Modeling start-up modes and corresponding cycling costs in the unit commitment problem

Hermans, Mathias; Delarue, Erik

doi:10.1109/ptc.2017.7981137

Cited by 5 publications

(8 citation statements)

References 8 publications

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“…In [21], we extended a state-of-the-art DUC formulation [22] to include multiple start-up loading ramp rates of CCGT units and their associated maintenance costs. Leveraging an extended version of the model in [21], we analyzed the relation between the provision of spinning reserve capacity and CCGT start-up decisions for various shares of vRES and dynamic reserve requirements in [7]. Faster but more costly startups were found to reduce the total operating costs and the cost-optimal reserve requirements.…”

Section: Introductionmentioning

confidence: 99%

“…Faster but more costly startups were found to reduce the total operating costs and the cost-optimal reserve requirements. The work in [7,21], however, focused exclusively on the increased flexibility provided by increased start-up loading ramp rates, and did not consider the duration of the start-up procedure prior to loading, nor did it account for this duration as a minimum lead time when making or adjusting scheduling decisions based on updates of renewable energy forecasts. Furthermore, reserve requirements were imposed exogenously, whereas in what follows, we adopt probabilistic reserve constraints, which facilitate online, cost-optimal reserve sizing [17].…”

Section: Introductionmentioning

confidence: 99%

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Impact of generator start-up lead times on short-term scheduling with high shares of renewables

2020

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To cope with the variability and uncertainty introduced by, i.a., intermittent renewable energy sources, the flexible planning and operation of generation units is crucial. Their reaction time is constrained by the lead times on the start-up decisions, whereas the demand for flexibility and operating reserves depends on the market clearing frequency. The start-up lead times are limited by the operator's tolerance for increased maintenance on the asset, which should be reflected in short-term scheduling models. To study this interaction between the market clearing frequency and the start-up capabilities of combined-cycle gas turbines, we develop a unit commitment model. The model considers multiple start-up trajectories and the scheduling decisions in joint energy-operating reserve and balancing markets. The uncertainty on wind power forecasts is presented via wind power forecast updates generated by a dedicated data-driven tool. Leveraging this model, we investigate the interaction between (i) the frequency of wind power forecast updates, linked to the market clearing frequency, (ii) cost-optimal operating reserve volumes and (iii) combined-cycle gas turbine start-up decisions. Results show that, in general, higher market clearing frequencies lead to lower operating costs, driven by decreasing volumes of operating reserves and facilitated by the fast start-up capabilities of combined-cycle gas turbines.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Impact of generator start-up lead times on short-term scheduling with high shares of renewables

2020

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“…In [11], the impact of varying the start-up rate and the corresponding turbine maintenance costs of CCGTs on their cycling regime was examined through a sensitivity analysis. In [12], a standard unit commitment formulation [13] was extended to allow multiple start-up loading modes while accounting for the appropriate turbine maintenance costs based on LTSAs. An exploratory case study in [12] investigated the need for start-up flexibility of CCGTs in the presence of a constant day-ahead overestimation of intermittent renewables and limited planning horizons by allowing a faster, but more costly, start-up mode.…”

Section: Introductionmentioning

confidence: 99%

“…In [12], a standard unit commitment formulation [13] was extended to allow multiple start-up loading modes while accounting for the appropriate turbine maintenance costs based on LTSAs. An exploratory case study in [12] investigated the need for start-up flexibility of CCGTs in the presence of a constant day-ahead overestimation of intermittent renewables and limited planning horizons by allowing a faster, but more costly, start-up mode. Fast start-ups were found to be optimal on many occasions, leading to a more cost-efficient operating strategy when considering fast start maintenance penalties.…”

Section: Introductionmentioning

confidence: 99%

“…Fast start-ups were found to be optimal on many occasions, leading to a more cost-efficient operating strategy when considering fast start maintenance penalties. In this paper, we leverage the model in [12] and build on our previous work to contribute to the existing literature in the following three ways: 1) An analytical derivation and a methodological illustration of the incentive for fast starting and its dependence on the forecast error and the cost of fast starting is presented.…”

Section: Introductionmentioning

confidence: 99%

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Impact of CCGT Start-Up Flexibility and Cycling Costs Toward Renewables Integration

Hermans

Bruninx²,

Delarue³

2019

2019 IEEE Power &Amp; Energy Society General Meeting (PESGM)

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The large scale introduction of variable and limitedly predictable renewables requires flexible power system operation, enabled by, i.a., dynamic power plant operation, storage, demand response and enhanced interconnections. The fast start-up capabilities of combined-cycle gas turbines (CCGTs) are crucial in this regard. However, these non-standard operating conditions significantly reduce the lifetime of critical turbine components, as reflected in long-term service agreements (LTSAs). This should also be reflected in short-term scheduling models. In light of this challenge, we apply a unit commitment model that allows multiple start-up loading modes while accounting for the corresponding turbine maintenance costs based on LTSAs. Leveraging this model, we investigated the need for fast start-up capabilities of a set of CCGTs as part of a small scale test system considering various shares of renewables and dynamic reserve requirements. We have found that fast starts are often cost-optimal despite their greater turbine maintenance costs and a cost reduction of around 1 % is obtained when considering more costly fast start-up modes when scheduling. Furthermore, cost-optimal reserve sizing is a function of the planning frequency and is reduced by fast starting capabilities. We conclude that taking advantage of fast start-up capabilities benefits the electricity generation system and yields a significant cost reduction.

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Optimization of wind power generation to minimize operation costs in the daily scheduling of hydrothermal systems

Cotia

Borges

Diniz

2019

International Journal of Electrical Power & Energy Systems

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Modeling start-up modes and corresponding cycling costs in the unit commitment problem

Cited by 5 publications

References 8 publications

Impact of generator start-up lead times on short-term scheduling with high shares of renewables

Impact of generator start-up lead times on short-term scheduling with high shares of renewables

Impact of CCGT Start-Up Flexibility and Cycling Costs Toward Renewables Integration

Optimization of wind power generation to minimize operation costs in the daily scheduling of hydrothermal systems

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