Abstract
To integrate renewable energy generation from wind and solar radiation, most combined heat and power (CHP) plants in northern China are undergoing large-scale upgrades and retrofitting to improve operational flexibility. Simultaneously, the downregulation service (DRS) market is still retained in the day-ahead market in many provinces. Considering a flexible CHP plant with multiple types of coal-fired CHP units and heat storage as a price taker, this paper establishes a collaborative bidding strategy for the CHP plant to participate in both the day-ahead energy market and day-ahead DRS market. The bidding strategy includes the optimal output decision model, power output range model, capacity segmenting model, and bidding models for two markets determined by the marginal generation cost (MGC) and the marginal downregulation cost (MDRC), respectively. These models are validated based on realistic data from a CHP plant in Northeast China.
Highlights
In China, to motivate thermal power plants to reduce their output of power to accumulate curtailed renewable power, such as wind power and PV power, the downregulation service (DRS) market[1] is designed to be a supplement to the bench-marking electricity price mechanism (BEPM)
L ( =P / P ) e,t,min plant e,t,min plant e,N plant of the combined heat and power (CHP) plant is greater than the baseline load rate Lsys of the downregulation market at a certain period, it means that the plant has the ability to participate in the energy market but no ability to participate in the downregulation market
This paper studied the bidding strategy of a flexible CHP plant with multiple types of CHP units and heat storage participating in a day-ahead market composed of the energy market and DRS market
Summary
In China, to motivate thermal power plants to reduce their output of power to accumulate curtailed renewable power, such as wind power and PV power, the downregulation service (DRS) market[1] is designed to be a supplement to the bench-marking electricity price mechanism (BEPM). The spot market can motivate thermal power plants to improve their operational flexibility through time-of-use pricing, the DRS market is still supposed to be reserved at the early stage of the spot market in some northern provinces, such as Shanxi[5], Gansu and Liaoning. In these provinces, nonflexible generation, such as wind, solar, and nuclear generation, has a very large share and continues to increase rapidly. The bidding strategy consists of an optimal output decision model, output power range model, capacity segmentation model, marginal generation cost (MGC) model, marginal downregulation cost (MDRC) model, and bidding models in the two markets
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