Abstract
The integration of European electricity markets aims at market coupling among interconnected power systems and the evolution of environmentally friendly technologies. This process is anticipated to utilize more efficiently the flexible generation and interconnections transmission capacity and provide environmental and economic benefits to final consumers. This paper presents a mixed integer linear programming model for the optimal scheduling of a power system (unit commitment problem) simulating the day-ahead electricity market. The model determines the optimal daily power generation mix, the electricity trade with neighboring countries, the evolution of the system's marginal price and the resulting environmental impact. The model incorporates CO2 emissions intensity constraints and introduces flexible ramping products, in addition to reserve requirements, aiming to identify their impacts on both operational and economic decisions. The model is applied on the Greek power system and its interconnections with neighboring power systems in Southeast Europe. The proposed approach can provide useful insights on the optimal generation and interconnections portfolio that meets the real electricity market operating needs of contemporary power systems with environmental and ramping capacity constraints.
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Notes
European day-ahead power markets are steadily adopting a single price coupling algorithm, which has the name of EUPHEMIA (acronym of Pan-European Hybrid Electricity Market Integration Algorithm).
Abbreviations
- AU:
-
Autumn
- DEM:
-
Demand
- EXP:
-
Exports
- GAMS:
-
General Algebraic Modelling System
- HYD:
-
Hydroelectric
- IMP:
-
Imports
- LIG:
-
Lignite
- LOS:
-
Losses
- MILP:
-
Mixed Integer Linear Programming
- NG:
-
Natural gas
- NGCC:
-
Natural gas combined cycle
- NGOC:
-
Natural gas open cycle
- RES:
-
Renewable energy sources
- RMR-dn:
-
Ramp-down capability requirements
- RMR-up:
-
Ramp-up capability requirements
- RR-dn:
-
Down reserve requirements
- RR-up:
-
Up reserve requirements
- SM:
-
Summer
- SMP:
-
System's marginal price
- SP:
-
Spring
- TSO:
-
Transmission system operator
- Wd:
-
Weekday
- Wk:
-
Weekend
- WN:
-
Winter
- \(f^{h}\) :
-
Set of power capacity blocks f of each hydroelectric unit h
- \(f^{i}\) :
-
Set of power capacity blocks f of each interconnection in
- \(f^{th}\) :
-
Set of power capacity blocks f of each thermal unit th
- \(ng^{cc}\) :
-
Set of natural gas-fired combined cycle units
- \(ng^{gt}\) :
-
Set of natural gas-fired gas turbine units
- h :
-
Set of hydroelectric units
- \(ht\) :
-
Set of hydrothermal units (thermal and hydroelectric)
- a :
-
Set of all units (thermal, hydroelectric, and renewables)
- az :
-
Set of unit a belonging to zone z
- iz :
-
Set of interconnection in belonging to zone z
- dt :
-
Set of representative days
- in :
-
Set of interconnections
- lg :
-
Set of lignite-fired units
- ng :
-
Set of natural gas-fired units (combined cycle and gas turbines)
- res :
-
Set of renewable energy sources
- st :
-
Set of lignite-fired and natural gas-fired combined cycle units
- t :
-
Set of time periods
- th :
-
Set of thermal units (lignite-fired and natural gas-fired units)
- z :
-
Set of zones
- \(BE_{{in,f^{i} ,t,dt}}\) :
-
Power capacity quantity of each exports interconnection in in operational block \(f^{i}\) during time period t and representative day dt (MW)
- \(BI_{{in,f^{i} ,t,dt}}\) :
-
Power capacity quantity of each imports interconnection in in operational block \(f^{i}\) during time period t and representative day dt (MW)
- \(BO_{in,t,dt}\) :
-
Border price of each interconnection in during time period t and representative day dt (€/MWh)
- \(BP_{{ht,f^{ht} ,t,dt}}\) :
-
Power capacity quantity of each hydrothermal unit ht in operational block \(f^{ht}\) during time period t and representative day dt (MW)
- \(CEC_{th,t,dt}\) :
-
CO2 emissions cost of each thermal unit th during time period t and representative day dt (€/MWh)
- \(CE_{{in,f^{i} ,t,dt}}\) :
-
Power capacity price of each exports interconnection in in operational block \(f^{i}\) during time period t and representative day dt (€/MWh)
- \(CE_{ht}\) :
-
CO2 emissions coefficient of each hydrothermal unit ht (tCO2/MWh)
- \(CI_{{in,f^{i} ,t,dt}}\) :
-
Power capacity price of each imports interconnection in in operational block \(f^{i}\) during time period t and representative day dt (€/MWh)
- \(CL_{t,dt}\) :
-
Net load difference between time periods t and \(t - 1\) during representative day \(td\) (MW)
- \(CP_{{ht,f^{ht} ,t,dt}}\) :
-
Power capacity price of each hydrothermal unit ht in operational block \(f^{ht}\) during time period t and representative day dt (€/MWh)
- \(DD_{t,dt}\) :
-
Power demand of the studied system during time period t and representative day dt (MW)
- \(EC_{in,t,dt}\) :
-
Capacity of exports interconnection in during time period t and representative day dt (MW)
- \(FC_{th,t,dt}\) :
-
Fuel cost of each thermal unit th during time period t and representative day \(dt\) (€/MWh)
- \(IC_{in,t,dt}\) :
-
Capacity of imports interconnection in during time period t and representative day dt (MW)
- \(IC_{in,t,dt}^{min}\) :
-
Technical minimum capacity of imports interconnection in during time period \(t\) and representative day dt (MW)
- \(MVC_{th,t,dt}\) :
-
Minimum average variable cost of each thermal unit th during time period t and representative day dt (€/MWh)
- \(MUT_{ht}\) :
-
Minimum up time of each hydrothermal unit ht (h)
- \(MDT_{ht}\) :
-
Minimum down time of each hydrothermal unit ht (h)
- \(Max_{t,dt}^{Po}\) :
-
Capacity of the largest available thermal unit th during time period t and representative day dt (MW)
- \(NE_{t,a,dt}\) :
-
Net power injections efficiency coefficient of each unit a during time period t and representative day dt (p.u.)
- \(NL_{t,dt}\) :
-
System net load during time period t and representative day dt (MW)
- \(OVC_{th,t,dt}\) :
-
Other variable cost of each thermal unit th during time period t and representative day dt (€/MWh)
- \(P_{ht,dt}^{ini}\) :
-
Initial power output (at the last hour of the previous day) of each hydrothermal unit ht during representative day dt (MW)
- \(P_{ht,t,dt}^{max}\) :
-
Technical maximum of each hydrothermal unit ht during time period t and representative day dt (MW)
- \(P_{ht,t,dt}^{min}\) :
-
Technical minimum of each hydrothermal unit ht during time period t and representative day dt (MW)
- \(P_{t,a,dt}^{fix}\) :
-
Fixed (mandatory) power output of each unit a during time period t and representative day dt (MW)
- \(R_{ht}^{dn}\) :
-
Ramp-down rate of each hydrothermal unit ht (MW/min)
- \(R_{ht}^{up}\) :
-
Ramp-up rate of each hydrothermal unit ht (MW/min)
- \(R_{in}^{im,dn}\) :
-
Ramp-down rate of each interconnection in (MW/min)
- \(R_{in}^{im,up}\) :
-
Ramp-up rate of each interconnection in (MW/min)
- \(RR_{t,dt}^{dn}\) :
-
System ramp-down capability requirements during time period t and representative day dt (MW)
- \(RR_{t,dt}^{up}\) :
-
System ramp-up capability requirements during time period t and representative day dt (MW)
- \(SD_{ht}\) :
-
Shut-down cost of each hydrothermal unit th (€)
- \(rd_{ht,t,dt}\) :
-
Contribution of hydrothermal unit ht in downward reserve during time period t and representative day dt (MW)
- \(rmd_{ht,t,dt}\) :
-
Contribution of hydrothermal unit ht in ramp-down capability requirements during time period t and representative day dt (MW)
- \(rmu_{ht,t,dt}\) :
-
Contribution of hydrothermal unit ht in ramp-up capability requirements during time period t and representative day dt (MW)
- \(ru_{ht,t,dt}\) :
-
Contribution of hydrothermal unit ht in upward reserve during time period t and representative day dt (MW)
- \(ep_{{in,f^{i} ,t,dt}}\) :
-
Power exports from interconnection in in operational block \(f^{i}\) during time period t and representative day dt (MW)
- \(ex_{in,t,dt}\) :
-
Power exports from interconnection in during time period t and representative day dt (MW)
- \(im_{in,t,dt}\) :
-
Power imports from interconnection in during time period t and representative day dt (MW)
- \(ip_{{in,f^{i} ,t,dt}}\) :
-
Power imports from interconnection in in operational block \(f^{i}\) during time period t and representative day dt (MW)
- \(pp_{{ht,f^{ht} ,t,dt}}\) :
-
Power output of hydrothermal unit ht in operational block \(f^{ht}\) during time period t and representative day dt (MW)
- \(p_{ht,t,dt}\) :
-
Power output of hydrothermal unit ht during time period t and representative day dt (MW)
- \(rd_{in,t,dt}^{im}\) :
-
Contribution of interconnection in in downward reserve during time period t and representative day dt (MW)
- \(rmd_{in,t,dt}^{im}\) :
-
Contribution of interconnection in in ramp-down capability requirements during time period t and representative day dt (MW)
- \(rmu_{in,t,dt}^{im}\) :
-
Contribution of interconnection in in ramp-up capability requirements during time period t and representative day dt (MW)
- \(ru_{in,t,dt}^{im}\) :
-
Contribution of interconnection in in upward reserve during time period t and representative day dt (MW)
- \(u_{ht,t,dt}\) :
-
1, if hydrothermal unit ht is operational during time period t and representative day dt
- \(u_{ht,t,dt}^{sd}\) :
-
1, if hydrothermal unit ht shuts-down during time period t and representative day dt
- \(u_{ht,t,dt}^{st}\) :
-
1, if hydrothermal unit ht starts-up during time period t and representative day dt
- \(u_{in,t,dt}^{im}\) :
-
1, if there is imported energy from interconnection in during time period t and representative day dt
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Koltsaklis, N.E., Dagoumas, A.S. A power system scheduling model with carbon intensity and ramping capacity constraints. Oper Res Int J 21, 647–687 (2021). https://doi.org/10.1007/s12351-018-0440-z
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DOI: https://doi.org/10.1007/s12351-018-0440-z