A multi-strategy coordinated regional power grid fast safety correction method and system

Abstract

The application discloses a kind of multi-strategy coordinated regional power grid fast security correction method, system, the method includes: the power grid range and calculation period of carrying out regional power grid security correction are obtained;Carry out security check calculation, analyze flow overrun condition;Determine the provincial power grid participating in security correction, identify effective constraint;Build security correction model considering unit output adjustment, optimize and adjust unit output;If still exist overrun, build time period merging security correction model considering unit output-start-stop-inter-provincial port-sub-area external DC adjustment, determine unit start-stop state;The unit start-stop state of time period merging is assigned to full time period and fixed, build full time period security correction model of unit output-inter-provincial port-sub-area external DC adjustment, eliminate flow overrun;Carry out security check and security correction iterative calculation, obtain the correction result satisfying regional power grid security.The application provides technical support for regional power grid supply guarantee and consumption promotion under the environment of power spot market.

Description

TECHNICAL FIELD

[0001] The application belongs to the field of power system dispatching automation, and particularly relates to a multi-strategy coordinated regional power grid fast and safe correction method and system. BACKGROUND

[0002] Under the traditional three-public dispatching mode, each provincial power grid is responsible for formulating its own day-ahead and intra-day generation plans, and seven categories of data are reported to the regional power grid. The regional power grid performs overall network safety checking based on the provincial boundary data. When there is equipment over-limit in the regional power grid, the regional power grid safety correction is further performed. Since the unit start-stop state is fixed in advance under the traditional three-public dispatching mode, the provincial inter-district and district-outside tie-line plans are fixed parameters. Therefore, the traditional safety correction model only adjusts the unit output, the mathematical model type is a safety constraint economic dispatching model, the solving difficulty is small, and the calculation speed is fast.

[0003] With the rapid advancement of the construction of new power systems and electricity spot markets, the proportion of wind, light and new energy and flexible adjustment resources gradually increases, showing characteristics such as market subject diversification, transaction variety diversification, adjustment resource massification, decision-making globalization, and application scenario complication. Higher requirements are put forward for efficient solution of the clearing algorithm, safe and stable power supply, and maximum consumption of new energy. The complexity and importance of regional power grid safety correction are comprehensively improved. The adjustment resources of the regional power grid safety correction are changed from the traditional unit output to the unit output, unit start-stop, provincial inter-district highway, and district-outside DC plan. The mathematical model type is changed from the traditional safety constraint economic dispatching to the safety constraint unit combination and economic dispatching considering multiple, multiple transaction varieties, and complex operation mode. The solving variables and constraint conditions increase from hundreds of thousands to more than one million, the solving difficulty is greatly improved, and the calculation performance cannot be guaranteed. SUMMARY

[0004] The purpose of the present application is to provide a strategy coordinated regional power grid fast and safe correction method and system. On the one hand, the scheme provides technical support for regional power grid supply guarantee and consumption promotion in the electricity spot market environment. On the other hand, it solves the defect that the calculation performance of the prior art cannot meet the practical requirements of regional power grid safety correction.

[0005] Technical solution: A multi-strategy coordinated regional power grid fast and safe correction method according to the present application comprises:

[0006] Obtaining boundary data and calculation period for performing regional power grid safety correction from a regional and provincial power grid D5000 or a new generation of dispatching and control system, and generating a safety correction calculation scenario of the regional power grid;

[0007] Performing regional power grid safety checking calculation based on the safety correction calculation scenario of the regional power grid, and analyzing the over-limit condition of the power flow in each provincial power grid in the regional power grid;

[0008] If there is an equipment / section out-of-limit in the regional power grid, the effective equipment / section of the regional power grid safety correction is identified according to the power flow result of the equipment / section; and the provincial power grid participating in the regional power grid safety correction is determined according to the effective equipment / section, so as to narrow the safety correction adjustment range and improve the calculation efficiency of the safety correction in the subsequent steps;

[0009] The safety correction model of the regional power grid is constructed with the unit output of the provincial power grid participating in the regional power grid safety correction as the decision variable, and the unit output of the provincial power grid participating in the regional power grid safety correction is adjusted by using the safety constrained economic dispatch algorithm based on the safety correction model considering the unit output adjustment, so as to eliminate the equipment / section power flow out-of-limit;

[0010] If the safety correction model considering the unit output adjustment cannot eliminate the equipment / section out-of-limit, the time period merging safety correction model of the regional power grid is constructed with the unit output, unit start-stop, inter-provincial port plan and external tie-line plan as the decision variable, and the unit start-stop state is calculated by adjusting the decision variable in sequence based on the time period merging safety correction model and using the safety constrained unit combination algorithm;

[0011] The all-time period safety correction model of the regional power grid is established based on the unit start-stop state calculated by the time period merging safety correction model considering the unit output-start-stop-inter-provincial port-external DC adjustment, and the unit output, inter-provincial port plan and external tie-line plan are optimized in sequence based on the all-time period safety correction model and using the safety constrained economic dispatch algorithm, so as to eliminate the equipment / section power flow out-of-limit;

[0012] Based on the calculation result of the all-time period safety correction model considering the unit output-inter-provincial port-external DC adjustment, the regional power grid safety check calculation is carried out, the equipment / section power flow out-of-limit of the regional power grid is analyzed, and if there is a new out-of-limit equipment / section, it is added to the safety correction model considering the unit output adjustment, and the final correction result meeting the safety of the regional power grid is obtained through iterative calculation.

[0013] Further, the boundary data of the scenario generation includes provincial power grid system data, unit data, tie-line data, load data and unit group data; and the calculation period is the shortest dispatching period of the provincial power grid under the regional power grid.

[0014] Further, the power grid safety analysis adopts the calculation strategy of provincial balance, and the power flow and the sensitivity are calculated at the same time, the power flow is used to analyze the equipment / section power flow out-of-limit of the power grid, and the sensitivity is used to construct the safety correction optimization model.

[0015] Further, the effective section of the effective constraint identification is the power transmission section that will restrict the unit operation in the power grid operation, and the identification method is as follows:

[0016] According to the relationship between the power flow result F of the power transmission section s,t and the physical power transmission limit P of the power transmission section max,s , the function type of the power transmission section is divided:

[0017] If |F s,t | < σ*P max,s , the power transmission section s is an invalid section at time period t;

[0018] If |F s,t | ≥ σ*P max,s , the power transmission section s is an effective section at time period t;

[0019] In the formula, σ is the function constraint judgment coefficient;

[0020] The judgment method of the participating adjustment province is as follows:

[0021] If the effective device / section is a provincial device / section, the province of the device / section independently participates in adjustment;

[0022] If the effective device / section is an inter-provincial device / section, the provinces connected with the device / section all participate in adjustment.

[0023] Further, the security correction model considering unit output adjustment only optimizes unit output, and the unit start-stop state, inter-provincial port plan and out-of-area tie line plan are all known parameters, which are based on the data reported by the provincial power grid;

[0024] The optimization objective function of the security correction model considering unit output adjustment is as follows:

[0025]

[0026] In the formula, N is the total number of units; T is the total time considered for calculation; NS is the total number of devices / sections; ΔP i,t represents the output adjustment amount of unit i at time t; M p is the penalty factor of unit output adjustment; M b is the penalty factor for generation and consumption balance constraint; M s is the penalty factor of device / section s at time t; and are respectively the positive and negative relaxation variables of the generation and consumption balance constraint at time t; and are respectively the positive and negative power flow relaxation variables of device / section s at time t; and are respectively the positive and negative relaxation variables of the generation and consumption balance constraint at time t;

[0027] The constraint conditions of the security correction model considering unit output adjustment include provincial balance constraint, unit output adjustment amount, upper and lower limits of unit output, unit output creep and slope, and power grid safety constraint.

[0028] Provincial balance constraints:

[0029] The total generation of each province is equal to the difference between the short-term load forecast and the inter-provincial exchange power, as shown in the following equation:

[0030]

[0031] where P i,t represents the output of unit i at time t, which is a decision variable; is the set of units in province a; represents the initial inter-provincial exchange power plan of province a at time t; D a,t is the system load of province a at time t;

[0032] Definition of unit output adjustment:

[0033]

[0034] where: is the unit i output plan reported by the province at time t, and is the market clearing result of each provincial power grid; ΔP i,t is the unit i output plan adjustment at time t;

[0035] Upper and lower limits of unit output constraints:

[0036]

[0037] where U i,t is the start-stop state of unit i at time t, if the unit is stopped, U i,t = 0, through this constraint, the unit output can be limited to 0, when the unit is started, U i,t = 1, this constraint is the conventional upper and lower limits of output constraints; is the minimum technical output of unit i at time t; is the maximum technical output of unit i at time t;

[0038] Unit output ramping constraints:

[0039]

[0040] where, is the maximum upward ramping of unit i, is the maximum downward ramping of unit i; when the unit is at the start time, the unit's upward output range is determined by the allowed start rate of the unit, η i,t is the unit start integer variable, η i,t = 1 means that unit i is started at time t; when the unit is at the stop time, the unit's downward output range is determined by the allowed stop rate of the unit; γi,t On integer variable, γ i,t = 1 for unit i is off at time t.

[0041] Power transmission equipment power flow constraints:

[0042] The security correction model and the cross-section power flow constraints of the first iteration of the security check can be described as:

[0043]

[0044] The security correction model and the cross-section power flow constraints of the second iteration and subsequent iterations of the security check can be described as:

[0045]

[0046] In the formula, P i,t is the active power of unit i at time t; is the active power of unit i at the previous iteration at time t; D k,t is the bus load value of node k at time t; are the positive and negative power flow transmission limits of equipment / cross-section s, respectively; G s-i is the generator output power transfer distribution factor of the node where unit i is located to equipment / cross-section s; G s-k is the output power transfer distribution factor of node k to equipment / cross-section s; G s-j is the output power transfer distribution factor of the node where tie line j is located to equipment / cross-section s; are the positive and negative power flow relaxation variables of equipment / cross-section s, respectively; is the AC power flow of equipment / cross-section s at the previous iteration at time t.

[0047] Further, the period merging security correction model considering unit output-start-stop-interzone port adjustment and external DC adjustment includes the following steps of period merging:

[0048] Let L t be the system load at time t, then the system load change rate of adjacent time periods t and t+1 is:

[0049]

[0050] Calculate the system load change rate for all time periods, find the minimum change rate ΔL t corresponding to the time period;

[0051] Merge time periods t and t+1 into a new time period;

[0052] The minimum change rate ΔL tIf the condition is satisfied, the time period merging is completed, otherwise, the system load change rate of adjacent time periods t and t+1 is recalculated.

[0053] Further, the optimization objective function of the time period merging security correction model considering unit output-start-stop-inter-province gap-outside DC adjustment is expressed as:

[0054]

[0055] In the formula, N is the total number of units; T is the total number of time periods after security correction time period merging; NS is the total number of devices / sections; DN is the total number of DC tie lines; NT is the province / city set; ΔP i,t represents the output adjustment amount of unit i at time t; ΔP d,t represents the planned adjustment amount of DC tie line d at time t; represents the start-stop state of unit i at time period t reported by each province / city; U i,t represents the start-stop state of unit i at time period t after calculation; represents the originally planned inter-province exchange power at time period t of province a; T a,t represents the inter-province exchange power plan at time period t of province a after calculation; M d represents the penalty factor of DC tie line planned adjustment amount; M a represents the penalty factor of inter-province exchange power plan adjustment; M p represents the penalty factor of unit output adjustment; M u represents the penalty factor of unit start-stop change; M b represents the penalty factor for generation and consumption balance constraint; M s represents the penalty factor of device / section s at time t; respectively represent the positive and negative relaxation variables of generation and consumption balance constraint at time t; respectively represent the positive and negative power flow relaxation variables of device / section s at time t.

[0056] Further, the optimization objective function of the time period merging security correction model considering unit output-start-stop-inter-province gap-outside DC adjustment contains multiple penalty factors, wherein the order from large to small of each penalty factor is as follows: balance constraint relaxation penalty factor M b , grid security constraint relaxation penalty factor M s , DC tie line planned adjustment amount penalty factor M d , inter-province exchange power plan adjustment penalty factor M a , unit start-stop change penalty factor M u , unit output adjustment penalty factor M p , which are adjusted in order from large to small.

[0057] Furthermore, in the process of constructing a period-merged safety correction model that takes into account unit output, start-up and shutdown, inter-provincial ports, and DC adjustments outside the region, the following model constraints need to be established:

[0058] Provincial balance constraints:

[0059] After the inter-provincial port plan and the inter-regional connection line plan are adjusted, the provincial balance constraints are modified to:

[0060]

[0061] Where, P i,t represents the output of unit i at time t, the decision variable; is the set of units in province a; T a,t represents the inter-provincial exchange power of province a at time t; D a,t is the system load of province a at time t;

[0062] Minimum continuous start and stop time constraints for units:

[0063]

[0064] Where, T U 、T D The minimum continuous start time and minimum continuous stop time of the unit; The time that the unit i has been continuously started and stopped during period t can be expressed as the state variable U i,t To express:

[0065]

[0066] Unit startup and shutdown switching variable constraints:

[0067]

[0068]

[0069] Where η i,t is the unit startup integer variable, η i,t =1 means the unit i is started during period t; when the unit is shut down, γ i,t is the unit startup integer variable, γ i,t =1 means the unit i is shut down during period t and the following conditions are met:

[0070]

[0071] Inter-provincial exchange plan power balance constraints:

[0072] The adjustment amount of inter-provincial exchange power of each province in the region should satisfy that the cumulative amount of inter-provincial exchange power change is equal to the amount of DC change outside the region, and the specific expression is as follows:

[0073]

[0074] The DC transmission plan adjustment amount is defined as follows:

[0075]

[0076] In the formula, P is the initial transmission plan of the DC transmission channel d at time t; P d,t is the active power of the DC transmission channel d at time t;

[0077] The DC tie-line power inter-provincial distribution constraint is as follows:

[0078] After the DC power is connected to the grid at the DC converter station, the DC power is distributed to each province and city according to a certain proportion, and the following constraint is satisfied:

[0079]

[0080] In the formula, r d,a is the power distribution factor of the DC transmission channel d to the province a; ΔDT a,t represents the inter-provincial exchange power change amount of the province a under the jurisdiction of the sub-center at time t caused by the DC change outside the region; the distribution factor should satisfy the following condition:

[0081]

[0082] The DC tie-line power limit constraint is as follows:

[0083] Due to the physical performance of the DC tie-line, the DC tie-line plan power cannot exceed the allowed maximum value and be lower than the allowed minimum value, and the following constraint is satisfied:

[0084]

[0085] In the formula, is the minimum power limit of the DC tie-line d at time t; is the maximum power limit of the DC tie-line d at time t;

[0086] The DC tie-line power converter station distribution constraint is as follows:

[0087] After the DC power is connected to the grid at the DC converter station, the DC power is distributed to each province and city according to a certain proportion, and the following constraint is satisfied:

[0088]

[0089] In the formula, v d,hPower distribution factor of DC transmission channel d to converter station h; Δp h,t represents the power plan adjustment amount of the converter station; the distribution factor needs to satisfy the following conditions:

[0090]

[0091] Further, the all-time period safety correction model considering unit output-provincial interconnection substation-out-of-province DC adjustment takes the unit operation state calculated by the time period merging safety correction model considering unit output-start-stop-provincial interconnection substation-out-of-province DC adjustment as the standard, assigns the unit operation state of the merged time period to the all-time period and fixes it as a known parameter, and only adjusts the unit output, provincial interconnection substation plan and out-of-province DC plan; the constraints related to the unit operation state are eliminated.

[0092] Further, based on the calculation result of the all-time period safety correction model considering unit output-provincial interconnection substation-out-of-province DC adjustment, regional power grid safety checking calculation is carried out, the over-limit equipment / section flow of the regional power grid is analyzed, and if there is new over-limit equipment / section, it is added to the safety correction model considering unit output adjustment, and through iterative calculation, the correction result satisfying the safety of the regional power grid is finally obtained, including:

[0093] The safety checking adopts alternating current flow calculation method to analyze the over-limit equipment / flow of the regional power grid after safety correction, and sends the new over-limit equipment / section and over-limit time period to safety correction;

[0094] The iterative calculation of safety correction and safety checking is carried out until there is no over-limit equipment / section in the regional power grid or the maximum number of iterations is reached.

[0095] Based on the same inventive concept, a multi-strategy coordinated regional power grid fast safety correction system of the present application comprises:

[0096] A scene generation module is configured to obtain boundary data and calculation period for carrying out regional power grid safety correction from the regional and provincial power grid D5000 or new generation dispatching and control system, and generate a safety correction calculation scene of the regional power grid;

[0097] A power grid safety analysis module is configured to carry out regional power grid safety checking calculation based on the safety correction calculation scene of the regional power grid, and analyze the over-limit equipment / section flow of each provincial power grid in the regional power grid;

[0098] An identification module is configured to identify effective equipment / section and determine the provinces participating in adjustment; if there is over-limit equipment / section in the regional power grid, the effective section of the regional power grid safety correction is identified according to the flow result of the transmission section; and the provincial power grid participating in the regional power grid safety correction is determined according to the effective equipment / section, the adjustment range of the safety correction is narrowed, and the calculation efficiency of the safety correction in the subsequent steps is improved.

[0099] A safety correction model model construction module is configured to construct a safety correction model of a regional power grid with unit output of a provincial power grid participating in safety correction of the regional power grid as a decision variable, and based on the safety correction model, to adjust the unit output of the provincial power grid participating in safety correction of the regional power grid by using a safety constraint economic dispatch algorithm to eliminate over-limit of equipment / section power flow;

[0100] A time period merging safety correction model construction module is configured to, in case that the safety correction model considering unit output adjustment cannot eliminate over-limit of equipment / section, construct a time period merging safety correction model of the regional power grid with unit output, unit start-stop, inter-provincial port plan and out-of-area tie-line plan as decision variables, and based on the time period merging safety correction model, to adjust each decision variable in sequence by using a safety constraint unit combination algorithm to eliminate over-limit of power flow;

[0101] A full time period safety correction model construction module is configured to, based on unit start-stop state calculated by the time period merging safety correction model considering unit output-start-stop-inter-provincial port-out-of-area DC adjustment, establish a full time period safety correction model of the regional power grid, and based on the full time period safety correction model, to optimize unit output, inter-provincial port plan and out-of-area tie-line plan in sequence by using a safety constraint economic dispatch algorithm to eliminate over-limit of power flow;

[0102] An iterative calculation module is configured to, based on calculation result of the full time period safety correction model considering unit output-inter-provincial port-out-of-area DC adjustment, carry out regional safety checking calculation, analyze over-limit of equipment / section power flow of the regional power grid, and add newly added over-limit equipment / section to the safety correction model considering unit output adjustment to re-carry out safety correction optimization solution, and through iterative calculation, finally obtain correction result meeting safety of the regional power grid.

[0103] Further, the boundary data of the scenario generation includes provincial power grid system data, unit data, tie-line data, load data and unit group data; and the calculation period is the shortest dispatching period of the regional power grid under jurisdiction of the provincial power grid.

[0104] Further, the power grid safety analysis adopts a calculation strategy of provincial balance, and simultaneously calculates power flow and sensitivity; the power flow is used for analyzing over-limit of power flow of the power grid, and the sensitivity is used for constructing a safety correction optimization model.

[0105] Further, the effective section of the effective constraint identification is a power transmission section that will restrict unit operation in power grid operation, and the identification method is as follows:

[0106] According to the relationship between power flow result F of the power transmission section s,t and physical power transmission limit value P of the power transmission section max,s , the function type of the power transmission section is divided.

[0107] If |F s,t |<σ*P max,s , then the transmission section s is an invalid section at time period t;

[0108] If |F s,t |≥σ*P max,s , then the transmission section s is an effective section at time period t;

[0109] wherein σ is an effective constraint judgment coefficient;

[0110] The judgment method of the participating adjustment provinces is as follows:

[0111] If the effective device / section is a provincial device / section, then the province of the device / section independently participates in adjustment;

[0112] If the effective device / section is an inter-provincial device / section, then the provinces connected with the device / section all participate in adjustment.

[0113] Further, the security correction model considering unit output adjustment only optimizes unit output, and the unit start-stop state, inter-provincial port planning and out-of-area tie-line planning are all known parameters, which are based on the data reported by the provincial power grid;

[0114] The optimization objective function of the security correction model considering unit output adjustment is as follows:

[0115]

[0116] wherein N is the total number of units; T is the total number of time periods considered for calculation; NS is the total number of devices / sections; ΔP i,t represents the output adjustment amount of unit i at time t; M p is a penalty factor of unit output adjustment; M b is a penalty factor for generation and consumption balance constraint; M s is a penalty factor of device / section s at time t; respectively are positive and negative slack variables of generation and consumption balance constraint at time t; respectively are positive and negative power flow slack variables of device / section s at time t; respectively are positive and negative slack variables of generation and consumption balance constraint at time t;

[0117] The constraint conditions of the security correction model considering unit output adjustment include provincial balance constraint, unit output adjustment amount, upper and lower limits of unit output, unit output creep and slope, and power grid safety constraint; wherein:

[0118] Provincial balance constraint:

[0119] The total power of units in each province equals the difference between the short-term load forecasting value of the provincial system and the inter-provincial exchange power, as shown in the following formula:

[0120]

[0121] P i,t represents the power of unit i at time t; is the set of units in province a; represents the initial inter-provincial exchange power plan of province a at time t; D a,t is the system load of province a at time t;

[0122] The unit power adjustment amount is defined as:

[0123]

[0124] In the formula: is the power plan of unit i at time t reported by the province, and is the market clearing result of each provincial power grid; ΔP i,t is the power plan adjustment amount of unit i at time t;

[0125] The upper and lower limits of unit power are constrained as:

[0126]

[0127] In the formula, U i,t is the start-stop state of unit i at time t, if the unit is stopped, U i,t = 0, through this constraint condition, the unit power can be limited to 0, when the unit is started, U i,t = 1, this constraint condition is the conventional upper and lower limit constraint of power; is the minimum technical power of unit i at time t; is the maximum technical power of unit i at time t;

[0128] The unit power ramping constraint is:

[0129]

[0130] In the formula, is the maximum upward ramping amount of unit i, is the maximum downward ramping amount of unit i; when the unit is at the start time, the ascending power range of the unit is determined by the allowed start rate of the unit, η i,t is the unit start integer variable, η i,t = 1 means that unit i is started at time t; when the unit is at the stop time, the descending power range of the unit is determined by the allowed stop rate of the unit; γ i,t is the unit start integer variable, γ i,t = 1 means that unit i is stopped at time t.

[0131] Power transmission equipment / sectional power flow constraints:

[0132] The security correction model and the equipment / sectional power flow constraints of the first round of iteration of the security check can be described as:

[0133]

[0134] The security correction model and the equipment / sectional power flow constraints of the second round and subsequent iterations of the security check can be described as:

[0135]

[0136] In the formula, P i,t is the active power of unit i in period t; is the active power of unit i in the previous round in period t; D k,t is the bus load value of node k in period t; are respectively the positive and negative power flow transmission limits of equipment / section s; G s-i is the generator output power transfer distribution factor of unit i to equipment / section s; G s-k is the output power transfer distribution factor of node k to equipment / section s; G s-j is the output power transfer distribution factor of the node where the tie line j is located to equipment / section s; are respectively the positive and negative power flow relaxation variables of equipment / section s; is the AC power flow of equipment / section s in the previous round of security correction in period t.

[0137] Further, the period merging security correction model considering unit output-start-stop-inter-regional port-outside DC adjustment, the period merging method of which comprises the following steps:

[0138] Let L t be the system load in period t, then the system load change rate of adjacent periods t and t+1 is:

[0139]

[0140] Calculate the system load change rate of all periods, find the minimum change rate ΔL t corresponding to the period;

[0141] Merge periods t and t+1 into a new period;

[0142] Whether the minimum change rate ΔL t is greater than the set threshold, or whether the number of periods left after merging reaches the preset number, the determination condition takes effect, then the period merging is completed, otherwise, recalculate the system load change rate of adjacent periods t and t+1.

[0143] Further, the objective function of the time period merging security correction model considering unit output-start-stop-inter-province gap-outside DC adjustment is expressed as:

[0144]

[0145] In the formula, N is the total number of units; T is the total number of time periods after security correction time period merging; NS is the total number of devices / sections; DN is the total number of DC tie lines; NT is the province / city set; ΔP i,t represents the output adjustment amount of unit i at time t; ΔP d,t is the planned adjustment amount of DC tie line d at time t; is the start-stop state of unit i at time period t reported by each province / city; U i,t is the start-stop state of unit i at time period t after calculation; is the originally planned inter-province exchange power at time period t of province a; T a,t is the inter-province exchange power plan at time period t of province a after calculation; M d is the penalty factor of DC tie line planned adjustment; M a is the penalty factor of inter-province exchange power plan adjustment; M p is the penalty factor of unit output adjustment; M u is the penalty factor of unit start-stop change; M b is the penalty factor for generation and consumption balance constraint; M s is the penalty factor of device / section s at time t; are the positive and negative relaxation variables of generation and consumption balance constraint at time t, respectively; are the positive and negative power flow relaxation variables of device / section s at time t, respectively.

[0146] Further, the optimization objective function of the time period merging security correction model considering unit output-start-stop-inter-province gap-outside DC adjustment contains multiple penalty factors, and the order from large to small is: the balance constraint relaxation penalty factor M b , the grid security constraint relaxation penalty factor M s , the DC tie line planned adjustment penalty factor M d , the inter-province exchange power plan adjustment penalty factor M a , the unit start-stop change penalty factor M u , the unit output adjustment penalty factor M p , which are adjusted in order from large to small.

[0147] Further, in the process of constructing the time period merging security correction model considering unit output-start-stop-inter-province gap-outside DC adjustment, the following constraint conditions need to be established:

[0148] Provincial balance constraints:

[0149] After the inter-provincial interchange plan and the out-of-area tie-line plan are adjusted, the provincial balance constraints are modified as follows:

[0150]

[0151] where P i,t represents the output of unit i at time t, which is a decision variable; is the set of units in province a; T a,t represents the inter-provincial exchange power of province a at time t; D a,t is the system load of province a at time t;

[0152] Minimum continuous start-up and shut-down time constraints of units:

[0153]

[0154] where T U , T D are the minimum continuous start-up time and the minimum continuous shut-down time of a unit; is the time that unit i has been continuously started up and shut down at time t, which can be represented by a state variable U i,t :

[0155]

[0156] Unit start-up and shut-down switching variable constraints:

[0157]

[0158] where η i,t is the unit start-up integer variable, η i,t = 1 indicates that unit i is started up at time t; when the unit is at the shut-down time, γ i,t is the unit start-up integer variable, γ i,t = 1 indicates that unit i is shut down at time t, and satisfies the following conditions:

[0159]

[0160] Inter-provincial exchange plan power flow balance constraints:

[0161] For the adjustment amount of the inter-provincial exchange power of each province in the region, the sum of the inter-provincial exchange power change amounts should be equal to the out-of-area DC change amount, and the specific expression is as follows:

[0162]

[0163] Definition of DC transmission plan adjustment amount:

[0164]

[0165] wherein: Pd(t) is the initial power transmission plan of the DC transmission channel d at time t; Pd(t) = Pd(t-1) + ΔPd(t); d,t Pd(t) is the active power of the DC transmission channel d at time t;

[0166] DC tie-line power inter-provincial distribution constraint:

[0167] After the DC power is brought into the grid at the DC converter station, it is distributed to each province and city in a certain proportion, satisfying the following constraint:

[0168]

[0169] wherein: r d,a Pd(t) is the power distribution factor of the DC transmission channel d to the province a; ΔDT a,t represents the inter-provincial exchange power change amount of the province a under the jurisdiction of the sub-center at time t due to the change of the DC outside the province; the distribution factor needs to satisfy the following condition:

[0170]

[0171] DC tie-line power limit constraint:

[0172] Limited by the physical performance of the DC tie-line, the planned power of the DC tie-line cannot exceed the allowed maximum value and be lower than the allowed minimum value, satisfying the following constraint:

[0173]

[0174] wherein, Pd(t) is the minimum power limit of the DC tie-line d at time t; Pd(t) is the maximum power limit of the DC tie-line d at time t;

[0175] DC tie-line power converter station distribution constraint:

[0176] After the DC power is brought into the grid at the DC converter station, it is distributed to each province and city in a certain proportion, satisfying the following constraint:

[0177]

[0178] wherein, v d,h Pd(t) is the power distribution factor of the DC transmission channel d to the converter station h; ΔP h,t represents the converter station power plan adjustment amount; the distribution factor needs to satisfy the following condition:

[0179] ∑h ∈H v d, h = 1.

[0180] Further, the all-time period safety correction model considering unit output-provincial interconnection gap-interregional DC adjustment takes the unit operation state calculated by the time period merging safety correction model considering unit output-start-stop-provincial interconnection gap-interregional DC adjustment as a reference, assigns the unit operation state of the merged time period to the all-time period and fixes it as a known parameter, and only adjusts the unit output, provincial interconnection gap plan and interregional DC plan; the constraints related to the unit operation state are removed from the constraint conditions.

[0181] Further, based on the calculation results of the all-time period safety correction model considering unit output-provincial interconnection gap-interregional DC adjustment, regional power grid safety checking calculation is carried out to analyze the over-limit situation of regional power grid equipment / section flow, and if new over-limit equipment / section is added, it is added to the safety correction model considering unit output adjustment, and through iterative calculation, the correction results meeting the safety of the regional power grid are finally obtained, including:

[0182] The safety checking adopts alternating current flow calculation method to analyze the over-limit situation of regional power grid equipment / flow after safety correction, and sends the newly added over-limit equipment and over-limit period to safety correction;

[0183] The iterative calculation of safety correction and safety checking is carried out until there is no over-limit equipment in the regional power grid or the maximum number of iterations is reached.

[0184] Based on the same inventive concept, a multi-strategy coordinated regional power grid fast safety correction device of the present application comprises a processor and a memory, the memory stores computer instructions, and the processor is used to execute the computer instructions stored in the memory, and when the computer instructions are executed by the processor, the electronic device realizes the steps of the above-mentioned multi-strategy coordinated regional power grid fast safety correction method.

[0185] Based on the same inventive concept, a computer readable storage medium of the present application stores a computer program, and when the program is executed by a processor, the steps of the above-mentioned multi-strategy coordinated regional power grid fast safety correction method are realized.

[0186] Advantages: Compared with the prior art, the significant technical effects of the present application are:

[0187] An effective constraint identification and participating adjustment province determination, a safety correction considering unit output adjustment, a time period merging safety correction considering unit output-start-stop-provincial interconnection gap-interregional DC adjustment, and a multi-stage coordinated optimization strategy of all-time period safety correction considering unit output-provincial interconnection gap-interregional DC adjustment are formulated, and the fast execution of the safety correction process is realized.

[0188] By participating in the adjustment of the provincial power grid judgment, the similar period merging, the effective safety constraint identification and other strategies, the period scale and the constraint dimension of the safety correction calculation are reduced, the feasible solution space is reduced, and the solving efficiency is improved.

[0189] The modeling strategy of sequentially adjusting the unit output, unit start-stop, inter-provincial exchange power and out-of-area tie line plan is proposed, which maximizes the reliable power supply and maximizes the digestion of new energy.

[0190] Through the cooperation of various strategies, the feasible region of unit commitment problem is reduced, and a more compact effective optimization space is obtained, the calculation efficiency is improved without affecting the optimal solution of unit commitment, the solving process is clear, the calculation result is stable, and the method has high applicability. BRIEF DESCRIPTION OF DRAWINGS

[0191] Figure 1 is a flowchart of a multi-strategy coordinated regional power grid fast safety correction method disclosed by the embodiment of the present application;

[0192] Figure 2 is a structural schematic diagram of a multi-strategy coordinated regional power grid fast safety correction system disclosed by the embodiment of the present application;

[0193] Figure 3 is a structural schematic diagram of a multi-strategy coordinated regional power grid fast safety correction device disclosed by the embodiment of the present application. DETAILED DESCRIPTION

[0194] The present application will be described in detail below with reference to the accompanying drawings and specific embodiments. Those skilled in the art will understand that the purposes and advantages realized by the present application are not limited to the above specific description of beneficial effects, and the above and other purposes realized by the present application will be more clearly understood according to the following detailed description.

[0195] Those skilled in the art should understand that the exemplary components, systems and methods described in conjunction with the disclosed embodiments of the present application can be realized in hardware, software or a combination of both. Whether to realize in hardware or software depends on the specific application of the technical solution and the design and tree conditions. Professional technicians can use different methods to realize the functions for each specific application, but such implementation should not be considered beyond the scope of the present application.

[0196] Reference to "an embodiment" or "the embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment can be included in at least one embodiment of the application. The appearances of the phrase "in various embodiments" in various places in the specification are not necessarily all referring to the same embodiment, nor are they necessarily all referring to a common embodiment, or an embodiment that is independent of all other embodiments. One of ordinary skill in the art will recognize that the embodiments described herein can be combined with other embodiments in various ways.

[0197] Embodiment 1

[0198] Reference is made to Figure 1 , Figure 1 is a flowchart of a multi-strategy coordinated regional power grid fast safety correction method disclosed by an embodiment of the application. Wherein, Figure 1 The described regional power grid fast safety correction method is applied to a power system, such as for power system automatic dispatching, and the like, without limitation of embodiments of the application. As shown in Figure 1 The multi-strategy coordinated regional power grid fast safety correction method can include the following operations:

[0199] Step S1, scene generation. Obtain boundary data and calculation period for carrying out regional power grid safety correction from regional and provincial power grid D5000 or new generation control system, and generate safety correction calculation scene of regional power grid.

[0200] Wherein, the boundary data includes provincial power grid system data, unit data, tie line data, load data and unit group data, and the calculation period is the shortest out-of-clearing period of the regional power grid under jurisdiction of the provincial power grid.

[0201] In this embodiment, the power grid range and calculation period that need to carry out regional power grid safety correction calculation are determined, and data preparation is carried out, including provincial power grid system data, unit data, tie line data, load data and unit group data, to generate a regional power grid safety correction calculation scene.

[0202] The system data includes period information, system load and system standby requirement. The unit data includes unit basic information, unit calculation parameter, unit energy offer, unit initial state, unit power constraint and unit ramping rate. The tie line plan data includes tie line basic information and tie line plan power. The load data includes bus load forecast. The unit group data includes unit group power limit and unit group energy limit. The sensitivity data includes unit, load injection power to line, section flow generation transfer distribution factor.

[0203] Step S2, power grid safety analysis. Carrying out regional power grid safety check calculation, analyzing the over-limit situation of each provincial power grid in the regional power grid. If there is no over-limit of the whole network device / section flow, then enter step S8;

[0204] In this embodiment, the security check calculation adopts a provincial balance calculation strategy, and the power flow and sensitivity are calculated. On one hand, the over-limit condition of the power flow of the equipment / section in the power grid is analyzed, and on the other hand, the sensitivity information is provided for the security correction optimization model construction.

[0205] In this step, the regional power grid security check calculation is carried out, the over-limit condition of the power flow of each provincial power grid in the regional power grid is analyzed, if there is no over-limit, step S8 is entered; if there is over-limit, the provincial power grid participating in the adjustment is determined.

[0206] Step S3, effective constraint and participating adjustment province identification determination. If there is equipment / section over-limit in the regional power grid, according to the power flow result of the equipment / section, the effective equipment / section of the regional power grid security correction is identified, the number of equipment / sections considered in the security correction model is reduced; and according to the effective equipment / section, the provincial power grid participating in the regional power grid security correction is determined, the adjustment range of the security correction is narrowed, and the calculation efficiency of the subsequent step of the security correction is improved.

[0207] In this embodiment, the effective section of the effective constraint identification is the power transmission section that will restrict the operation of the unit in the power grid operation, and the identification method is as follows:

[0208] According to the relationship between the power flow result F of the power transmission section s,t and the physical power transmission limit value P of the power transmission section max,s , the effective type of the power transmission section is divided:

[0209] According to the relationship between the power flow result F of the power transmission section s,t and the physical power transmission limit value P of the power transmission section max,s , the effective type of the power transmission section is divided:

[0210] If |F s,t |<σ*P max,s , the power transmission section s is an invalid section at time period t;

[0211] If |F s,t |≥σ*P max,s , the power transmission section s is an effective section at time period t;

[0212] In the formula, σ is the effective constraint determination coefficient.

[0213] The determination method of the participating adjustment province is as follows:

[0214] If the effective equipment / section is the provincial equipment / section, the province of the equipment / section independently participates in the adjustment;

[0215] If the effective equipment / section is the inter-provincial equipment / section, the provinces connected with the equipment / section all participate in the adjustment.

[0216] In this embodiment, if the effective section is in the provincial power grid a, the units in the provincial power grid a participate in adjustment; if the effective section is a provincial section, crossing the provincial power grids a and b, the units in the provincial power grids a and b participate in adjustment simultaneously.

[0217] By effectively constraining the identification in the limit equipment / section (i.e. effective equipment / section), filtering invalid equipment / section, reducing the number of equipment / sections considered by the security correction optimization model, determining the provincial power grid participating in adjustment based on the effective equipment / section, narrowing the security correction optimization calculation range, and improving the efficiency of the regional power grid security correction calculation.

[0218] Step S4, the security correction model considering the unit output adjustment. A security correction model is constructed with the unit output of the provincial power grid participating in the regional power grid security correction as the decision variable Safety correction model for regional grid , and based on the security correction model considering the unit output adjustment Safety correction model, Figure 2 The security constrained economic dispatch algorithm is used to adjust the unit output of the provincial power grid participating in the regional power grid security correction to eliminate the equipment / section flow limit overrun; if all equipment / section limit overruns are successfully eliminated, step S8 is entered, otherwise step S5 is entered. If the flow limit overrun is eliminated, step S8 is entered; otherwise, the next step is continued.

[0219] In this embodiment, the optimization objective function of the security correction model considering the unit output adjustment is as follows:

[0220]

[0221] In the formula, N is the total number of units; T is the total number of time considered for calculation; NS is the total number of equipment / sections; ΔP i,t represents the output adjustment amount of unit i at time t (non-network dispatching direct dispatching unit); M p is the penalty factor of unit output adjustment; M b is the penalty factor for generation and consumption balance constraint; M s is the penalty factor of equipment / section s at time t; are the positive and negative relaxation variables of the generation and consumption balance constraint at time t, respectively; are the positive and negative flow relaxation variables of equipment / section s at time t, respectively; are the positive and negative relaxation variables of the generation and consumption balance constraint at time t, respectively.

[0222] In this embodiment, during the construction of the security correction model considering the unit output adjustment, the model constraint conditions need to be established.

[0223] The model constraint conditions include provincial balance constraint, unit output adjustment amount, unit output upper and lower limit, unit output climbing and sliding slope, and power grid safety constraint.

[0224] 1) Provincial balance constraint:

[0225] The total generation of a province is equal to the difference between the short-term load forecast of the province and the inter-provincial exchange power, as shown in the following equation:

[0226]

[0227] where P i,t represents the output of unit i at time t, decision variable; is the set of units in province a; represents the initial inter-provincial exchange power plan of province a at time t (positive for import and negative for export), known parameter; D a,t is the system load of province a at time t, known parameter;

[0228] 2) Definition of unit output adjustment:

[0229]

[0230] where: is the unit output plan reported by the province at time t, is the market clearing result of each provincial power grid, and ΔP i,t is the unit output plan adjustment at time t;

[0231] 3) Upper and lower limits of unit output constraint:

[0232]

[0233] where U i,t is the start-stop state of unit i at time t, if the unit is stopped, U i,t = 0, through this constraint, the unit output can be limited to 0, when the unit is started, U i,t = 1, this constraint is the conventional upper and lower limit constraint of output; is the minimum technical output of unit i at time t; is the maximum technical output of unit i at time t;

[0234] 4) Unit output ramping constraint:

[0235]

[0236] where, is the maximum upward ramping of unit i, is the maximum downward ramping of unit i; when the unit is in the start-up time, the ascending output range of the unit is determined by the allowed start-up rate of the unit (here it is ), η i,t is the unit start-up integer variable, η i,t= 1 means that unit i is on at time t; when the unit is at the off time, the unit's reduced output range is determined by the unit's allowed shutdown rate (here, the unit's allowed shutdown rate is i,t = 1 means that unit i is on at time t; when the unit is at the off time, the unit's reduced output range is determined by the unit's allowed shutdown rate (here, the unit's allowed shutdown rate is i,t = 1 means that unit i is on at time t; when the unit is at the off time, the unit's reduced output range is determined by the unit's allowed shutdown rate (here, the unit's allowed shutdown rate is

[0237] 5) Power transmission equipment power flow constraint:

[0238] The security correction model and the section power flow constraint of the first round of iteration of the security check can be described as:

[0239]

[0240] The security correction model and the section power flow constraint of the second round and subsequent iterations of the security check can be described as:

[0241]

[0242] In the formula, P i,t is the active power of unit i at time t, which is a decision variable; is the active power of unit i at the previous round at time t; D k,t is the bus load value of node k at time t; are the positive and negative power flow transmission limits of equipment / section s, respectively; G s-i is the generator output power transfer distribution factor of the node where unit i is located to equipment / section s; G s-k is the output power transfer distribution factor of node k to equipment / section s; G s-j is the output power transfer distribution factor of the node where tie line j is located to equipment / section s; are the positive and negative power flow relaxation variables of equipment / section s, respectively; is the AC power flow of equipment / section s at the previous round of security correction at time t.

[0243] Step S5, time period merging security correction model considering unit output-start-stop-inter-province port adjustment: if the security correction model considering unit output adjustment cannot eliminate equipment / section over-limit, a time period merging security correction model of the regional power grid is constructed with unit output, unit start-stop, inter-province port plan, and external tie line plan as decision variables, and based on the time period merging security correction model, a security constrained unit commitment algorithm is used to adjust each decision variable in turn to provide the unit operation state for step S6.

[0244] ​The effective section is identified according to the calculation result of the safety correction model considering unit output adjustment, the grid safety constraint is constructed, and the number of dense constraints is reduced; according to the change trend of the grid load at different time periods in the calculation period, similar calculation time periods are merged, the number of time periods entering the optimization is reduced, and the time period scale is reduced; the unit output, unit start-stop, inter-provincial port plan and inter-district tie-line plan are adjusted in turn, and the section limit is eliminated.

[0245] In the embodiment, according to the change trend of the grid load at different time periods in the calculation period, similar calculation time periods are merged, and the specific process is as follows:

[0246] Let L t be the system load at time period t, then the system load change rate of adjacent time periods t and t+1 is:

[0247]

[0248] The system load change rate of all time periods is calculated, and the time period corresponding to the minimum change rate ΔL t is found.

[0249] Time periods t and t+1 are merged into a new time period;

[0250] According to the system load change rate, the time period merging is repeated until the minimum change rate ΔL t is greater than the set threshold value, or the number of time periods remaining after merging reaches the preset number, the determination condition takes effect, and the time period merging is completed; otherwise, the system load change rate of adjacent time periods t and t+1 is recalculated.

[0251] In the embodiment, the optimization objective function of the time period merging safety correction model considering unit output-start-stop-inter-provincial port-inter-district DC adjustment is represented as:

[0252]

[0253] In the formula, N is the total number of units; T is the total number of time periods after safety correction time period merging; NS is the total number of devices / sections; DN is the total number of DC tie-line; NT is the set of provinces and cities; ΔP i,t represents the output adjustment amount of unit i at time t, which is a decision variable; ΔP d,t is the planned adjustment amount of DC tie-line d at time t, which is a decision variable; is the start-stop state of unit i at time period t reported by each province and city, which is a known parameter; U i,t is the start-stop state of unit i at time period t after calculation, which is a decision variable; is the original inter-provincial exchange power plan of province a at time period t, which is a known parameter; T a,tM d M a M p M u M b M s M M M

[0254] In this embodiment, the order of the penalty factors in the optimization objective function of the time period merging security correction model considering unit output-start-stop-inter-province port adjustment-out-of-province DC adjustment is as follows: the balance constraint relaxation penalty factor M b , the power grid security constraint relaxation penalty factor M s , the DC tie-line plan adjustment amount penalty factor M d , the inter-province exchange power plan adjustment penalty factor M a , the unit start-stop change penalty factor M u , and the unit output adjustment penalty factor M p , and the priority order is adjusted by the size order.

[0255] In the process of constructing the time period merging security correction model considering unit output-start-stop-inter-province port adjustment-out-of-province DC adjustment, the model constraint conditions need to be established. Compared with the security correction optimization model considering unit output adjustment, the following constraint conditions are added:

[0256] 1) Provincial balance constraint:

[0257] After the inter-province port plan and the out-of-province tie-line plan are adjusted, the provincial balance constraint is modified as follows:

[0258]

[0259] In the formula, P i,t represents the output of unit i at time t, which is a decision variable; is the set of units in province a; T a,t represents the inter-province exchange power of province a at time t (positive for sending in and negative for outputting), which is a decision variable; D a,t is the system load of province a at time t, which is a known parameter.

[0260] 2) Minimum continuous start-stop time constraint of unit:

[0261]

[0262] where T U , T D are the minimum continuous on-time and minimum continuous off-time of the unit; is the time that unit i has been continuously on and off at time period t, which can be represented by state variable U i,t :

[0263]

[0264] 3) Unit start-up and shut-down switching variable constraints:

[0265]

[0266] where η i,t is the unit on integer variable, η i,t = 1 means that unit i is on at time period t; and γ i,t is the unit off integer variable, γ i,t = 1 means that unit i is off at time period t, and satisfies the following conditions:

[0267]

[0268] 4) Inter-province exchange plan power flow balance constraints:

[0269] For the adjustment amount of inter-province exchange power of each province in the region, the inter-province exchange power change amount accumulation should be equal to the out-of-region DC change amount, and the specific expression is:

[0270]

[0271] 5) DC transmission plan adjustment amount definition:

[0272]

[0273] where: is the initial transmission plan of DC transmission channel d at time t, which is a known parameter; P d,t is the active power of DC transmission channel d at time t, which is a decision variable;

[0274] 6) DC tie-line power inter-province distribution constraints:

[0275] After the DC power is connected to the grid at the DC converter station, it is distributed to each province and city according to a certain proportion, and satisfies the following constraints:

[0276]

[0277] where r d,aPower distribution factor of DC transmission channel d to a province; ΔDT a,t represents the variation of inter-provincial exchange power of the sub-center jurisdictional province a at time t caused by the variation of DC outside the region; the distribution factor needs to meet the following conditions:

[0278]

[0279] 7) DC tie-line power limit constraint:

[0280] Limited by the physical performance of the DC tie-line, the planned power of the DC tie-line cannot exceed the allowed maximum value and be lower than the allowed minimum value, meeting the following constraints:

[0281]

[0282] In the formula, is the minimum power limit of the DC tie-line d at time t; is the maximum power limit of the DC tie-line d at time t;

[0283] 8) DC tie-line power converter station distribution constraint:

[0284] After the DC power is connected to the grid at the DC converter station, it is distributed to each province and city according to a certain proportion, meeting the following constraints:

[0285]

[0286] In the formula, v d,h is the power distribution factor of DC transmission channel d to converter station h; Δph ,t represents the power plan adjustment amount of the converter station; the distribution factor needs to meet the following conditions:

[0287] ∑h ∈H v d, h=1.

[0288] Step S6, a full-time period safety correction model considering unit output-provincial interconnection gap-DC outside the region adjustment. Based on the unit start-stop state calculated by the "time period merging safety correction model considering unit output-start-stop-provincial interconnection gap-DC outside the region adjustment", a full-time period safety correction model of the regional power grid is established, and a safety constrained economic dispatch algorithm is used to optimize the unit output, provincial interconnection gap plan and external tie-line plan in turn, so as to eliminate the equipment / section flow out of limit.

[0289] The all-time period safety correction model considering unit output-interregional port-interregional DC adjustment is an all-time period safety correction model considering unit output-start-stop-interregional port-interregional DC adjustment, the unit operation state calculated is accurate, the unit operation state of the merged time period is assigned to the all-time period and fixed as a known parameter, and only the unit output, interregional port plan and interregional DC plan are adjusted. The minimum start-stop time, start-stop times and other constraints related to the unit operation state are removed from the constraint conditions, and the other constraints are the same as those of the all-time period safety correction model considering unit output-start-stop-interregional port-interregional DC adjustment, and will not be repeated.

[0290] In the scheme, the abstract model of the all-time period safety correction model considering unit output-interregional port-interregional DC adjustment is the same as that of the all-time period safety correction model considering unit output-start-stop-interregional port-interregional DC adjustment, and the example models are different, mainly in the following points: 1) the optimization time period of the all-time period safety correction model considering unit output-interregional port-interregional DC adjustment is the all-time period, and the number of time periods is more than that of the all-time period safety correction model considering unit output-start-stop-interregional port-interregional DC adjustment; 2) the all-time period safety correction model considering unit output-interregional port-interregional DC adjustment takes the unit start-stop state calculated by the all-time period safety correction model considering unit output-start-stop-interregional port-interregional DC adjustment as a reference, and assigns the start-stop state to the all-time period; 3) the all-time period safety correction model considering unit output-interregional port-interregional DC adjustment fixes the unit start-stop state, and only optimizes the unit output, interregional exchange power and interregional DC plan of the all-time period.

[0291] Step S7, safety correction and safety checking iteration. Based on the calculation results of the all-time period safety correction model considering unit output-interregional port-interregional DC adjustment, safety checking calculation is carried out, the over-limit equipment / section flow of the regional power grid is analyzed, and if new over-limit equipment / section is added, it is added to the safety correction model considering unit output adjustment, and enters step S4, and through iterative calculation, the correction result meeting the safety of the regional power grid is finally obtained.

[0292] In the embodiment, the safety correction and safety checking iteration calculation includes:

[0293] The safety checking adopts alternating current flow calculation mode, analyzes the over-limit equipment / section flow of the regional power grid after safety correction, and sends the newly added over-limit equipment / section and over-limit time period to safety correction;

[0294] The safety correction and safety checking iteration calculation is carried out until there is no over-limit equipment / section in the regional power grid or the maximum iteration number is reached.

[0295] Step S8, the correction result meeting the safety of the regional power grid is issued to each provincial power grid, and the calculation is ended.

[0296] The technical scheme of the present application is to obtain the power grid range and calculation period for carrying out regional power grid safety correction, generate a calculation scenario; carry out power grid safety analysis to analyze the out-of-limit situation of regional power grid equipment / section flow; determine the provincial power grid participating in regional power grid safety correction, identify effective constraints, reduce the adjustment range and calculation scale; build a regional power grid safety correction optimization model considering unit output adjustment, optimize and adjust the unit output by using a safety constraint economic dispatch algorithm to eliminate the out-of-limit flow; if there is still an out-of-limit, carry out similar time period merging and power grid safety effective constraint identification to reduce the optimization time period and the number of constraints, build a time period merging safety correction model considering unit output-start-stop-provincial interconnection port-external DC adjustment, and adjust each decision variable in turn by using a safety constraint unit combination algorithm; then, taking the unit start-stop state calculated by the time period merging safety correction model considering unit output-start-stop-provincial interconnection port-external DC adjustment as a reference, build a full-time period safety correction model considering unit output-provincial interconnection port-external DC adjustment, and carry out full-time period safety constraint economic dispatch; based on the full-time period safety constraint economic dispatch result, carry out safety checking analysis, and add the newly added out-of-limit equipment / section to the regional power grid safety correction model, and finally obtain the correction result meeting the regional power grid safety through iterative calculation.

[0297] The technical scheme of the present application is a regional level checking means for guaranteeing the normal operation of the spot market in each province and city in the regional power grid. With the rapid advancement of the construction of the provincial power spot market, the market participants and market transaction types increase dramatically, the power grid operation mode is complex and changeable, the provincial power grid safety checking function cannot guarantee the safe and stable operation of the inter-provincial section, cannot give an optimal correction strategy when a safety risk occurs, and has problems such as inaccurate local equipment flow and low calculation efficiency, which has a profound impact on the safety control of the power grid, and the safe operation of the power grid is at risk. The multi-strategy coordinated regional power grid fast safety correction algorithm under the power market environment provided by the present application provides technical support for reliable execution of the clearing result of the provincial spot market in the region, power production organization operation management under the new situation of standardization, and improvement of the ability to protect safety, supply and consumption, which is conducive to the safe and stable development of the process of power marketization, plays a core hub role in optimizing the allocation of overall resources of the regional power grid and promoting clean energy consumption.

[0298] Embodiment 2

[0299] Please refer to Figure 2 , Figure 3 is a structural schematic diagram of a multi-strategy coordinated regional power grid fast safety correction system disclosed by the embodiment of the present application, which can realize regional power grid fast safety correction, and specifically comprises:

[0300] A scene generation module is configured to acquire boundary data and a calculation period for carrying out regional power grid safety correction from a regional and provincial power grid D5000 or a new generation dispatching system, and generate a safety correction calculation scene of the regional power grid;

[0301] A power grid safety analysis module is configured to carry out regional power grid safety checking calculation based on the safety correction calculation scene of the regional power grid, and analyze over-limit conditions of tide equipment / section flows in the regional power grid.

[0302] An identification module is configured to identify effective equipment / sections and determine participating provinces; if there are over-limit equipment / sections in the regional power grid, the effective sections for regional power grid safety correction are identified according to tide flow results of the transmission sections; and the provincial power grids participating in the regional power grid safety correction are determined according to the effective equipment / sections, so as to narrow the safety correction adjustment range and improve the calculation efficiency of the safety correction in subsequent steps.

[0303] A safety correction model construction module is configured to construct a safety correction model of the regional power grid taking unit outputs of the provincial power grids participating in the regional power grid safety correction as decision variables, and adjust the unit outputs of the provincial power grids participating in the regional power grid safety correction by using a safety constrained economic dispatch algorithm based on the safety correction model, so as to eliminate over-limit tide flows of the equipment / sections.

[0304] A time period merging safety correction model construction module is configured to, in the case that the safety correction model taking into account the unit output adjustment cannot eliminate over-limit conditions of the equipment / sections, construct a time period merging safety correction model of the regional power grid taking unit outputs, unit start-stop, inter-provincial port plan and inter-regional tie-line plan as decision variables, and adjust the decision variables in sequence by using a safety constrained unit combination algorithm based on the time period merging safety correction model, so as to eliminate over-limit tide flows.

[0305] A full time period safety correction model construction module is configured to establish a full time period safety correction model of the regional power grid taking unit start-stop states calculated by the time period merging safety correction model taking into account unit output-start-stop-inter-provincial port-inter-regional DC adjustment as a reference, and optimize the unit output, inter-provincial port plan and inter-regional tie-line plan in sequence by using a safety constrained economic dispatch algorithm based on the full time period safety correction model, so as to eliminate over-limit tide flows.

[0306] An iterative calculation module is configured to carry out regional safety checking calculation based on calculation results of the full time period safety correction model taking into account unit output-inter-provincial port-inter-regional DC adjustment, analyze over-limit conditions of tide flows of equipment / sections in the regional power grid, and add the newly added over-limit equipment / sections to the safety correction model taking into account unit output adjustment, so as to re-carry out safety correction optimization and solution, and finally obtain a correction result meeting the safety of the regional power grid through iterative calculation.

[0307] In an alternative embodiment, the multi-strategy coordinated regional power grid fast security correction method comprises: a) obtaining the grid range and calculation period for carrying out regional power grid security correction, and generating a calculation scenario; b) carrying out power grid security analysis to analyze the regional power grid tide device / section flow overrun situation; c) determining the provincial power grid participating in the regional power grid security correction, identifying effective constraints, reducing the adjustment range and calculation scale; d) constructing a regional power grid security correction optimization model taking unit output as the decision variable, optimizing and adjusting the unit output by using the security constrained economic dispatch algorithm to eliminate the flow overrun; e) if there is still overrun, carrying out similar period merging and power grid security effective constraint identification to reduce the optimization period and the number of constraints, constructing a regional power grid security correction model taking unit output, unit start-stop, inter-provincial port planning, and external tie-line planning as decision variables, and adjusting each decision variable in turn by using the security constrained unit commitment algorithm to eliminate the flow overrun; f) taking the unit start-stop state of the security constrained unit commitment optimization as the benchmark, carrying out full-period security constrained economic dispatch; g) based on the full-period security constrained economic dispatch result, carrying out security check analysis, and adding the newly added overrun device to the regional power grid security correction model, and finally obtaining the correction result meeting the regional power grid security through iterative calculation; h) issuing the correction result meeting the regional power grid security to each provincial power grid, and ending the calculation.

[0308] Further, the boundary data of the scenario generation includes provincial power grid system data, unit data, tie-line data, load data, and unit group data; and the calculation period is the shortest dispatching period of the regional power grid under jurisdiction.

[0309] Further, the power grid security analysis adopts a provincial balance calculation strategy, and simultaneously calculates the flow and the sensitivity, the flow is used to analyze the power grid flow overrun situation, and the sensitivity is used to construct the security correction optimization model.

[0310] Further, the effective section for the effective constraint identification is a power transmission section that will restrict the unit operation in the power grid operation, and the identification method is as follows:

[0311] According to the relationship between the flow result F of the power transmission section and the physical power transmission limit P of the power transmission section, s,t max,s the function type of the power transmission section is divided:

[0312] If |F s,t |<σ*P max,s , the power transmission section s is an invalid section at the time period t;

[0313] If |F s,t |≥σ*P max,s , the power transmission section s is an effective section at the time period t;

[0314] In the formula, σ is the function constraint judgment coefficient.​

[0315] The determination method of participating adjustment provinces is as follows:

[0316] If the effective device / section is a provincial device / section, the device / section participates in the adjustment independently of the province;

[0317] If the effective device / section is an inter-provincial device / section, the provinces connected with the device / section all participate in the adjustment.

[0318] Further, the security correction model considering unit output adjustment only optimizes unit output, and the unit start-stop state, inter-provincial port plan and out-of-area tie line plan are all known parameters, which are subject to the data reported by the provincial power grid;

[0319] The optimization objective function of the security correction model considering unit output adjustment is as follows:

[0320]

[0321] In the formula, N is the total number of units; T is the total number of time considered for calculation; NS is the total number of devices / sections; ΔP i,t represents the output adjustment amount of unit i at time t; M p is a penalty factor of unit output adjustment; M b is a penalty factor for generation and consumption balance constraint; M s is a penalty factor of device / section s at time t; respectively, are the positive and negative relaxation variables of the generation and consumption balance constraint at time t; respectively, are the positive and negative power flow relaxation variables of device / section s at time t; respectively, are the positive and negative relaxation variables of the generation and consumption balance constraint at time t;

[0322] The constraint conditions of the security correction model considering unit output adjustment include provincial balance constraint, unit output adjustment amount, upper and lower limits of unit output, unit output creep and slope, and power grid safety constraint; wherein:

[0323] Provincial balance constraint:

[0324] The total output of units in each province is equal to the difference between the short-term predicted value of the system load of the province and the inter-provincial exchange power, as shown in the following formula:

[0325]

[0326] In the formula, P i,t represents the output of unit i at time t; is a set of units in province a; represents the initial inter-provincial exchange power plan of province a at time t; D a,t is the system load of province a at time t;

[0327] The definition of the unit output adjustment amount is:

[0328]

[0329] In the formula: is the output plan of the unit i reported by the province and city at time t, is the power market clearing result of each provincial power grid, and ΔP i,t is the output plan adjustment amount of the unit i at time t;

[0330] The upper and lower limits of the unit output constraint are:

[0331]

[0332] In the formula, U i,t is the start-stop state of the unit i at time t, if the unit is stopped, U i,t = 0, through the constraint condition, the unit output can be limited to 0, when the unit is started, U i,t = 1, the constraint condition is the conventional upper and lower limit constraint of the output; is the minimum technical output of the unit i at time t; is the maximum technical output of the unit i at time t;

[0333] The unit output ramping constraint is:

[0334]

[0335] In the formula, is the maximum upward ramping amount of the unit i, is the maximum downward ramping amount of the unit i; when the unit is at the start time, the ascending output range of the unit is determined by the allowed start rate of the unit, η i,t is the unit start integer variable, η i,t = 1, the unit i is started at time t; when the unit is at the stop time, the descending output range of the unit is determined by the allowed stop rate of the unit; γ i,t is the unit start integer variable, γ i,t = 1, the unit i is stopped at time t.

[0336] The power transmission equipment / sectional power flow constraint is:

[0337] The equipment / sectional power flow constraint of the security correction model and the first round of iteration of the security check can be described as:

[0338]

[0339] The equipment / sectional power flow constraint of the security correction model and the second round and subsequent iterations of the security check can be described as:

[0340]

[0341] P i,t is the active power of unit i in period t; is the active power of unit i in the last round of period t; D k,t is the bus load value of node k in period t; are the positive and negative power flow transmission limits of device / section s, respectively; G s-i is the generator output power transfer distribution factor of unit i to device / section s; G s-k is the output power transfer distribution factor of node k to device / section s; G s-j is the output power transfer distribution factor of the node where tie line j is located to device / section s; are the positive and negative power flow relaxation variables of device / section s, respectively; is the AC power flow of device / section s in the last round of period t.

[0342] Further, a period merging security correction model considering unit output-start-stop-inter-province port-external DC adjustment is provided, and the period merging method thereof includes the following steps:

[0343] Let L t be the system load in period t, then the system load change rate of adjacent periods t and t+1 is:

[0344]

[0345] Calculate the system load change rate of all periods, find the minimum change rate ΔL t corresponding period;

[0346] Merge periods t and t+1 into a new period;

[0347] whether the minimum change rate ΔL t is greater than the set threshold, or whether the number of periods left after merging reaches the preset number, the determination condition is effective, then the period merging is completed, otherwise recalculate the system load change rate of adjacent periods t and t+1.

[0348] Further, the objective function of the period merging security correction model considering unit output-start-stop-inter-province port-external DC adjustment is represented as:

[0349]

[0350] wherein N is the total number of units; T is the total number of periods after security correction period merging; NS is the total number of devices / sections; DN is the total number of DC tie lines; NT is the province / city set; ΔP i,trepresents the output adjustment amount of unit i at time t; ΔP d,t represents the planned adjustment amount of DC tie line d at time t; represents the start-stop state of unit i reported by each province at time t; U i,t represents the start-stop state of unit i at time t after calculation; represents the planned inter-provincial exchange power of province a at time t; T a,t represents the planned inter-provincial exchange power of province a at time t after calculation; M d represents the penalty factor of the planned adjustment amount of DC tie line; M a represents the penalty factor of the planned adjustment amount of inter-provincial exchange power; M p represents the penalty factor of unit output adjustment; M u represents the penalty factor of unit start-stop change; M b represents the penalty factor for generation and consumption balance constraint; M s represents the penalty factor of device / section s at time t; respectively represents the positive and negative relaxation variables of generation and consumption balance constraint at time t; respectively represents the positive and negative power flow relaxation variables of device / section s at time t.

[0351] Further, the optimization objective function of the time period merging security correction model considering unit output-start-stop-inter-provincial port adjustment-outside DC adjustment contains multiple penalty factors, and the order from large to small is: balance constraint relaxation penalty factor M b , grid security constraint relaxation penalty factor M s , DC tie line planned adjustment amount penalty factor M d , inter-provincial exchange power plan adjustment penalty factor M a , unit start-stop change penalty factor M u , unit output adjustment penalty factor M p , which are adjusted in order from large to small.

[0352] Further, in the process of constructing the time period merging security correction model considering unit output-start-stop-inter-provincial port adjustment-outside DC adjustment, the following constraint conditions need to be established:

[0353] Provincial balance constraint:

[0354] After the inter-provincial port plan and the outside tie line plan participate in adjustment, the provincial balance constraint is modified as:

[0355]

[0356] In the formula, P i,t represents the output of unit i at time t, which is a decision variable; represents the set of units in province a; T a,tD a,t D

[0357] Minimum continuous on-off time constraint of generating units:

[0358]

[0359] where T U , T D are the minimum continuous on-time and off-time of generating units; are the continuous on-time and off-time of generating unit i at time period t, which can be represented by state variable U i,t :

[0360]

[0361] Switching variable constraint of generating unit start-up and shut-down:

[0362]

[0363] where η i,t is the on-off integer variable of generating unit, η i,t = 1 means that generating unit i is on at time period t; when the generating unit is at the off-time, γ i,t is the on-off integer variable of generating unit, γ i,t = 1 means that generating unit i is off at time period t, and satisfies the following conditions:

[0364]

[0365] Inter-province exchange plan power flow balance constraint:

[0366] For the adjustment amount of inter-province exchange power of each province in the region, the cumulative amount of inter-province exchange power change should be equal to the amount of change of DC outside the region, and the specific expression is:

[0367]

[0368] Definition of DC transmission plan adjustment amount:

[0369]

[0370] where: is the initial transmission plan of DC transmission channel d at time t; P d,t is the active power of DC transmission channel d at time t;

[0371] Inter-province distribution constraint of DC tie-line power:

[0372] After the DC tie-line power is connected to the grid at the DC converter station, it is distributed to each province and city according to a certain proportion, and satisfies the following constraints:

[0373]

[0374] wherein r d,a is the power allocation factor of DC transmission channel d to province a; ΔDT a,t represents the variation of inter-provincial exchange power of province a under the jurisdiction of the sub-center at time t caused by the variation of DC outside the region; the allocation factor needs to satisfy the following conditions:

[0375]

[0376] DC tie-line power limit constraint:

[0377] Limited by the physical performance of the DC tie-line, the planned power of the DC tie-line cannot exceed the allowed maximum value and be lower than the allowed minimum value, satisfying the following constraint:

[0378]

[0379] wherein, is the minimum power limit of DC tie-line d at time t; is the maximum power limit of DC tie-line d at time t;

[0380] DC tie-line power converter station allocation constraint:

[0381] After the DC power is connected to the grid at the DC converter station, it is allocated to each province and city in a certain proportion, satisfying the following constraint:

[0382]

[0383] wherein v d,h is the power allocation factor of DC transmission channel d to converter station h; Δp h,t represents the converter station power plan adjustment amount; the allocation factor needs to satisfy the following conditions:

[0384] ∑h ∈H v d, h = 1.

[0385] Further, the all-time period safety correction model considering unit output-provincial interlink-provincial DC adjustment takes the unit operation state calculated by the time period merging safety correction model considering unit output-start-stop-provincial interlink-provincial DC adjustment as the standard, assigns the unit operation state of the merged time period to the all-time period and fixes it as a known parameter, only adjusts the unit output, provincial interlink plan and provincial DC plan; the constraints related to the unit operation state are removed from the constraint conditions.

[0386] Further, based on the calculation result of the full period security correction model considering the unit output-inter-province gap-out-of-region DC adjustment, the regional power grid security checking calculation is carried out, the over-limit situation of the regional power grid equipment / section flow is analyzed, if the newly added over-limit equipment / section is over-limit, it is added to the security correction model considering the unit output adjustment, and the correction result meeting the security of the regional power grid is finally obtained through iterative calculation, including:

[0387] The security checking adopts the alternating current flow calculation mode, the over-limit situation of the regional power grid equipment / flow after the security correction is analyzed, and the newly added over-limit equipment and over-limit period are sent to the security correction;

[0388] The iterative calculation of the security correction and the security checking is carried out until there is no over-limit equipment in the regional power grid or the maximum iteration number is reached.

[0389] Embodiment 3

[0390] Please refer to Figure 3 , Figure 3 It is a structure schematic diagram of a multi-strategy coordinated regional power grid fast security correction device disclosed by the embodiment of the application. Wherein, Figure 3 The device described can be applied to the power system, such as used for power system automatic dispatching, and the embodiment of the application is not limited.

[0391] As ​ shown, the device can include a processor and a memory, the memory stores computer instructions, the processor is used to execute the computer instructions stored in the memory, when the computer instructions are executed by the processor, the electronic device realizes the steps of the method as described in the above embodiment, and can achieve the technical effect consistent with the above method.

[0392] The memory can include a computer system readable medium in the form of a volatile memory, such as a random access memory (RAM) and / or a cache memory. The device can further include other removable / non-removable, volatile / non-volatile computer system storage media. For example, the memory can be used to read and write non-removable, non-volatile magnetic media (usually referred to as "hard disk drive"). The program / utility having a set of (at least one) program modules can be stored in, for example, the memory, such as an operating system, one or more application programs, other program modules, and program data, each of which or some combination thereof can include the implementation of a network environment. The program modules usually perform the functions and / or methods in the embodiments described in the application.

[0393] The processor performs various functional applications and data processing by running the program stored in the memory, for example, realizes the method provided by the embodiment one of the application.

[0394] Embodiment 4

[0395] The embodiment 4 of the present application further provides a computer readable storage medium, which stores a computer program. The computer program is executed by a processor to implement the steps of the method in the above embodiment and achieve the same technical effects.

[0396] The computer readable storage medium of the embodiment of the present application can adopt any combination of one or more computer readable media. The computer readable medium can be a computer readable signal medium or a computer readable storage medium. The computer readable storage medium may, for example, but is not limited to, an electrical, magnetic, optical, electromagnetic, infrared, or semiconductor system, device or apparatus, or any combination of the above. More specific examples (non-exhaustive list) of the computer readable storage medium include an electrical connection having one or more wires, a portable computer diskette, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the above. In this document, the computer readable storage medium can be any tangible medium that contains or stores a program that can be used by or in connection with an instruction execution system, apparatus or device.

[0397] The computer readable signal medium can include a data signal propagated in a baseband or propagated as a carrier wave in a propagated data signal, in which the computer readable program code is contained. Such propagated data signal can take many forms, including but not limited to electromagnetic signal, optical signal or any suitable combination of the above. The computer readable signal medium can also be any computer readable medium that is not a computer readable storage medium and that can transmit, propagate or transport program for use by or in connection with an instruction execution system, apparatus or device.

[0398] The program code contained in the computer readable medium can be transmitted by any suitable medium, including but not limited to wireless, wire, cable, RF, etc., or any suitable combination of the above.

[0399] Computer program code for carrying out operations of the present application can be written in any combination of one or more programming languages, including an object oriented programming language such as Java, Smalltalk, C++ or the like, and conventional procedural programming languages, such as the "C" programming language or similar programming languages. The program code can execute entirely on the user's computer, partly on the user's computer, as a stand-alone software package, partly on the user's computer and partly on a remote computer or entirely on the remote computer or server. In the latter scenario, the remote computer can be connected to the user's computer through any type of network, including a local area network (LAN) or a wide area network (WAN), or the connection can be made to an external computer (for example, through the Internet using an Internet Service Provider).

[0400] Of course, the storage medium provided by the embodiments of the present application includes computer executable instructions, and the computer executable instructions are not limited to the method operations described above, but can also perform related operations in the method provided by any embodiment of the present application.

[0401] The above specific embodiments further illustrate the purposes, technical solutions and beneficial effects of the present application. It should be understood that the above description is only for specific embodiments of the present application and is not intended to limit the present application. Any modification, equivalent replacement, improvement, etc. made within the spirit and principle of the present application shall be included in the protection scope of the present application.

Claims

1. A multi-strategy coordinated regional power grid rapid security correction method, characterized in that: include: Obtain boundary data and calculation cycles for regional power grid security correction from regional and provincial power grid D5000 or new generation control systems to generate regional power grid security correction calculation scenarios; Based on the security correction calculation scenario of the regional power grid, the regional power grid security verification calculation is carried out to analyze the power flow exceeding the limit of each provincial power grid within the regional power grid; If there are devices / sections exceeding limits within the regional power grid, the system identifies valid devices / sections for regional power grid security correction based on the power flow results of the devices / sections. Furthermore, the system determines the provincial power grids that will participate in the regional power grid security correction based on the valid devices / sections, thereby narrowing the scope of security correction adjustments and improving the calculation efficiency of security correction in subsequent steps. A regional power grid security correction model is constructed, using the unit output of the provincial power grid participating in the regional power grid security correction as the decision variable. Based on the security correction model that takes unit output adjustment into account, a security-constrained economic dispatch algorithm is used to adjust the unit output of the provincial power grid participating in the regional power grid security correction to eliminate equipment / section power flow exceeding the limit. If the safety correction model that takes into account the unit output adjustment cannot eliminate the equipment / section over-limit, a time-period-merged safety correction model for the regional power grid is constructed with unit output, unit start-up and shutdown, inter-provincial port plan, and inter-regional tie line plan as decision variables. Based on the time-period-merged safety correction model, a safety-constrained unit combination algorithm is used to adjust each decision variable in turn and calculate the unit start-up and shutdown status. Based on the unit start-up and shutdown status calculated by the period-merged safety correction model that takes into account unit output, start-up and shutdown, inter-provincial connection, and external DC adjustment, a full-time safety correction model for the regional power grid is established. Based on the full-time safety correction model, a safety-constrained economic dispatch algorithm is used to sequentially optimize unit output, inter-provincial connection plans, and external interconnection line plans to eliminate equipment / section power flow over-limits. Based on the calculation results of the full-time security correction model that takes into account the unit output, inter-provincial interface, and out-of-region DC adjustment, regional power grid security verification calculations are carried out to analyze the over-limit situation of regional power grid equipment / section power flow. If new over-limit equipment / section is added, it will be added to the security correction model that takes into account the unit output adjustment. Through iterative calculation, the correction result that meets the regional power grid security is finally obtained.

2. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1 is characterized by: The boundary data generated by the scenario includes provincial power grid system data, unit data, tie line data, load data and unit group data; the calculation period is the shortest clearing period of the provincial power grid under the jurisdiction of the regional power grid.

3. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1, characterized in that: The power grid security analysis adopts a provincial balance calculation strategy and simultaneously calculates power flow and sensitivity. The power flow is used to analyze the power grid power flow exceeding the limit, and the sensitivity is used to build a security correction optimization model.

4. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1 is characterized by: The effective section for effective constraint identification is the transmission section that will restrict the operation of the unit during grid operation. The identification method is as follows: According to the power flow results of the transmission section F s,t The physical transmission limit P of the transmission section max,s The relationship between them is used to classify the effective types of transmission sections: If |F s,t |<σ*P max,s , then the transmission section s is an invalid section in time period t; If |F s,t |≥σ*P max,s , then the transmission section S is the effective section in time period t; Where, σ is the effective constraint determination coefficient; The method for determining the provinces participating in the adjustment is as follows: If the valid equipment / section is within the province, the province where the equipment / section is located will participate in the adjustment independently; If the valid equipment / section is an inter-provincial equipment / section, all provinces connected to the equipment / section will participate in the adjustment.

5. The method for rapid security correction of regional power grids with multi-strategy coordination according to claim 1 is characterized in that: The safety correction model that takes into account unit output adjustment only optimizes unit output. The unit start and stop status, inter-provincial port plan, and inter-regional tie line plan are all known parameters, and are based on the data reported by the provincial power grid. The optimization objective function of the safety correction model taking into account the unit output adjustment is as follows: Where N is the total number of units; T is the total number of time considered in the calculation; NS is the total number of equipment / sections; ΔP i,t Represents the output adjustment of unit i at time t; M p M is the penalty factor for unit output adjustment; b is the penalty factor for power generation and consumption balance constraint; M s is the penalty factor of equipment / section s at time t; are the positive and negative slack variables of the power generation and consumption balance constraint at time t; are the forward and reverse power flow relaxation variables of equipment / section s at time t, respectively; are the positive and negative slack variables of the power generation and consumption balance constraint at time t; The constraints of the safety correction model taking into account the unit output adjustment include provincial balance constraints, unit output adjustment amount, unit output upper and lower limits, unit output ramp-up and grid security constraints; among which: Provincial balance constraints: The total output of each province's units is equal to the difference between the short-term forecast value of the provincial system load and the inter-provincial exchange power, as shown in the following formula: Where, P i,t represents the output of unit i at time t; Assemble the units for Province A; represents the initial inter-provincial power exchange plan of province a at time t; D a,t is the system load of province a at time t; Definition of unit output adjustment: Where: is the output plan of unit i at time t reported by the province or city, is the power market clearing result of each provincial power grid, ΔP i,t is the planned output adjustment of unit i at time t; Upper and lower limit constraints of unit output: Where U i,t is the start and stop status of unit i at time t. If the unit is shut down, U i,t =0, through this constraint condition, the unit output can be limited to 0. When the unit is started, U i,t =1, this constraint is the conventional upper and lower limit constraint of output; is the minimum technical output of unit i at time t; is the maximum technical output of unit i at time t; Unit output climbing constraint: Where, is the maximum climbing grade of unit i, is the maximum downhill climb of unit i; when the unit is at the start-up moment, the unit's output range is determined by the unit's allowable startup rate, η i,t is the unit startup integer variable, η i,t =1 means that unit i is started at time t; when the unit is at the shutdown moment, the unit's output reduction range is determined by the unit's allowable shutdown rate; γ i,t is the unit startup integer variable, γ i,t =1 means unit i is shut down at time t; Transmission equipment / section power flow constraints: The equipment / section power flow constraints for the first iteration of the safety correction model and safety verification can be described as follows: The equipment / section power flow constraints cleared from the second round of safety verification and subsequent iterations can be described as follows: Where, P i,t is the active power of unit i in period t; D is the active power of the unit i in the last round of period t; k,t is the bus load value of node k in period T; are the forward and reverse power transmission limits of equipment / section s respectively; G s-i G is the generator output power transfer distribution factor of the node where unit i is located to the equipment / section s; s-k is the output power transfer distribution factor of node k to device / section s; G s-j is the output power transfer distribution factor of the node where the tie line j is located to the equipment / section s; are the forward and reverse power flow relaxation variables of equipment / section s respectively; It is the AC power flow of the last round of safety correction results of equipment / section s in period t.

6. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1 is characterized in that: The time period merging safety correction model taking into account unit output, start and stop, inter-provincial interface, and out-of-region DC adjustment, and its time period merging method includes the following steps: Let L t is the system load in period t, then the system load change rate in adjacent periods t and t+1 is: Calculate the system load change rate for all time periods and find the minimum change rate ΔL t The corresponding time period; Merge periods t and t+1 into a new period; Minimum change rate ΔL t Whether it is greater than the set threshold, or whether the number of time periods remaining after merging reaches the preset number, the judgment condition is effective, and the time period merging is completed; otherwise, the system load change rate of the adjacent time periods t and t+1 is recalculated.

7. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1 is characterized in that: The objective function of the period-merged safety correction model taking into account unit output, start-stop, inter-provincial interface, and DC adjustment outside the region is expressed as: Where N is the total number of units; T is the total number of periods after the safety correction period is merged; NS is the total number of equipment / sections; DN is the total number of DC tie lines; NT is the province and city aggregate; ΔP i,t Indicates the output adjustment of unit i at time t; ΔP d,t is the planned adjustment amount of DC tie line d at time t; U is the start / stop status of unit i in period t reported by each province and city; i,t is the start and stop status of the unit i in time period t after calculation; is the inter-provincial exchange power plan originally planned for province a during period t; T a,t M is the inter-provincial exchange power plan for the calculated province a period t; d M is the penalty factor for the planned adjustment of the DC tie line; a M is the penalty factor for adjusting the inter-provincial exchange power plan; p M is the penalty factor for unit output adjustment; u M is the penalty factor for the start and stop changes of the unit; b is the penalty factor for power generation and consumption balance constraint; M s is the penalty factor of equipment / section s at time t; are the positive and negative slack variables of the power generation and consumption balance constraint at time t; are the forward and reverse power flow relaxation variables of equipment / section s at time t.

8. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 7 is characterized in that: The optimization objective function of the period-merged safety correction model considering the unit output-start-stop-inter-provincial port-out-region DC adjustment includes multiple penalty factors, and the order of the penalty factors from large to small is as follows: balance constraint relaxation penalty factor M b , Power grid security constraint relaxation penalty factor M s , DC tie line planned adjustment penalty factor M d , inter-provincial exchange power plan adjustment penalty factor M a , penalty factor m for unit start and stop changes u , Penalty factor M for unit output adjustment p , adjust in order from large to small.

9. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 7 is characterized in that: When constructing a time-phased safety correction model that takes into account unit output, start-up and shutdown, inter-provincial ports, and DC adjustments outside the region, the following constraints need to be established: Provincial balance constraints: After the inter-provincial port plan and the inter-regional connection line plan are adjusted, the provincial balance constraints are modified to: Where, P i,t represents the output of unit i at time t, the decision variable; is the collection of units in province a; T a,t represents the inter-provincial exchange power of province a at time t; D a,t is the system load of province a at time t; Minimum continuous start and stop time constraints for units: Where, T U 、T D The minimum continuous start time and minimum continuous stop time of the unit; The time that the unit i has been continuously started and stopped during period t can be expressed as the state variable U i,t To express: Unit startup and shutdown switching variable constraints: Where η i,t is the unit startup integer variable, η i,t =1 means the unit i is started during period t; when the unit is shut down, γ i,t is the unit startup integer variable, γ i,t =1 means the unit i is shut down during period t and the following conditions are met: Inter-provincial exchange plan power balance constraints: The adjustment amount of inter-provincial exchange power of each province in the region must satisfy the requirement that the cumulative change of inter-provincial exchange power is equal to the cumulative change of DC power outside the region. The specific expression is: Definition of HVDC transmission plan adjustment amount: Where: is the initial transmission plan of DC transmission channel d at time t; P d,t is the active power of DC transmission channel d at time t; Constraints on inter-provincial power distribution of DC tie lines: After the DC power is connected to the grid at the DC converter station, it is distributed to each province and city in a certain proportion, meeting the following constraints: Where: r d,a is the power allocation factor of DC transmission channel d to province a; ΔDT a,t It represents the change in inter-provincial exchange power caused by DC changes outside the region at time t in province a under the jurisdiction of the sub-center. The allocation factor must meet the following conditions: DC tie line power limit constraints: Due to the physical properties of the DC tie line, the planned power of the DC tie line cannot exceed the maximum value allowed and cannot be lower than the minimum value allowed, and must meet the following constraints: Where, is the minimum power limit of the DC tie line d at time t; is the maximum power limit of the DC tie line d at time t; DC tie line power converter station allocation constraints: After the DC power is connected to the grid at the DC converter station, it is distributed to each province and city in a certain proportion, meeting the following constraints: Where, v d,h is the power allocation factor of DC transmission channel d to converter station h; Δp h,t Indicates the planned adjustment amount of converter station power; the allocation factor must meet the following conditions: ∑h ∈H v d, h=1。 10. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1, characterized in that: The full-time safety correction model taking into account the unit output-inter-provincial port-extra-regional DC adjustment is based on the unit operating status calculated by the period-merged safety correction model taking into account the unit output-start and stop-inter-provincial port-extra-regional DC adjustment. The unit operating status of the merged period is assigned to the full period and fixed as a known parameter. Only the unit output, inter-provincial port plan and extra-regional DC plan are adjusted; the constraints related to the unit operating status are eliminated from the constraint conditions.

11. The method for rapid security correction of a regional power grid with multi-strategy coordination according to claim 1, characterized in that: Based on the calculation results of the full-time security correction model that takes into account the unit output, inter-provincial interface, and out-of-region DC adjustment, the regional power grid security verification calculation is carried out to analyze the over-limit situation of regional power grid equipment / section power flow. If new over-limit equipment / section is added, it is added to the security correction model that takes into account the unit output adjustment. Through iterative calculation, a correction result that satisfies the regional power grid security is finally obtained, including: Safety verification uses AC power flow calculation to analyze the over-limit situation of regional power grid equipment / power flow after safety correction, and sends new over-limit equipment and over-limit time periods for safety correction; Carry out iterative calculations of safety correction and safety verification until no equipment in the regional power grid exceeds the limit or the maximum number of iterations is reached.

12. A multi-strategy coordinated regional power grid rapid security correction system, characterized by: include: Scenario generation module, used to obtain boundary data and calculation cycles for regional power grid security correction from regional and provincial power grid D5000 or new generation control systems, and generate regional power grid security correction calculation scenarios; The power grid security analysis module is used to carry out regional power grid security verification calculations based on the security correction calculation scenario of the regional power grid, and analyze the flow exceeding the limit of the provincial power grid tidal equipment / section within the regional power grid; The identification module is used to identify valid devices / sections and determine the provinces participating in the adjustment. If there are devices / sections exceeding the limit in the regional power grid, the module identifies the valid sections for regional power grid security correction based on the power flow results of the transmission section. The module also determines the provincial power grids participating in the regional power grid security correction based on the valid devices / sections, narrowing the scope of security correction adjustment and improving the calculation efficiency of security correction in subsequent steps. A safety correction model construction module that takes into account unit output adjustment is used to construct a regional power grid safety correction model with the unit output of the provincial power grid participating in the regional power grid safety correction as the decision variable. Based on the safety correction model, a safety-constrained economic dispatch algorithm is used to adjust the unit output of the provincial power grid participating in the regional power grid safety correction to eliminate equipment / section power flow exceeding the limit; A module for constructing a time-period-merged safety correction model that takes into account unit output, start-stop, inter-provincial connection, and external DC adjustment is used to address situations where the safety correction model taking into account unit output adjustment cannot eliminate equipment / section over-limit situations. A time-period-merged safety correction model for the regional power grid is constructed with unit output, unit start-stop, inter-provincial connection plan, and external connection line plan as decision variables. Based on the time-period-merged safety correction model, a safety-constrained unit commitment algorithm is used to sequentially adjust each decision variable to eliminate power flow over-limit situations. A full-time security correction model construction module that takes into account the adjustment of unit output, inter-provincial ports, and external DC is used to establish a full-time security correction model for the regional power grid based on the unit start-stop status calculated by the period-merged security correction model that takes into account unit output, start-stop, inter-provincial ports, and external DC adjustments. Based on the full-time security correction model, a security-constrained economic dispatch algorithm is used to sequentially optimize unit output, inter-provincial port plans, and external tie line plans to eliminate power flow over-limits. The iterative calculation module is used to carry out regional safety verification calculations based on the calculation results of the full-time safety correction model that takes into account the unit output-inter-provincial interface-extra-regional DC adjustment, analyze the over-limit situation of regional power grid equipment / section power flow, and add the newly over-limit equipment / section to the safety correction model that takes into account the unit output adjustment, re-carry out the safety correction optimization solution, and finally obtain the correction results that meet the regional power grid safety through iterative calculation.

13. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The boundary data generated by the scenario includes provincial power grid system data, unit data, tie line data, load data and unit group data; the calculation period is the shortest clearing period of the provincial power grid under the jurisdiction of the regional power grid.

14. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The power grid security analysis adopts a provincial balance calculation strategy and simultaneously calculates power flow and sensitivity. The power flow is used to analyze the power grid power flow exceeding the limit, and the sensitivity is used to build a security correction optimization model.

15. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The effective section for effective constraint identification is the transmission section that will restrict the operation of the unit during grid operation. The identification method is as follows: According to the power flow results of the transmission section F s,t The physical transmission limit P of the transmission section max,s The relationship between them is used to classify the effective types of transmission sections: If |F s,t |<σ*P max,s , then the transmission section s is an invalid section in time period t; If |F s,t |≥σ*P max,s , then the transmission section s is an effective section in time period t; Where, σ is the effective constraint determination coefficient; The method for determining the provinces participating in the adjustment is as follows: If the valid equipment / section is within the province, the province where the equipment / section is located will participate in the adjustment independently; If the valid equipment / section is an inter-provincial equipment / section, all provinces connected to the equipment / section will participate in the adjustment.

16. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The safety correction model that takes into account unit output adjustment only optimizes unit output. The unit start and stop status, inter-provincial port plan, and inter-regional tie line plan are all known parameters, and are based on the data reported by the provincial power grid. The optimization objective function of the safety correction model taking into account the unit output adjustment is as follows: Where N is the total number of units; T is the total number of time considered in the calculation; NS is the total number of equipment / sections; ΔP i,t Represents the output adjustment of unit i at time t; M p M is the penalty factor for unit output adjustment; b is the penalty factor for power generation and consumption balance constraint; M s is the penalty factor of equipment / section s at time t; are the positive and negative slack variables of the power generation and consumption balance constraint at time t; are the forward and reverse power flow relaxation variables of equipment / section s at time t, respectively; are the positive and negative slack variables of the power generation and consumption balance constraint at time t; The constraints of the safety correction model taking into account the unit output adjustment include provincial balance constraints, unit output adjustment amount, unit output upper and lower limits, unit output ramp-up and grid security constraints; among which: Provincial balance constraints: The total output of each province's units is equal to the difference between the short-term forecast value of the provincial system load and the inter-provincial exchange power, as shown in the following formula: Where, P i,t represents the output of unit i at time t; Assemble the units for Province A; represents the initial inter-provincial power exchange plan of province a at time t; D a,t is the system load of province a at time t; Definition of unit output adjustment: Where: is the output plan of unit i at time t reported by the province or city, is the power market clearing result of each provincial power grid, ΔP i,t is the planned output adjustment of unit i at time t; Upper and lower limit constraints of unit output: Where U i,t is the start and stop status of unit i at time t. If the unit is shut down, U i,t =0, through this constraint condition, the unit output can be limited to 0. When the unit is started, U i,t =1, this constraint is the conventional upper and lower limit constraint of output; is the minimum technical output of unit i at time t; is the maximum technical output of unit i at time t; Unit output climbing constraint: Where, is the maximum climbing grade of unit i, is the maximum downhill climb of unit i; when the unit is at the start-up moment, the unit's output range is determined by the unit's allowable startup rate, η i,t is the unit startup integer variable, η i,t =1 means that unit i is started at time t; when the unit is at the shutdown moment, the unit's output reduction range is determined by the unit's allowable shutdown rate; γ i,t is the unit startup integer variable, γ i,t =1 means unit i is shut down at time t; Transmission equipment / section power flow constraints: The equipment / section power flow constraints for the first iteration of the safety correction model and safety verification can be described as follows: The equipment / section power flow constraints cleared from the second round of safety verification and subsequent iterations can be described as follows: Where, P i,t is the active power of unit i in period t; D is the active power of the unit i in the last round of period t; k,t is the bus load value of node k in period t; are the forward and reverse power transmission limits of equipment / section s respectively; G s-i G is the generator output power transfer distribution factor of the node where unit i is located to the equipment / section s; s-k is the output power transfer distribution factor of node k to device / section s; G s-j is the output power transfer distribution factor of the node where the tie line j is located to the equipment / section s; are the forward and reverse power flow relaxation variables of equipment / section s respectively; It is the AC power flow of the last round of safety correction results of equipment / section s in period t.

17. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The time period merging safety correction model taking into account unit output, start and stop, inter-provincial interface, and out-of-region DC adjustment, and its time period merging method includes the following steps: Let L t is the system load in period t, then the system load change rate in adjacent periods t and t+1 is: Calculate the system load change rate for all time periods and find the minimum change rate ΔL t The corresponding time period; Merge periods t and t+1 into a new period; Minimum change rate ΔL t Whether it is greater than the set threshold, or whether the number of time periods remaining after merging reaches the preset number, the judgment condition is effective, and the time period merging is completed; otherwise, the system load change rate of the adjacent time periods t and t+1 is recalculated.

18. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The objective function of the period-merged safety correction model taking into account unit output, start-stop, inter-provincial interface, and DC adjustment outside the region is expressed as: Where N is the total number of units; T is the total number of periods after the safety correction period is merged; NS is the total number of equipment / sections; DN is the total number of DC tie lines; NT is the province and city aggregate; ΔP i,t Indicates the output adjustment of unit i at time t; ΔP d,t is the planned adjustment amount of DC tie line d at time t; U is the start / stop status of unit i in period t reported by each province and city; i,t is the start and stop status of the unit i in time period t after calculation; is the inter-provincial exchange power plan originally planned for province a during period t; T a,t M is the inter-provincial exchange power plan for the calculated province a period t; d M is the penalty factor for the planned adjustment of the DC tie line; a M is the penalty factor for adjusting the inter-provincial exchange power plan; p M is the penalty factor for unit output adjustment; u M is the penalty factor for the start and stop changes of the unit; b is the penalty factor for power generation and consumption balance constraint; M d is the penalty factor of equipment / section s at time t; are the positive and negative slack variables of the power generation and consumption balance constraint at time t; are the forward and reverse power flow relaxation variables of equipment / section s at time t.

19. The multi-strategy coordinated regional power grid rapid security correction system according to claim 18, characterized in that: The optimization objective function of the period-merged safety correction model considering the unit output-start-stop-inter-provincial port-out-region DC adjustment includes multiple penalty factors, and the order of the penalty factors from large to small is as follows: balance constraint relaxation penalty factor M b , Power grid security constraint relaxation penalty factor M s , DC tie line planned adjustment penalty factor M d , inter-provincial exchange power plan adjustment penalty factor M a , change the penalty factor M for unit start and stop u , Penalty factor M for unit output adjustment p , adjust in order from large to small.

20. The multi-strategy coordinated regional power grid rapid security correction system according to claim 18, characterized in that: When constructing a time-phased safety correction model that takes into account unit output, start-up and shutdown, inter-provincial ports, and DC adjustments outside the region, the following constraints need to be established: Provincial balance constraints: After the inter-provincial port plan and the inter-regional connection line plan are adjusted, the provincial balance constraints are modified to: Where, P i,t represents the output of unit i at time t, the decision variable; is the collection of units in province a; T a,t represents the inter-provincial exchange power of province a at time t; D a,t is the system load of province a at time t; Minimum continuous start and stop time constraints for units: Where, T U 、T D The minimum continuous start time and minimum continuous stop time of the unit; The time that the unit i has been continuously started and stopped during period t can be expressed as the state variable U i,t To express: Unit startup and shutdown switching variable constraints: Where η i,t is the unit startup integer variable, η i,t =1 means the unit i is started during period t; when the unit is shut down, γ i,t is the unit startup integer variable, γ i,t =1 means the unit i is shut down during period t and the following conditions are met: Inter-provincial exchange plan power balance constraints: The adjustment amount of inter-provincial exchange power of each province in the region must satisfy the requirement that the cumulative change of inter-provincial exchange power is equal to the cumulative change of DC power outside the region. The specific expression is: Definition of HVDC transmission plan adjustment amount: Where: is the initial transmission plan of DC transmission channel d at time t; P d,t is the active power of DC transmission channel d at time t; Constraints on inter-provincial power distribution of DC tie lines: After the DC power is connected to the grid at the DC converter station, it is distributed to each province and city in a certain proportion, meeting the following constraints: Where: r d,a is the power allocation factor of DC transmission channel d to province a; ΔDT a,t It represents the change in inter-provincial exchange power caused by DC changes outside the region at time t in province a under the jurisdiction of the sub-center. The allocation factor must meet the following conditions: DC tie line power limit constraints: Due to the physical properties of the DC tie line, the planned power of the DC tie line cannot exceed the maximum value allowed and cannot be lower than the minimum value allowed, and must meet the following constraints: Where, is the minimum power limit of the DC tie line d at time t; is the maximum power limit of the DC tie line d at time t; DC tie line power converter station allocation constraints: After the DC power is connected to the grid at the DC converter station, it is distributed to each province and city in a certain proportion, meeting the following constraints: Where, v d,h is the power allocation factor of DC transmission channel d to converter station h; Δp h,t Indicates the planned adjustment amount of converter station power; the allocation factor must meet the following conditions: ∑ h∈H v d,h ＝1。 21. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: The full-time safety correction model taking into account the unit output-inter-provincial port-extra-regional DC adjustment is based on the unit operating status calculated by the period-merged safety correction model taking into account the unit output-start and stop-inter-provincial port-extra-regional DC adjustment. The unit operating status of the merged period is assigned to the full period and fixed as a known parameter. Only the unit output, inter-provincial port plan and extra-regional DC plan are adjusted; the constraints related to the unit operating status are eliminated from the constraint conditions.

22. The multi-strategy coordinated regional power grid rapid security correction system according to claim 12, characterized in that: Based on the calculation results of the full-time security correction model that takes into account the unit output, inter-provincial interface, and out-of-region DC adjustment, the regional power grid security verification calculation is carried out to analyze the over-limit situation of regional power grid equipment / section power flow. If new over-limit equipment / section is added, it is added to the security correction model that takes into account the unit output adjustment. Through iterative calculation, a correction result that satisfies the regional power grid security is finally obtained, including: Safety verification uses AC power flow calculation to analyze the over-limit situation of regional power grid equipment / power flow after safety correction, and sends new over-limit equipment and over-limit time periods for safety correction; Carry out iterative calculations of safety correction and safety verification until no equipment in the regional power grid exceeds the limit or the maximum number of iterations is reached.

23. A multi-strategy coordinated regional power grid rapid security correction device, characterized in that: The electronic device comprises a processor and a memory, wherein the memory stores computer instructions, and the processor is used to execute the computer instructions stored in the memory. When the computer instructions are executed by the processor, the electronic device implements the steps of the multi-strategy coordinated regional power grid rapid security correction method as described in any one of claims 1 to 11.

24. A computer-readable storage medium, characterized in that The computer-readable storage medium stores a computer program, which, when executed by a processor, implements the steps of the multi-strategy coordinated regional power grid rapid security correction method according to any one of claims 1 to 11.

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