 304 is further configured to:

[0164] Overall take the pump group variable set corresponding to each sub-period as the particle to be optimized in the constructed particle swarm optimization model.

[0165] Input the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions into the particle swarm optimization model, so that the particle swarm optimization model iteratively optimizes the particle to be optimized according to the set particle swarm size, maximum number of iterations, inertia weight, and learning factor until the optimal pump group operation strategy is obtained.

[0166] Optionally, the duration of each sub-period is equal.

[0167] Optionally, the pump group variable set corresponding to the sub-period includes the start-stop state variable and the speed percentage variable of each main pump within the sub-period, and the start-stop state variable and the speed percentage variable of each booster pump within the sub-period.

[0168] Optionally, the optimal pump group operation strategy includes the pump group operation parameter values corresponding to each sub-period, and the pump group operation parameter values corresponding to the sub-period include the start-stop state identifier and the speed percentage of each main pump and each booster pump within the sub-period.

[0169] The above device further includes:

[0170] A control unit, configured to, after determining the optimal pump group operation strategy, for any sub-period, control the start-stop state and speed of each main pump and each booster pump within the sub-period according to the pump group operation parameter values corresponding to the sub-period.

[0171] The pump group operation strategy optimization device for the oilfield water injection system proposed in this embodiment can divide the target operation period of the oilfield water injection system into multiple sub-periods, construct the pump group variable set corresponding to each sub-period according to each sub-period respectively, construct the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions based on the operation coupling characteristics of the main pump and the booster pump in the sub-period, and perform particle swarm optimization iteration on the pump group variable set corresponding to each sub-period based on the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions to determine the optimal pump group operation strategy, which can reduce the pump group energy consumption of the oilfield water injection system during the target operation period and effectively improve the energy utilization efficiency of the oilfield water injection system while meeting the different wellhead differential requirements.

[0172] The pump group operation strategy optimization device for the oilfield water injection system in this embodiment is presented in the form of functional units. Here, the unit refers to an ASIC (Application Specific Integrated Circuit) circuit, a processor and a memory that execute one or more software or fixed programs, and / or other devices that can provide the above functions.

[0173] The embodiment of the present invention also provides a computer device having the above Figure 3 shown pump group operation strategy optimization device for the oilfield water injection system.

[0174] Please refer to Figure 4 , a schematic structural diagram of a computer device provided by an alternative embodiment of the present invention. The computer device includes: one or more processors 10, a memory 20, and interfaces for connecting various components, including a high-speed interface and a low-speed interface. Each component communicates with each other using different buses and can be installed on a common main board or installed in other ways as needed. The processor can process instructions executed within the computer device, including instructions stored in the memory or on the memory to display graphical information of the GUI on an external input / output device (such as a display device coupled to the interface). In some alternative embodiments, if necessary, multiple processors and / or multiple buses can be used together with multiple memories. Similarly, multiple computer devices can be connected, and each device provides some necessary operations (such as an array of servers, a set of blade servers, or a multi-processor system). Figure 4 Take one processor 10 as an example in

[0175] The processor 10 may be a central processing unit, a network processor, or a combination thereof. Among them, the processor 10 may further include a hardware chip. The above-mentioned hardware chip may be an application-specific integrated circuit, a programmable logic device, or a combination thereof. The above-mentioned programmable logic device may be a complex programmable logic device, a field-programmable gate array, a generic array logic, or any combination thereof.

[0176] Among them, the memory 20 stores instructions that can be executed by at least one processor 10, so that at least one processor 10 executes the method shown in the above embodiments.

[0177] The memory 20 may include a program storage area and a data storage area. Among them, the program storage area can store an operating system and application programs required for at least one function. The data storage area can store data created according to the use of the computer device, etc. In addition, the memory 20 may include a high-speed random access memory, and may further include a non-transitory memory, such as at least one disk storage device, a flash memory device, or other non-transitory solid-state storage devices. In some alternative embodiments, the memory 20 may optionally include a memory remotely provided with respect to the processor 10, and these remote memories can be connected to the computer device through a network. Examples of the above-mentioned network include, but are not limited to, the Internet, an enterprise intranet, a local area network, a mobile communication network, and combinations thereof.

[0178] The memory 20 may include a volatile memory, such as a random access memory. The memory may also include a non-volatile memory, such as a flash memory, a hard disk, or a solid-state drive. The memory 20 may further include a combination of the above-mentioned types of memories.

[0179] The computer device further includes a communication interface 30 for the computer device to communicate with other devices or communication networks.

[0180] The embodiments of the present invention also provide a computer-readable storage medium. The method according to the embodiments of the present invention can be implemented in hardware, firmware, or be implemented as computer code that can be recorded on a storage medium, or be implemented as computer code originally stored in a remote storage medium or a non-transitory machine-readable storage medium and downloaded through a network and will be stored in a local storage medium, so that the method described herein can be stored in such software processed on a storage medium using a general-purpose computer, a dedicated processor, or programmable or dedicated hardware. Among them, the storage medium can be a magnetic disk, an optical disk, a read-only memory, a random access memory, a flash memory, a hard disk, or a solid-state drive, etc.; further, the storage medium can also include a combination of the above-mentioned types of memories. It can be understood that a computer, a processor, a microprocessor controller, or programmable hardware includes a storage component that can store or receive software or computer code, and when the software or computer code is accessed and executed by the computer, the processor, or the hardware, the method shown in the above embodiments is implemented.

[0181] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit them; although the present invention has been described in detail with reference to the foregoing embodiments, those of ordinary skill in the art should understand that they can still modify the technical solutions described in the foregoing embodiments, or perform equivalent replacements for some of the technical features; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the spirit and scope of the technical solutions of the embodiments of the present invention.

Claims

1. An optimization method for the operation strategy of the pump unit in an oilfield water injection system, characterized in that, Including: Dividing the target operation period of the oilfield water injection system into multiple sub-periods; wherein, the oilfield water injection system includes multiple parallel main pumps and multiple booster pumps on multiple first wellhead branch lines; Constructing a pump group variable set corresponding to each sub-period respectively according to each sub-period, and the pump group variable set corresponding to the sub-period includes operation parameter variables of each main pump and each booster pump within the sub-period; Constructing a pump group parameter coupling relationship, a pump group energy consumption objective function and a pump group operation constraint condition of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period; Based on the pump group parameter coupling relationship, the pump group energy consumption objective function and the pump group operation constraint condition, performing particle swarm optimization iteration on the pump group variable set corresponding to each sub-period to determine the optimal pump group operation strategy.

2. The method according to claim 1, characterized in that The constructing the pump group parameter coupling relationship, the pump group energy consumption objective function and the pump group operation constraint condition of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period includes: Based on the similarity principle of fluid machinery, constructing a relationship model between the flow rate variable, head variable, power variable and rotational speed variable of a single pump, and taking it as the pump group parameter coupling relationship; wherein, the single pump is the main pump or the booster pump; Constructing the pump group energy consumption objective function of the oilfield water injection system according to the operation parameter variables of each main pump and each booster pump within each sub-period; Constructing the pump group operation constraint condition of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period.

3. The method according to claim 2, wherein The constructing the pump group operation constraint condition of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump within the sub-period includes: Constructing a flow coupling constraint between the main pump and the booster pump according to the operation coupling characteristics of each main pump and each booster pump within the sub-period, and constructing a first pressure demand constraint for each first wellhead branch line, a second pressure demand constraint for each second wellhead branch line and a pressure constraint in front of the regulating valve on each wellhead branch line; wherein, the second wellhead branch line is the wellhead branch line without the booster pump in the oilfield water injection system; Setting a rotational speed coordination constraint for each main pump and each booster pump based on the safety requirement of the single pump rotational speed; Overall determining the flow coupling constraint between the main pump and the booster pump, each first pressure demand constraint, the second pressure demand constraint, the pressure constraint in front of the regulating valve and the rotational speed coordination constraint as the pump group operation constraint condition of the oilfield water injection system.

4. The method according to claim 1, wherein The performing particle swarm optimization iteration on the pump group variable set corresponding to each sub-period based on the pump group parameter coupling relationship, the pump group energy consumption objective function and the pump group operation constraint condition to determine the optimal pump group operation strategy includes: Taking the pump group variable set corresponding to each sub-period as a particle to be optimized in the constructed particle swarm optimization model; Input the coupling relationship of the pump group parameters, the pump group energy consumption objective function, and the pump group operation constraint conditions into the particle swarm optimization model, so that the particle swarm optimization model iteratively optimizes the particles to be optimized according to the set particle swarm size, maximum number of iterations, inertia weight, and learning factor until the optimal pump group operation strategy is obtained.

5. The method according to claim 1, wherein The duration of each sub-period is equal.

6. The method according to claim 1, wherein The pump group variable set corresponding to the sub-period includes the start-stop state variable and the rotational speed percentage variable of each main pump during the sub-period, and the start-stop state variable and the rotational speed percentage variable of each booster pump during the sub-period.

7. The method according to claim 6, characterized in that, The optimal pump group operation strategy includes the pump group operation parameter values corresponding to each sub-period, and the pump group operation parameter values corresponding to the sub-period include the start-stop state identifier and the rotational speed percentage of each main pump and each booster pump during the sub-period; After determining the optimal pump group operation strategy, the method further includes: For any one of the sub-periods, control the start-stop state and rotational speed of each main pump and each booster pump during the sub-period according to the pump group operation parameter values corresponding to the sub-period.

8. An optimization device for the operation strategy of a pump unit in an oilfield water injection system, characterized in that, Includes: A segmentation unit for segmenting the target operation period of the oilfield water injection system into multiple sub-periods; wherein, the oilfield water injection system includes multiple parallel main pumps and multiple booster pumps on the first wellhead branch line; A first construction unit for respectively constructing the pump group variable set corresponding to each sub-period according to each sub-period, and the pump group variable set corresponding to the sub-period includes the operation parameter variables of each main pump and each booster pump during the sub-period; A second construction unit for constructing the coupling relationship of the pump group parameters, the pump group energy consumption objective function, and the pump group operation constraint conditions of the oilfield water injection system according to the operation coupling characteristics of the main pump and the booster pump during the sub-period; An iteration unit for performing particle swarm optimization iteration on the pump group variable set corresponding to each sub-period based on the pump group parameter coupling relationship, the pump group energy consumption objective function, and the pump group operation constraint conditions to determine the optimal pump group operation strategy.

9. A computer device, characterized in that, Includes: A memory and a processor, which are communicatively connected to each other. The memory stores computer instructions, and the processor executes the computer instructions to execute the pump group operation strategy optimization method of the oilfield water injection system according to any one of claims 1 to 7.

10. A computer-readable storage medium, characterized in that, Computer instructions are stored on the computer-readable storage medium, and the computer instructions are used to cause a computer to execute the pump group operation strategy optimization method of the oilfield water injection system according to any one of claims 1 to 7.

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