CN109558628A - A kind of coordination optimizing method and system of real-time generation schedule - Google Patents
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Abstract
The present invention provides a kind of coordination optimizing method of real-time generation schedule and systems, comprising: obtain level-2 area grid power vacancy, calculate level-2 area power grid can security invocation spare capacity；When the vacancy of level-2 area grid power be greater than level-2 area power grid can safety calling spare capacity when, by establishing the real-time generation optimization plan of level-2 area, adjust level-2 area grid dispatching management unit generation；If level-2 area grid dispatching management unit generation amount is not enough to make up level-2 area grid power vacancy, by establishing two stage optimization method, the real-time generation optimization plan of level-1 area power grid is established, level-1 area grid dispatching management unit generation is adjusted.State point saves integrated regulating object design after this method is suitable for extensive power missing, is quickly adjusted to electric network active jointly by scheduling at different levels, eliminates influence caused by high-power missing.
Description
Technical Field
The invention relates to the field of electric power, in particular to a method and a system for coordinated optimization of a real-time power generation plan.
Background
Energy resources in China are rich, but geographical distribution is extremely uneven and cloudy, and the distribution characteristics of more north, less south and more west, less east and more west are presented, for example, more than 70% of energy resources such as coal resources and water energy resources in China are distributed in the northwest region, while the economic development and consumption level of the region in China are just opposite to the energy resources and the reverse distribution situation of the load center establish the basic pattern and the development strategy of the power resources in China, namely, west-east power transmission, south-north mutual supply and national networking, and the potential of long-distance and large-capacity power transmission such as extra-high voltage alternating current and extra-high voltage direct current is imperative. Especially, the ultra-high voltage direct current transmission system has the characteristics of large capacity, controllability, flexibility and the like, and is widely applied to the aspects of interconnection in large areas in China, long-distance and large-capacity transmission of north electricity south electricity transmission and west electricity east electricity transmission, cross-channel gorge electricity transmission and the like.
At present, with the continuous deepening of the construction of an extra-high voltage interconnected power grid, the scale of the power grid is rapidly enlarged, the structure of the power grid is increasingly complex, and national networking is basically formed. The operation integration degree of the power grid is greatly improved, 500 KV interconnected power grids which are pulled by hands nearby are developed into uniform power grids connected by extra-high voltage main racks, the alternating current and electric connection is tight, the alternating current and direct current exchange capacity is large, the mutual influence and interaction of all levels of power grids are further enhanced, and the power grid characteristics are changed from a partition mode to an overall mode. The rapid increase of the power transmission capacity provides solid and reliable hardware guarantee for the optimal allocation of resources and the effective consumption of new energy in a large range, but simultaneously brings new challenges for the safe and stable operation of a power grid. Among these challenges, how to deal with the large-scale rate missing problem caused by the fault of the extra-high voltage ac/dc interconnection line is a problem which needs to be solved urgently.
An emergency lockout fault or an extra-high voltage alternating current line fault of an extra-high voltage direct current transmission system can cause a transmitting end system to generate power surplus and a receiving end system to generate large power loss, and if a transmitting end power grid is connected to the network only through an extra-high voltage line or the system is disconnected after the extra-high voltage line fault occurs, a large amount of power loss can cause the frequency of the receiving end system to fluctuate greatly. Therefore, aiming at the development trend and the practical requirements of 'alternating current-direct current coupling, transmitting-receiving end coupling and upper-lower stage coupling' of an extra-high voltage large power grid, a plan optimization and adjustment technology in a day for coping with regional mutual economy of large-scale power loss is researched and developed.
Disclosure of Invention
The invention provides a method and a system for coordinating and optimizing a real-time power generation plan, which aim to solve the problem of large-scale loss caused by faults of an extra-high voltage alternating current-direct current interconnection line in the prior art.
The technical scheme provided by the invention is as follows:
a method of coordinated optimization of a real-time power generation plan, comprising:
acquiring the power shortage of the secondary area power grid, and calculating the standby capacity which can be safely called by the secondary area power grid;
when the shortage of the power of the secondary area power grid is larger than the safe calling reserve capacity of the secondary area power grid, adjusting the power generation of a secondary area power grid dispatching management unit by establishing a secondary area real-time power generation optimization plan;
if the generated energy of the secondary area power grid dispatching management unit is not enough to make up the power shortage of the secondary area power grid, a primary area power grid real-time power generation optimization plan is established by establishing a two-stage optimization method, and the power generation of the primary area power grid dispatching management unit is adjusted.
Preferably, the formula for calculating the backup capacity that can be safely called by the secondary regional power grid is as follows:
wherein: sResReserve capacity, S, for the safe deployment of the secondary regional power gridmReserve capacity, S, that can be safely called for secondary regional grid dispatch management unitsnThe reserve capacity which can be safely called for a primary regional power grid dispatching management unit; sAGCmSafe calling spare capacity, S, of AGC unit for secondary regional power grid dispatching management unitAGCnThe standby capacity can be safely called for a primary regional power grid dispatching management unit AGC unit; k is a radical ofmScheduling and managing standby safety proportionality coefficients of AGC units for a secondary regional power grid; k is a radical ofnDispatching a standby safety proportionality coefficient of an AGC unit of a management unit for a primary regional power grid; cAGCmFor the second-level regional gridThe spare capacity of an AGC unit of the degree management unit; cNAGCmThe spare capacity of the non-AGC machine set; cAGCnThe standby capacity of an AGC unit of a management unit is scheduled for a first-level regional power grid; cNAGCnAnd dispatching the spare capacity of a non-AGC unit of the management unit for the primary regional power grid.
Preferably, the establishing of the secondary region real-time power generation optimization plan includes:
based on generalized tie line plan constraints, unit output constraints, unit climbing constraints and line power constraints, the minimum power generation cost is taken as an adjustment target, and a real-time power generation optimization plan of a secondary area is established by adjusting generalized tie line plan relaxation variables of each secondary area power grid dispatching management unit in a primary area.
Preferably, the adjustment target is calculated according to the following formula, including:
the objective function for implementing the power generation optimization model among the secondary regional power grids is calculated according to the following formula:
in the formula: fpThe power generation cost of the internal combustion engine group in the secondary regional power grid is obtained; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated; delta Pm,tPlanning a relaxation variable for the generalized tie line at the provincial dispatching moment t;penalizing cost for unit slack; f (P)mi,t) Generating cost of the internal combustion engine set m in the secondary regional power grid in the time period t; n is a radical ofmThe total number of equivalent thermal power generating units in the secondary regional power grid; t is the number of scheduling time segments;
the constraint conditions of the real-time power generation optimization model between the secondary regional power grids comprise: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
Preferably, the generalized tie-line plan constraint is:
wherein,predicting power for the ultrashort-term load at the m-th moment t;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;predicting power for the new energy ultra-short term output at the time t of provincial dispatching m;planning total power of the thermal power generating unit at the moment t of provincial dispatching m in real time;planning the total power of the hydropower generating unit at the m-time t for province regulation in real time; delta Pm,tLoad deviation of the province m at the time t; gm,tThe total output at the moment t of province m; pm,maxThe maximum output power of the unit is adjusted for the province; pn,maxAnd (4) backing up the maximum output power of the management unit n for the primary regional power grid.
Preferably, the unit output constraint is as follows:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
wherein, PTi,maxThe maximum technical output power of the equivalent thermal power generating unit is obtained; pTi,tThe total output power of the thermal power at the moment t is obtained; pHi,maxThe maximum technical output power of the equivalent hydroelectric generating set; pHi,tThe total output power of the water, the electricity and the electricity at the moment t; pNi,maxThe maximum technical output power of the equivalent new energy unit is obtained; pNi,tThe total output power of the equivalent new energy at the moment t; pTi,minThe minimum technical output power P of an equivalent thermal power generating unitHi,minMinimum technical power, P, for equivalent hydropowerNi,minThe minimum technical output power of the equivalent new energy unit.
Preferably, the unit climbing restriction is as follows:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power is the climbing power (MW/h) of the thermal power generating unit i in unit time;the output power of the thermal power generating unit i at the moment t is obtained;and the output power of the thermal power generating unit i at the moment t-1 is obtained.
Preferably, the line power constraint is:
in the formula:a lower power limit for the transmission capacity of the ith link;the power upper limit of the transmission capacity of the ith tie line;and (4) when the transmission power of the line i at the moment t is calculated, the generated power of the primary regional power grid dispatching management unit is the planned generated power before the day.
Preferably, the establishing of the first-level regional power grid-level real-time power generation optimization plan includes:
based on generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint, the minimum power generation cost is taken as an adjustment target, and a first-level regional power grid-level real-time power generation optimization plan is established by adjusting generalized tie line plan relaxation variables of each first-level regional power grid scheduling management unit in a first-level region
Preferably, the adjustment target is calculated as follows:
in the formula,. DELTA.Pn,tScheduling and managing a generalized tie line plan relaxation variable at a time t in a unit n for a primary regional power grid; fRGenerating cost of the thermal power generating unit in the first-level regional power grid level power grid; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated;penalizing cost for unit slack; f (P)ni,t) Generating cost of the thermal power generating unit n in the first-level regional power grid-level power grid in the period t; n is a radical ofnThe total number of equivalent thermal power generating units in the primary regional power grid level power grid is set;
the constraints of the generalized tie plan within the first-level regional power grid include: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
Preferably, the generalized tie-line plan constraints include:
in the formula:planning the total output power of the thermal power generating unit at the moment n and t for the first-level regional power grid dispatching management unit in real time;scheduling and managing the hydroelectric generating set of the set at the n moment t for the primary regional power grid to output total power in real time;scheduling and managing a new energy unit of the unit at the n moment t for a first-level regional power grid to output total power in real time;predicting power for the ultrashort-term load at the m-th moment t;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;predicting power, delta P, for the new energy ultra-short term output at time t of provincial dispatching mm,tLoad deviation of the province m at the time t; gm,tThe total force at time t for province m.
Preferably, the unit output constraint includes:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
in the formula: pTi,maxThe maximum technical output power of the thermal power generating unit is obtained; pHi,maxThe maximum technical output power of the hydroelectric generating set; pNi,maxThe maximum technical output power of the new energy unit; pTi,minThe minimum technical output power of the thermal power generating unit is obtained; pHi,minThe minimum technical output power of the hydroelectric generating set; pNi,minThe minimum technical output power of the new energy unit.
Preferably, the unit climbing restraint includes:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power (MW/h) is the climbing power of the thermal power generating unit i in unit time.
Preferably, the line power constraint includes:
in the formula:a lower power limit for the transmission capacity of the ith link;the power upper limit of the transmission capacity of the ith connecting line;and (4) when calculating the transmission power of the line i at the moment t, adopting real-time plan generated power for the generated power of the secondary regional power grid dispatching management unit.
A coordinated optimization system of a real-time power generation plan, comprising:
a spare capacity acquisition module: acquiring the power shortage of the secondary area power grid, and calculating the standby capacity which can be safely called by the secondary area power grid;
a secondary real-time power generation planning module: when the shortage of the power of the secondary area power grid is larger than the safe calling reserve capacity of the secondary area power grid, adjusting the power generation of a secondary area power grid dispatching management unit by establishing a secondary area real-time power generation optimization plan;
a first-level real-time power generation planning module: if the generated energy of the secondary area power grid dispatching management unit is not enough to make up the power shortage of the secondary area power grid, a primary area power grid real-time power generation optimization plan is established by establishing a two-stage optimization method, and the power generation of the primary area power grid dispatching management unit is adjusted.
Preferably, the spare capacity acquiring module calculates the spare capacity that can be safely called by the secondary regional power grid according to the following formula:
wherein: sResReserve capacity, S, for the safe deployment of the secondary regional power gridmReserve capacity, S, that can be safely called for secondary regional grid dispatch management unitsnThe reserve capacity which can be safely called for a primary regional power grid dispatching management unit; sAGCmFor dispatching and managing AGC unit of unit for secondary regional power gridCan safely call the reserve capacity, SAGCnThe standby capacity can be safely called for a primary regional power grid dispatching management unit AGC unit; k is a radical ofmScheduling and managing standby safety proportionality coefficients of AGC units for a secondary regional power grid; k is a radical ofnDispatching a standby safety proportionality coefficient of an AGC unit of a management unit for a primary regional power grid; cAGCmThe standby capacity of an AGC unit of a management unit is scheduled for a secondary regional power grid; cNAGCmThe spare capacity of the non-AGC machine set; cAGCnThe standby capacity of an AGC unit of a management unit is scheduled for a first-level regional power grid; cNAGCnAnd dispatching the spare capacity of a non-AGC unit of the management unit for the primary regional power grid.
Preferably, the secondary real-time power generation planning module includes:
a secondary real-time power generation plan submodule: based on generalized tie line plan constraints, unit output constraints, unit climbing constraints and line power constraints, the minimum power generation cost is taken as an adjustment target, and a real-time power generation optimization plan of a secondary area is established by adjusting generalized tie line plan relaxation variables of each secondary area power grid dispatching management unit in a primary area.
Compared with the prior art, the invention has the beneficial effects that: the invention provides a method and a system for coordinating and optimizing a real-time power generation plan, which comprise the following steps: the method comprises the following steps: acquiring the power shortage of the provincial power grid, and calculating the reserve capacity which can be safely called by the provincial power grid; step two: when the shortage of the provincial power grid power is larger than the safe calling reserve capacity of the provincial power grid, adjusting the provincial dispatching unit to generate power by establishing a provincial real-time power generation optimization plan; step three: if the generated energy of the provincial dispatching unit is not enough to make up the power shortage of the provincial power grid, a regional real-time power generation optimization plan is established by establishing a two-stage optimization method, the power generation of the network dispatching unit is adjusted, and the power shortage of the provincial power grid is made up. The method is suitable for national province and province integrated adjustment object design after large-scale power loss, and the active power of the power grid is rapidly adjusted through all levels of scheduling together, so that the influence caused by high-power loss is eliminated.
Drawings
FIG. 1 is a flow chart of a method of coordinated optimization of a real-time power generation plan according to the present invention;
FIG. 2 is a schematic diagram of a power generation plan relationship of a national province three-level power grid of the invention;
fig. 3 is a flow chart of coordination of the national province real-time power generation plan of the invention.
Detailed Description
For a better understanding of the present invention, reference is made to the following description taken in conjunction with the accompanying drawings and examples.
Example 1:
fig. 1 is a flowchart of a method for coordinating and optimizing a real-time power generation plan according to the present invention, and as shown in fig. 1, the method for coordinating and optimizing a real-time power generation plan according to the present invention includes:
acquiring the power shortage of the secondary area power grid, and calculating the standby capacity which can be safely called by the secondary area power grid;
when the shortage of the power of the secondary area power grid is larger than the safe calling reserve capacity of the secondary area power grid, adjusting the power generation of a secondary area power grid dispatching management unit by establishing a secondary area real-time power generation optimization plan;
if the generated energy of the secondary area power grid dispatching management unit is not enough to make up the power shortage of the secondary area power grid, a primary area power grid real-time power generation optimization plan is established by establishing a two-stage optimization method, and the power generation of the primary area power grid dispatching management unit is adjusted.
The calculation formula of the backup capacity which can be safely called by the secondary regional power grid is as follows:
wherein: sResReserve capacity, S, for the safe deployment of the secondary regional power gridmReserve capacity, S, that can be safely called for secondary regional grid dispatch management unitsnThe reserve capacity which can be safely called for a primary regional power grid dispatching management unit; sAGCmSafe calling spare capacity, S, of AGC unit for secondary regional power grid dispatching management unitAGCnThe standby capacity can be safely called for a primary regional power grid dispatching management unit AGC unit; k is a radical ofmScheduling and managing standby safety proportionality coefficients of AGC units for a secondary regional power grid; k is a radical ofnDispatching a standby safety proportionality coefficient of an AGC unit of a management unit for a primary regional power grid; cAGCmThe standby capacity of an AGC unit of a management unit is scheduled for a secondary regional power grid; cNAGCmThe spare capacity of the non-AGC machine set; cAGCnThe standby capacity of an AGC unit of a management unit is scheduled for a first-level regional power grid; cNAGCnAnd dispatching the spare capacity of a non-AGC unit of the management unit for the primary regional power grid.
The establishment of the secondary region real-time power generation optimization plan comprises the following steps:
based on generalized tie line plan constraints, unit output constraints, unit climbing constraints and line power constraints, the minimum power generation cost is taken as an adjustment target, and a real-time power generation optimization plan of a secondary area is established by adjusting generalized tie line plan relaxation variables of each secondary area power grid dispatching management unit in a primary area.
The adjustment target is calculated according to the following formula, including:
the objective function for implementing the power generation optimization model among the secondary regional power grids is calculated according to the following formula:
in the formula: fpThe power generation cost of the internal combustion engine group in the secondary regional power grid is obtained; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated; delta Pm,tPlanning a relaxation variable for the generalized tie line at the m-time t of province tuning;penalizing cost for unit slack; f (P)mi,t) Generating cost of the internal combustion engine set m in the secondary regional power grid in the time period t; n is a radical ofmThe total number of equivalent thermal power generating units in the secondary regional power grid; t is the number of scheduling time segments;
the constraint conditions of the real-time power generation optimization model between the secondary regional power grids comprise: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
The generalized tie-line plan constraints are:
wherein,ultra-short-term load prediction at the time t of m province;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;for the ultra-short term output prediction of new energy at the time t of provincial dispatching m, real-time planned power output total of thermal power generating unit for adjusting m time t for provinceAnd, planning the total power sum of the hydroelectric generating set at the moment t of provincial dispatching m in real time,
ΔPm,tto account for the load deviation of m at time t. Gm,tThe total output of the province m at the moment t; pm,maxThe maximum output power of the unit is adjusted for the province; pn,maxAnd scheduling and managing the maximum output power of the unit n for the primary regional power grid.
The unit output constraint is as follows:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
wherein, PTi,maxThe maximum technical output of the equivalent thermal power generating unit is obtained; pT,itThe total output of the thermal power at the moment t; pHi,maxThe maximum technical output of the equivalent hydroelectric generating set; PH and it are the total output of the water, the electricity and the electricity at the moment t; pNi,maxThe maximum technical output of the equivalent new energy unit is obtained; PN and it are the total output of the equivalent new energy at the moment t; pTi,minThe minimum technical output, P, of the equivalent thermal power generating unitHi,minMinimum technical output, P, for equivalent hydropowerNi,minThe minimum technical output of the equivalent new energy unit is obtained.
The unit climbing restraint is as follows:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power (MW/h) is the climbing power of the thermal power generating unit i in unit time.
The line power constraint is:
in the formula:the lower limit of the transmission capacity of the ith connecting line;the upper limit of the transmission capacity of the ith tie line;and (4) when the transmission power of the line i at the moment t is calculated, the generated power of the primary regional power grid dispatching management unit is the planned generated power before the day.
The establishment of the first-level regional power grid-level real-time power generation optimization plan comprises the following steps:
based on generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint, the minimum power generation cost is taken as an adjustment target, and a first-level regional power grid-level real-time power generation optimization plan is established by adjusting generalized tie line plan relaxation variables of each first-level regional power grid scheduling management unit in a first-level region
The adjustment target is calculated as follows:
in the formula,. DELTA.Pn,tPlanning a relaxation variable for a generalized tie line at a moment t in a primary regional power grid; fRGenerating cost of the thermal power generating unit in the first-level regional power grid level power grid; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated; delta Pn,tPlanning a relaxation variable for a generalized tie line of a primary regional power grid dispatching management unit n at a time t;penalizing cost for unit slack; f (P)ni,t) Generating cost of the thermal power generating unit n in the first-level regional power grid-level power grid in the period t; n is a radical ofnThe total number of equivalent thermal power generating units in the primary regional power grid level power grid is set;
the constraints of the generalized tie plan within the first-level regional power grid include: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
The generalized tie-line plan constraint comprising:
in the formula:planning the output sum of the thermal power generating units at the moment t of the primary regional power grid dispatching management unit n in real time, planning the output sum of the hydroelectric generating set at the moment t of the primary regional power grid dispatching management set n in real time, planning the output sum of a new energy unit at the moment t of the n for the first-level regional power grid dispatching management unit in real time, ultra-short-term load prediction at the time t of m province;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;forecasting the ultra-short term output of the new energy at the time t of provincial dispatching m; delta Pm,tLoad deviation of the province m at the time t; gm,tThe total output of the province m at the moment t; pm,maxThe maximum output power of the unit is adjusted for the province; pn,maxAnd scheduling and managing the maximum output power of the unit n for the primary regional power grid.
The unit output constraint includes:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
in the formula: pTi,maxThe maximum technical output of the thermal power generating unit is obtained; pHi,maxThe maximum technical output of the hydroelectric generating set is obtained; pNi,maxThe maximum technical output of the new energy unit is obtained; pTi,minThe minimum technical output of the thermal power generating unit is obtained; pHi,minThe minimum technical output of the hydroelectric generating set is obtained; pNi,minThe minimum technical output is provided for the new energy unit.
The unit climbing restraint includes:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power (MW/h) is the climbing power of the thermal power generating unit i in unit time.
The line power constraint comprising:
in the formula:the lower limit of the transmission capacity of the ith connecting line;the upper limit of the transmission capacity of the ith connecting line;and (4) when calculating the transmission power of the line i at the moment t, adopting real-time plan generated power for the generated power of the secondary regional power grid dispatching management unit.
Based on the same invention concept, the invention also provides a coordination optimization system of the real-time power generation plan, which comprises the following steps:
a spare capacity acquisition module: acquiring the power shortage of the secondary area power grid, and calculating the standby capacity which can be safely called by the secondary area power grid;
a secondary real-time power generation planning module: when the shortage of the power of the secondary area power grid is larger than the safe calling reserve capacity of the secondary area power grid, adjusting the power generation of a secondary area power grid dispatching management unit by establishing a secondary area real-time power generation optimization plan;
a first-level real-time power generation planning module: if the generated energy of the secondary area power grid dispatching management unit is not enough to make up the power shortage of the secondary area power grid, a primary area power grid real-time power generation optimization plan is established by establishing a two-stage optimization method, and the power generation of the primary area power grid dispatching management unit is adjusted.
The spare capacity acquisition module calculates the spare capacity which can be safely called by the secondary regional power grid according to the following formula:
wherein: sResReserve capacity, S, for the safe deployment of the secondary regional power gridmReserve capacity, S, that can be safely called for secondary regional grid dispatch management unitsnThe reserve capacity which can be safely called for a primary regional power grid dispatching management unit; sAGCmSafe calling spare capacity, S, of AGC unit for secondary regional power grid dispatching management unitAGCnThe standby capacity can be safely called for a primary regional power grid dispatching management unit AGC unit; k is a radical ofmScheduling and managing standby safety proportionality coefficients of AGC units for a secondary regional power grid; k is a radical ofnDispatching a standby safety proportionality coefficient of an AGC unit of a management unit for a primary regional power grid; cAGCmThe standby capacity of an AGC unit of a management unit is scheduled for a secondary regional power grid; cNAGCmThe spare capacity of the non-AGC machine set; cAGCnThe standby capacity of an AGC unit of a management unit is scheduled for a first-level regional power grid; cNAGCnAnd dispatching the spare capacity of a non-AGC unit of the management unit for the primary regional power grid.
The secondary real-time power generation planning module comprises:
a secondary real-time power generation plan submodule: based on generalized tie line plan constraints, unit output constraints, unit climbing constraints and line power constraints, the minimum power generation cost is taken as an adjustment target, and a real-time power generation optimization plan of a secondary area is established by adjusting generalized tie line plan relaxation variables of each secondary area power grid dispatching management unit in a primary area.
The adjustment target of the secondary real-time power generation plan submodule is calculated according to the following formula, and the adjustment target comprises the following steps:
in the formula: fpThe power generation cost of the internal combustion engine group in the secondary regional power grid is obtained; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated; delta Pm,tPlanning a relaxation variable for the generalized tie line at the m-time t of province tuning;penalizing cost for unit slack; f (P)mi,t) Generating cost of the internal combustion engine set m in the secondary regional power grid in the time period t; n is a radical ofmThe total number of equivalent thermal power generating units in the secondary regional power grid; t is the number of scheduling time segments;
the constraint conditions of the real-time power generation optimization model between the secondary regional power grids comprise: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
The generalized tie-line plan constraint of the secondary real-time power generation plan sub-module is calculated according to the following formula:
wherein,ultra-short-term load prediction at the time t of m province;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;for the ultra-short term output prediction of new energy at the time t of provincial dispatching m, planning the total power sum of the thermal power generating unit at the moment t of provincial dispatching m in real time, planning the total power sum of the hydroelectric generating set at the moment t of provincial dispatching m in real time,
the unit output constraint of the secondary real-time power generation plan submodule is calculated according to the following formula:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
wherein, PTi,maxThe maximum technical output of the equivalent thermal power generating unit is obtained; pHi,maxThe maximum technical output of the equivalent hydroelectric generating set; pNi,maxThe maximum technical output of the equivalent new energy unit is obtained; pTi,minThe minimum technical output, P, of the equivalent thermal power generating unitHi,minFor minimum skill of equivalent hydropowerOperative force, PNi,minThe minimum technical output of the equivalent new energy unit is obtained.
The unit climbing restraint is as follows:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power (MW/h) is the climbing power of the thermal power generating unit i in unit time.
The line power constraint of the secondary real-time power generation plan submodule is calculated according to the following formula:
in the formula:the lower limit of the transmission capacity of the ith connecting line;the upper limit of the transmission capacity of the ith tie line;and (4) when the transmission power of the line i at the moment t is calculated, the generated power of the primary regional power grid dispatching management unit is the planned generated power before the day.
The primary real-time power generation planning module comprises:
a first-level real-time power generation plan submodule: based on generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint, the minimum power generation cost is taken as an adjustment target, and a first-level regional power grid-level real-time power generation optimization plan is established by adjusting generalized tie line plan relaxation variables of each first-level regional power grid scheduling management unit in a first-level region
The adjustment target of the primary real-time power generation planning module is calculated according to the following formula:
in the formula,. DELTA.Pn,tPlanning a relaxation variable for a generalized tie line at a moment t in a primary regional power grid; fRGenerating cost of the thermal power generating unit in the first-level regional power grid level power grid; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated; delta Pn,tPlanning a relaxation variable for a generalized tie line of a primary regional power grid dispatching management unit n at a time t;penalizing cost for unit slack; f (P)ni,t) Generating cost of the thermal power generating unit n in the first-level regional power grid-level power grid in the period t; n is a radical ofnThe total number of equivalent thermal power generating units in the primary regional power grid level power grid is set;
the constraints of the generalized tie plan within the first-level regional power grid include: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
The generalized tie line plan constraint of the primary real-time power generation plan module is calculated according to the following formula:
in the formula:scheduling management for primary regional power gridThe thermal power generating unit at the moment t of the unit n plans to obtain the total power in real time, planning the output sum of the hydroelectric generating set at the moment t of the primary regional power grid dispatching management set n in real time, planning the output sum of a new energy unit at the moment t of the n for the first-level regional power grid dispatching management unit in real time, ultra-short-term load prediction at the time t of m province;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;forecasting the ultra-short term output of the new energy at the time t of provincial dispatching m; delta Pm,tTo account for the load deviation of m at time t. Gm,tThe total force at time t for province m.
The unit output constraint of the primary real-time power generation planning module is calculated according to the following formula:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
in the formula: pTi,maxThe maximum technical output of the thermal power generating unit is obtained; pHi,maxThe maximum technical output of the hydroelectric generating set is obtained; pNi,maxThe maximum technical output of the new energy unit is obtained; pTi,minThe minimum technical output of the thermal power generating unit is obtained; pHi,minThe minimum technical output of the hydroelectric generating set is obtained; pNi,minThe minimum technical output of the new energy unit is obtained; pT,itThe total output of the thermal power at the moment t; pH,itThe total output of water, electricity and electricity at the moment t; pN,itThe total output of the equivalent new energy at the moment t.
The unit climbing constraint of the primary real-time power generation planning module is calculated according to the following formula:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power (MW/h) is the climbing power of the thermal power generating unit i in unit time.
The line power constraint of the primary real-time power generation planning module is calculated according to the following formula:
in the formula:the lower limit of the transmission capacity of the ith connecting line;for transmission capacity of ith linkAn upper limit;and (4) when calculating the transmission power of the line i at the moment t, adopting real-time plan generated power for the generated power of the secondary regional power grid dispatching management unit.
Example 3:
china's electric power system adopts the mode of ' unified scheduling, hierarchical management '. However, with the continuous deepening of the construction of the extra-high voltage interconnected power grid, the power grids in each region are in increasingly close contact, a partition and province-dividing balance mode is gradually broken through, a pattern of coordinated development of all levels of power grids is gradually formed, all levels of power grids need integrated coordinated operation and unified coordinated operation control, and resource optimization configuration in a larger range can be achieved, so that all levels of scheduling have independent services and have an incidence relation of mutual influence.
In terms of the current three-level scheduling plan mode, the main business of national dispatching is to compile a large-area tie line plan, complete annual and monthly power transactions of a large area and ensure reasonable distribution of cross-area power supply plans. The main business of the branch center is to compile an inter-provincial tie line plan, complete inter-provincial secondary distribution of the large-area tie line plan and ensure the reasonability of inter-provincial electric power trade execution and direct-regulating power plant plan. The main service of provincial dispatching is to compile an intra-provincial power plant plan so as to ensure the implementation of three-way, energy conservation and emission reduction and the operation safety of a power grid.
The generator set mainly comprises a thermal power generating unit, a hydroelectric generating unit and a new energy source unit. As for the generator set dispatching management, the generator sets in a provincial region can be divided into a provincial power grid dispatching management set (provincial dispatching set) and a regional power grid dispatching management set (network dispatching set). The former executes a dispatching plan compiled by a provincial power grid dispatching center, and the latter executes a dispatching plan compiled by a regional power grid dispatching center (sub-center).
In terms of system load, the load in a province is balanced by the following four aspects of power.
(1) Saving and adjusting the generating power of the unit;
(2) the generated power of the network dispatching unit;
(3) connecting lines in the regional power grid feed power;
the regional inter-grid links feed power, which is forwarded through the regional intra-grid links if there are no regional inter-grid links in the province.
The provincial power balance equation is as follows:
in the formula: pLThe total load of the network is saved;
PTm、PWm、PNmgenerating power for the power-saving and regulating unit, the hydroelectric unit and the new energy source unit respectively;
PTn、PWn、PNngenerating power for the grid regulated power supply, the hydropower station and the new energy source unit respectively;
the power input through the inter-provincial link and the inter-regional link, respectively.
The relation among three-level power grid power generation plans of a national grid, a regional power grid (sub-center) and a provincial power grid is shown in fig. 2, wherein the inter-regional tie line plan is compiled by a national grid dispatching center.
In actual operation, when a high-power loss is caused by a serious fault of an extra-high voltage direct current system or an extra-high voltage alternating current and other feed-in lines, the safe and stable operation of the system is ensured through control measures such as a generator tripping, load shedding, direct current modulation and the like according to a preset strategy table. However, the emergency control measures for maintaining transient stability usually cannot fill up the power shortage of the system, and further cannot ensure long-term stable and economic operation of the system after high power is lost.
At the present stage, a day-ahead power generation plan optimization model is commonly used in domestic power grids at all levels, but the day-ahead system load prediction, the day-ahead new energy output prediction and the day-ahead model mode have large deviation from the actual mode, so that the day-ahead power generation plan needs to be adjusted greatly in the actual execution, and huge pressure is brought to the real-time adjustment of automatic power generation control (AGC). Generally, real-time power generation planning is adopted as the correction of a day-ahead plan, a unit power generation plan of 1h in the future is calculated by taking ultra-short-term prediction data as a basis and 5min as a period, and the day-ahead power generation plan is corrected in a periodic rolling manner. The real-time power generation planning system is practically operated in a regional power grid and a provincial power grid, the real-time power generation planning grid-province coordination mainly takes provincial balance as a main part, and planning is carried out between provinces by taking a geographic interconnection line as a gateway, but the actual condition that only part of generator sets in the provincial region are managed by provincial power grid dispatching and a plurality of generator sets in the provincial region are managed by regional power grid dispatching is not considered.
Based on the power generation plan before the network province day, the intra-area tie line plan and the inter-area tie line plan, after high power is lost, the process of the national province real-time power generation plan coordination scheme is shown in fig. 3.
After a certain province has high power loss, the specific flow of the national province real-time power generation plan coordination is as follows:
the method comprises the following steps: acquiring the power shortage of the provincial network, calculating the safe calling reserve capacity of the provincial internal unit, and comparing;
step two: if the power shortage is larger than the spare capacity which can be safely called by the provincial unit, the power support of other provincial networks in the region is preferentially considered, and the method is implemented in the mode that a branch center (network dispatching) modifies the inter-provincial connecting line;
step three: the provincial power grid compiles a real-time power generation plan according to ultra-short-term load prediction, ultra-short-term power generation prediction of a provincial dispatching new energy unit, a new inter-provincial connecting line plan, feed-in power outside an area after high power loss and the like, and guides the provincial dispatching unit to operate;
step four: and the regional power grid compiles a real-time power generation plan according to ultra-short-term load prediction, ultra-short-term power generation prediction of the new energy source unit for power grid regulation, real-time power generation plan shortage power of the provincial power grid, non-regional feed-in power after high power is lost and the like, and guides the regional power grid dispatching management unit to operate. If the provincial power grid dispatching management unit can meet the requirements of the provincial power grid real-time power generation plan, the regional power grid support is not needed, and at the moment, the shortage power of the provincial power grid real-time power generation plan is 0;
step five: if the regional power grid dispatching unit can meet the requirements of the real-time power generation plan of the regional power grid, national grid support is not needed, otherwise, the national grid needs to modify the inter-regional tie line plan and the process is repeated.
According to different control modes, the provincial units can be divided into four types: the system comprises a provincial dispatching AGC unit, a provincial dispatching non-AGC unit, a network dispatching AGC unit and a network dispatching non-AGC unit.
Suppose that the spare capacity of the provincial dispatching AGC unit is CAGCmSpare capacity of provincial dispatching non-AGC set is CNAGCmThe spare capacity of the network tuning AGC unit is CAGCnThe spare capacity of the network modulation non-AGC unit is CNAGCn. The spare capacity S can be safely adjusted within the provinceResComprises the following steps:
wherein: sm、SnThe spare capacity can be safely called for the provincial dispatching unit and the network dispatching unit respectively;
SAGCm、SAGCnthe spare capacity can be safely called for the provincial dispatching AGC unit and the network dispatching AGC unit respectively;
km、knthe standby safety proportionality coefficients of the provincial dispatching AGC unit and the network dispatching AGC unit are respectively.
In a modern power system, a multi-stage power dispatching center is generally established to perform distributed coordination dispatching on an interconnected system so as to reduce the calculation scale, reduce the data communication traffic and keep independent autonomous operation of each regional power grid, but the coordination work is complicated due to the relative independence of each stage of dispatching.
According to the technology, a generalized tie line plan is introduced firstly, and then a provincial real-time power generation plan model which is suitable for high-power deficiency, ultra-short-term load prediction and ultra-short-term new energy power generation prediction is constructed.
Under the current scheduling mode taking provinces as balance areas, the cross-province and cross-region resource optimization configuration is mainly embodied in the form of tie line plans. If the power shortage of a certain province is larger than the spare capacity which can be safely called by an intra-province unit, the power support of other provinces in the region is preferably considered, and the support is implemented in the form that a branch center (regional power grid dispatching center) modifies an inter-province contact line. Therefore, after the high power is lost, the inter-provincial link power optimization scheduling model needs to be established.
When the inter-provincial tie line power plan is modified after high power is lost, the following two aspects are mainly considered:
1. the power generation cost of the thermoelectric generator set in the region is the minimum;
2. the inter-provincial link power variation is as small as possible, and it is desirable to maintain the original inter-provincial link power and electric quantity.
Therefore, when the inter-provincial link power is deviated from the day-ahead inter-provincial link power after the high power is lost, the deviation is converted into a form of penalty cost and added to the objective function.
In the formula: f (P)i,t) Generating cost of the thermal power generating unit i in the t period;
Pi,tthe output of the thermal power generating unit i in the time period t is obtained;
Ptj,tthe j-th tie line power value in the t period in the day-ahead plan;
the j-th tie line power value in the modified t period;
c is a tie line power deviation penalty coefficient;
NTthe total number of equivalent thermal power generating units in the regional power grid;
NLthe number of inter-provincial communication lines;
t is the number of the scheduling time segments.
According to the direct current power flow calculation method, the following methods are provided:
P＝Bθ (4)
Pl＝YBAθ (5)
in the formula: p is the power column vector injected by each node;
b is a direct current network node admittance matrix;
theta is a node voltage phase angle column vector;
Plactive power column vectors for the branches;
YBa diagonal matrix formed for the branch admittance;
a is a network incidence matrix.
And (4) and (5) obtaining the relation between the branch power and the node active injection power.
Pl＝YBAB-1P (6)
(6) The formula also comprises the relation between the inter-provincial tie line power and the node active injection power, and after the formula (3) is substituted, the quantity to be solved in the objective function is only the node injection power.
Since the main research object is the provincial junctor power, the scheduling plan accurate to the unit is arranged to be considered in the provincial scheduling. Therefore, the power supply in the model is expressed into an equivalent unit according to the provinces, so that the analog calculation amount is greatly reduced. The following constraints are mainly considered in the optimization scheduling model.
1) Power balance constraint
In the formula: n is a radical ofT、NH、NNThe number of equivalent thermal power, hydroelectric power and new energy source units in the region is respectively;
PTi,t、PHj,t、PNk,tgenerating power of the ith equivalent thermal power generating unit, the jth equivalent hydroelectric generating unit and the kth equivalent new energy generating unit in t time period respectively;
PL,tis the sum of the local load and the outbound power during the t period.
2) Generated output constraint
PTi,min≤PTi,t≤PTi,max(8)
PHi,min≤PHi,t≤PHi,max(9)
PNi,min≤PNi,t≤PNi,max(10)
In the formula: pTi,max、PHi,max、PNi,maxRespectively equivalent thermal power, hydroelectric power and maximum technical output of a new energy unit;
PTi,min、PHi,min、PNi,minrespectively equivalent thermal power, hydroelectric power and minimum technical output of a new energy unit;
3) tie line power constraint
In the formula:the lower limit and the upper limit of the transmission capacity of the j-th connecting line are respectively.
Establishing a generalized tie-line plan: assuming that a certain provincial generator set comprises two parts, namely a provincial dispatching m and a network dispatching n, the day-ahead generalized tie line plan is defined as:
in the formula: pLm,tPredicting the system load before the m-th moment t day of province;
inputting power of province m through the inter-area connecting line;
PNm,tpredicting the output of new energy before the m-th moment of provincial dispatching;
PNn,tpredicting the output of new energy before the moment t day of network regulation n;
Pm,max、Pn,maxadjusting the installed capacity for m provinces and n net provinces;
PTm,t、PWm,tthe sum of the outputs of the thermal power generating unit and the hydroelectric generating unit at the moment t of provincial debugging m;
PTn,t、PWn,tthe total output of the thermal power generating unit and the hydroelectric generating unit at the moment t of grid regulation n;
Gm,tfor saving time m and tPlanning a day-ahead generalized tie line;
Gn,tplanning a day-ahead generalized tie line at the moment t of the network tone n.
From formulae (1), (13), (14), one can obtain:
in the formula:the power received by the intertexture line at time t of m province is the power received day ahead.
The formula shows that the sum of the province dispatching day-ahead generalized tie plan and the corresponding network dispatching day-ahead generalized tie plan is equal to the day-ahead power receiving plan of the province passing through the province interprovince tie, so that the actual interprovince tie power receiving plan can track the day-ahead generalized tie power receiving plan as long as the province level power grid and the regional power grid optimize the real-time power generation plan and track the day-ahead generalized tie plans, and the province level power grid and the regional power grid are guaranteed to run in parallel without mutual interference.
Establishing a provincial real-time power generation optimization model when high power is absent: the day-ahead power generation plan model is very perfect and widely applied, but due to the fact that loads, new energy day-ahead forecast and ultra-short-term forecast have large differences, high power loss is caused by faults of an extra-high voltage alternating current circuit or an extra-high voltage direct current system and the like, the day-ahead power generation plan cannot be continuously executed, and a real-time power generation plan must be compiled to be corrected in a rolling mode.
An objective function established by the provincial real-time power generation optimization model is as follows:
in the formula: delta Pm,tGeneralized junctor for adjusting m time t for provinceMarking a relaxation variable;
penalty cost per slack.
Constraint conditions established by the provincial real-time power generation optimization model are as follows:
generalized junctor plan constraints
In the formula:ultra-short-term load prediction at the time t of m province;
inputting power of a province m through an inter-area connecting line when high power is lost;
for the ultra-short term output prediction of new energy at the time t of provincial dispatching m,
planning the total power sum of the thermal power generating unit at the moment t of provincial dispatching m in real time,
to saveAdjusting the real-time planned total force of the hydroelectric generating set at the moment t,
unit output constraint
Reference is made to formulae (8), (9) and (10).
Unit climbing restraint
The unit climbing constraint is a coupling relation between output of units of adjacent time sections and reflects the regulation rate of the generated power of the units. The active power of the unit is adjusted by adjusting the steam inlet of the steam turbine, and when the flow of the steam inlet is increased, the active power of the unit is improved; when the flow of the steam inlet is reduced, the active power of the unit is reduced. This process, which is not instantaneous, requires a certain amount of time. Therefore, there is a limit to how much power the unit can be adjusted up (also known as ramping) or down (also known as landslide) per unit time. The ramp constraints of the unit can be expressed as follows:
in the formula:the landslide power (MW/h) of the thermal power generating unit i in unit time;
the climbing power (MW/h) of the thermal power generating unit i in unit time.
Line power constraint
In the formula:the lower limit and the upper limit of the transmission capacity of the ith connecting line are respectively;
and (4) when the transmission power of the line i at the moment t is calculated, the power generation power of the network dispatching unit takes the planned power generation power before the day.
When the real-time power generation plans of the regional power grid and the provincial power grid are coordinated and optimized, the real-time power generation plan optimization model of the regional power grid also introduces the planning constraint of the generalized tie lines before each grid adjustment day. The regional power grid comprises a plurality of provincial power grid dispatching units, generalized tie line plan constraints before the date of the power grid dispatching of a plurality of provinces exist, if the generalized tie line plan constraints before the date of the power grid dispatching of a certain province cannot be strictly established and overflow occurs, support is provided by the tie line dispatching units of other provinces, the fact that the regional power grid dispatching management unit integrally completes deviation bearing amount is guaranteed, however, the tie line plan constraints before the date of the power grid dispatching of the overflowing province and the generalized tie line plan constraints before the date of the power grid dispatching providing the supporting province cannot be strictly established, in order to distinguish the overflow and support states of the power grid dispatching, a two-stage optimization mode is adopted on the regional power grid side, and the tracking condition of the day-ahead generalized tie line plan of each tie line dispatching unit of.
Establishing an optimization model in the provincial phase when high power is absent:
an objective function established by an intra-provincial optimization model when high power is absent:
in the formula: delta Pn,tPlanning a relaxation variable for the generalized tie line at the moment t of the network tone n;
penalty cost per slack.
Constraint conditions established by the intra-provincial optimization model when high power is absent:
generalized junctor plan constraints
In the formula:planning the total output sum of the thermal power generating unit at the moment t of grid regulation n in real time,
planning the total power sum of the hydroelectric generating set at the moment t of network regulation n in real time,
planning the total output sum for the new energy unit at the moment t of the network regulation n in real time,
unit output restraint:
the output constraint of thermal power, hydroelectric power and new energy source units in the grid regulation unit refers to formulas (8) - (10).
Unit climbing restraint:
the climbing constraint of the grid thermal power regulating unit can refer to an equation (18).
Line power constraint:
the line power constraint can refer to the formula (19), but when the transmission power at the time t of the line i is calculated, the generating power of the provincial dispatching unit adopts the real-time planning generating power.
Establishing a regional phase optimization model when high power is lost: if Δ Pn,tAnd if the number is 0, the high-power loss, the provincial load prediction error, the new energy output prediction error and the like caused by the inter-regional tie line fault can be completely balanced by adjusting the output of the provincial dispatching unit and the network dispatching unit in the province. Otherwise, coordination optimization in the regional power grid needs to be started, and power balance can be realized only by the support of other provincial units.
An objective function established by an intra-provincial optimization model when high power is absent:
the optimization target is the total power generation cost of the internal combustion engine set in the region and the total balance constraint cost of the generalized tie lines of each network dispatching set in the region:
in the formula: delta PA,tThe general balance constraint relaxation variable of each network dispatching unit generalized tie line in the region is defined;
penalty cost per slack.
Constraint conditions established by the intra-provincial optimization model when high power is absent:
and (3) planning total balance constraint of each network dispatching unit generalized tie line in the area:
unit output restraint:
the output constraint of thermal power, hydroelectric power and new energy source units in the regional internal unit refers to the formulas (8) - (10).
Unit climbing restraint:
the climbing restraint of the thermoelectric generator set in the region can refer to the formula (17).
Line power constraint:
the line power constraint can be referred to as equation (18). However, when calculating the transmission power at time t on the line i, the power generation power in each province should be real-time planned.
If Δ PA,tAnd if the number is 0, the high-power loss, the provincial load prediction error, the new energy output prediction error and the like caused by the inter-area tie line fault can be completely balanced by adjusting the output of the unit in the area. Otherwise, the inter-regional power grid tie line power plan needs to be adjusted, and the power plan is supported by the units in other regions to balance the power.
The objective function, constraint condition and solving method of the inter-area tie power plan optimization model can completely refer to the objective function, constraint condition and solving method of the inter-provincial tie power plan optimization model.
It is to be understood that the embodiments described are only a few embodiments of the present invention, and not all embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
As will be appreciated by one skilled in the art, embodiments of the present application may be provided as a method, system, or computer program product. Accordingly, the present application may take the form of an entirely hardware embodiment, an entirely software embodiment or an embodiment combining software and hardware aspects. Furthermore, the present application may take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, and the like) having computer-usable program code embodied therein.
The present application is described with reference to flowchart illustrations and/or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the application. It will be understood that each flow and/or block of the flow diagrams and/or block diagrams, and combinations of flows and/or blocks in the flow diagrams and/or block diagrams, can be implemented by computer program instructions. These computer program instructions may be provided to a processor of a general purpose computer, special purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, create means for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be stored in a computer-readable memory that can direct a computer or other programmable data processing apparatus to function in a particular manner, such that the instructions stored in the computer-readable memory produce an article of manufacture including instruction means which implement the function specified in the flowchart flow or flows and/or block diagram block or blocks.
These computer program instructions may also be loaded onto a computer or other programmable data processing apparatus to cause a series of operational steps to be performed on the computer or other programmable apparatus to produce a computer implemented process such that the instructions which execute on the computer or other programmable apparatus provide steps for implementing the functions specified in the flowchart flow or flows and/or block diagram block or blocks.
The present invention is not limited to the above embodiments, and any modifications, equivalent replacements, improvements, etc. made within the spirit and principle of the present invention are included in the scope of the claims of the present invention which are filed as the application.
Claims (16)
1. A method for coordinated optimization of a real-time power generation plan, comprising:
acquiring the power shortage of the secondary area power grid, and calculating the standby capacity which can be safely called by the secondary area power grid;
when the shortage of the power of the secondary area power grid is larger than the safe calling reserve capacity of the secondary area power grid, adjusting the power generation of a secondary area power grid dispatching management unit by establishing a secondary area real-time power generation optimization plan;
if the generated energy of the secondary area power grid dispatching management unit is not enough to make up the power shortage of the secondary area power grid, a primary area power grid real-time power generation optimization plan is established by establishing a two-stage optimization method, and the power generation of the primary area power grid dispatching management unit is adjusted.
2. The coordinated optimization method according to claim 1, wherein the formula for calculating the backup capacity that can be safely called by the secondary regional power grid is as follows:
wherein: sResReserve capacity, S, for the safe deployment of the secondary regional power gridmReserve capacity, S, that can be safely called for secondary regional grid dispatch management unitsnThe reserve capacity which can be safely called for a primary regional power grid dispatching management unit; sAGCmSafe calling spare capacity, S, of AGC unit for secondary regional power grid dispatching management unitAGCnThe standby capacity can be safely called for a primary regional power grid dispatching management unit AGC unit; k is a radical ofmScheduling and managing standby safety proportionality coefficients of AGC units for a secondary regional power grid; k is a radical ofnDispatching a standby safety proportionality coefficient of an AGC unit of a management unit for a primary regional power grid; cAGCmThe standby capacity of an AGC unit of a management unit is scheduled for a secondary regional power grid; cNAGCmThe spare capacity of the non-AGC machine set; cAGCnThe standby capacity of an AGC unit of a management unit is scheduled for a first-level regional power grid; cNAGCnAnd dispatching the spare capacity of a non-AGC unit of the management unit for the primary regional power grid.
3. The method for coordinated optimization of real-time power generation plans of claim 1, wherein the establishing of the secondary region real-time power generation optimization plan comprises:
based on generalized tie line plan constraints, unit output constraints, unit climbing constraints and line power constraints, the minimum power generation cost is taken as an adjustment target, and a real-time power generation optimization plan of a secondary area is established by adjusting generalized tie line plan relaxation variables of each secondary area power grid dispatching management unit in a primary area.
4. A method of coordinated optimization of a real-time power generation plan as claimed in claim 3, wherein said adjustment objective is calculated as follows, comprising:
the objective function for implementing the power generation optimization model among the secondary regional power grids is calculated according to the following formula:
in the formula: fpThe power generation cost of the internal combustion engine group in the secondary regional power grid is obtained; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated; delta Pm,tPlanning a relaxation variable for the generalized tie line at the provincial dispatching moment t;penalizing cost for unit slack; f (P)mi,t) Generating cost of the internal combustion engine set m in the secondary regional power grid in the time period t; n is a radical ofmThe total number of equivalent thermal power generating units in the secondary regional power grid; t is the number of scheduling time segments;
the constraint conditions of the real-time power generation optimization model between the secondary regional power grids comprise: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
5. The method for coordinated optimization of a real-time power generation plan according to claim 3, wherein the generalized tie-line plan constraints are:
wherein,for saving m time t ultra-short term loadMeasuring power;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;predicting power for the new energy ultra-short term output at the time t of provincial dispatching m;planning total power of the thermal power generating unit at the moment t of provincial dispatching m in real time;planning the total power of the hydropower generating unit at the m-time t for province regulation in real time; delta Pm,tLoad deviation of the province m at the time t; gm,tThe total output at the moment t of province m; pm,maxThe maximum output power of the unit is adjusted for the province; pn,maxAnd (4) backing up the maximum output power of the management unit n for the primary regional power grid.
6. The method of claim 4, wherein the unit output constraints are:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
wherein, PTi,maxThe maximum technical output power of the equivalent thermal power generating unit is obtained; pTi,tThe total output power of the thermal power at the moment t is obtained; pHi,maxThe maximum technical output power of the equivalent hydroelectric generating set; pHi,tThe total output power of the water, the electricity and the electricity at the moment t; pNi,maxThe maximum technical output power of the equivalent new energy unit is obtained; pNi,tThe total output power of the equivalent new energy at the moment t; pTi,minIs the most equivalent of a thermal power generating unitSmall technical output power, PHi,minMinimum technical power, P, for equivalent hydropowerNi,minThe minimum technical output power of the equivalent new energy unit.
7. The method for coordinating and optimizing a real-time power generation plan according to claim 4, wherein the unit climbing constraints are as follows:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power is the climbing power (MW/h) of the thermal power generating unit i in unit time;the output power of the thermal power generating unit i at the moment t is obtained;and the output power of the thermal power generating unit i at the moment t-1 is obtained.
8. The method of claim 4, wherein the line power constraint is:
in the formula:a lower power limit for the transmission capacity of the ith link;the power upper limit of the transmission capacity of the ith tie line;and (4) when the transmission power of the line i at the moment t is calculated, the generated power of the primary regional power grid dispatching management unit is the planned generated power before the day.
9. The method for coordinating and optimizing the real-time power generation plan according to claim 1, wherein the establishing of the primary regional grid-level real-time power generation optimization plan comprises:
based on generalized tie line plan constraints, unit output constraints, unit climbing constraints and line power constraints, the minimum power generation cost is taken as an adjustment target, and a primary regional power grid-level real-time power generation optimization plan is established by adjusting generalized tie line plan relaxation variables of each primary regional power grid dispatching management unit in a primary region.
10. A method for coordinated optimization of a factual power generation plan as claimed in claim 9, wherein said adjustment objective is calculated as follows:
in the formula,. DELTA.Pn,tScheduling and managing a generalized tie line plan relaxation variable at a time t in a unit n for a primary regional power grid; fRGenerating cost of the thermal power generating unit in the first-level regional power grid level power grid; f0The power generation cost of the internal combustion engine group in the primary regional power grid is calculated;penalizing cost for unit slack; f (P)ni,t) Generating cost of the thermal power generating unit n in the first-level regional power grid-level power grid in the period t; n is a radical ofnThe total number of equivalent thermal power generating units in the primary regional power grid level power grid is set;
the constraints of the generalized tie plan within the first-level regional power grid include: the method comprises the following steps of generalized tie line plan constraint, unit output constraint, unit climbing constraint and line power constraint.
11. The coordinated optimization method of claim 9, wherein the generalized tie plan constraints comprise:
in the formula:planning the total output power of the thermal power generating unit at the moment n and t for the first-level regional power grid dispatching management unit in real time;scheduling and managing the hydroelectric generating set of the set at the n moment t for the primary regional power grid to output total power in real time;scheduling and managing a new energy unit of the unit at the n moment t for a first-level regional power grid to output total power in real time;predicting power for the ultrashort-term load at the m-th moment t;inputting the power of a secondary regional power grid m through a tie line between primary regional power grids when the high power is lost;predicting power, delta P, for the new energy ultra-short term output at time t of provincial dispatching mm,tLoad deviation of the province m at the time t; gm,tThe total force at time t for province m.
12. The coordinated optimization method of claim 9, wherein the crew contribution constraints comprise:
PTi,min≤PTi,t≤PTi,max
PHi,min≤PHi,t≤PHi,max
PNi,min≤PNi,t≤PNi,max
in the formula: pTi,maxThe maximum technical output power of the thermal power generating unit is obtained; pHi,maxThe maximum technical output power of the hydroelectric generating set; pNi,maxThe maximum technical output power of the new energy unit; pTi,minThe minimum technical output power of the thermal power generating unit is obtained; pHi,minThe minimum technical output power of the hydroelectric generating set; pNi,minThe minimum technical output power of the new energy unit.
13. The coordinated optimization method of claim 9, wherein the unit ramp-up constraints comprise:
in the formula:the power is the landslide power (MW/h) of the thermal power generating unit i in unit time;the power (MW/h) is the climbing power of the thermal power generating unit i in unit time.
14. The coordinated optimization method of claim 9, wherein the line power constraints comprise:
in the formula:a lower power limit for the transmission capacity of the ith link;the power upper limit of the transmission capacity of the ith connecting line;and (4) when calculating the transmission power of the line i at the moment t, adopting real-time plan generated power for the generated power of the secondary regional power grid dispatching management unit.
15. A system for coordinated optimization of a real-time power generation plan, comprising:
a spare capacity acquisition module: acquiring the power shortage of the secondary area power grid, and calculating the standby capacity which can be safely called by the secondary area power grid;
a secondary real-time power generation planning module: when the shortage of the power of the secondary area power grid is larger than the safe calling reserve capacity of the secondary area power grid, adjusting the power generation of a secondary area power grid dispatching management unit by establishing a secondary area real-time power generation optimization plan;
a first-level real-time power generation planning module: if the generated energy of the secondary area power grid dispatching management unit is not enough to make up the power shortage of the secondary area power grid, a primary area power grid real-time power generation optimization plan is established by establishing a two-stage optimization method, and the power generation of the primary area power grid dispatching management unit is adjusted.
16. The coordinated optimization system of claim 15, wherein the reserve capacity acquisition module calculates a reserve capacity that can be safely recalled by a secondary regional power grid by:
wherein: sResReserve capacity, S, for the safe deployment of the secondary regional power gridmReserve capacity, S, that can be safely called for secondary regional grid dispatch management unitsnThe reserve capacity which can be safely called for a primary regional power grid dispatching management unit; sAGCmSafe calling spare capacity, S, of AGC unit for secondary regional power grid dispatching management unitAGCnThe standby capacity can be safely called for a primary regional power grid dispatching management unit AGC unit; k is a radical ofmScheduling and managing standby safety proportionality coefficients of AGC units for a secondary regional power grid; k is a radical ofnDispatching a standby safety proportionality coefficient of an AGC unit of a management unit for a primary regional power grid; cAGCmThe standby capacity of an AGC unit of a management unit is scheduled for a secondary regional power grid; cNAGCmThe spare capacity of the non-AGC machine set; cAGCnThe standby capacity of an AGC unit of a management unit is scheduled for a first-level regional power grid; cNAGCnAnd dispatching the spare capacity of a non-AGC unit of the management unit for the primary regional power grid.
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