Unit Commitment Policy Research Articles

Economic Valuation of Low-Load Operation with Auxiliary Firing of Coal-Fired Units

It is often claimed that coal-fired units are highly inflexible to accommodate variable renewable energy. However, a recently published report illustrates that making existing coal-fired units more flexible is both technically and economically feasible. Auxiliary firing is an effective and promising measure for coal-fired units to reduce their minimum loads and thus augment their flexibility. To implement the economic valuation of low-load operation with auxiliary firing (LLOAF) of coal-fired units, we improve the traditional fuel cost model to express the operating costs of LLOAF and present the economic criterion and economic index to assess the economics of LLOAF for a single coal-fired unit. Moreover, we investigate the economic value of LLOAF in the power system operation via day-ahead unit commitment problem and analyze the impacts on the scheduling results from unit commitment policies and from extra auxiliary fuel costs. Numerical simulations show that with the reduction of the extra auxiliary fuel costs LLOAF of coal-fired units can remarkably decrease the total operating costs of the power system. Some further conclusions are finally drawn.

Stochastic and Deterministic Unit Commitment Considering Uncertainty and Variability Reserves for High Renewable Integration

The uncertain and variable nature of renewable energy sources in modern power systems raises significant challenges in achieving the dual objective of reliable and economically efficient system operation. To address these challenges, advanced scheduling strategies have evolved during the past years, including the co-optimization of energy and reserves under deterministic or stochastic Unit Commitment (UC) modeling frameworks. This paper presents different deterministic and stochastic day-ahead UC formulations, with focus on the determination, allocation and deployment of reserves. An explicit distinction is proposed between the uncertainty and the variability reserve, capturing the twofold nature of renewable generation. The concept of multi-timing scheduling is proposed and applied in all UC policies, which allows for the optimal procurement of such reserves based on intra-hourly (real-time) intervals, when concurrently optimizing energy and commitments over hourly intervals. The day-ahead scheduling results are tested against different real-time dispatch regimes, with none or limited look-ahead capability, or with the use of the variability reserve, utilizing a modified version of the Greek power system. The results demonstrate the enhanced reliability achieved by applying the multi-timing scheduling concept and explicitly considering the variability reserve, and certain features regarding the allocation and deployment of reserves are discussed.

Optimal operation and forecasting policy for pump storage plants in day-ahead markets

Pump storage plants are an important electricity storage technology at present. Investments in this technology are expected to increase. The necessary investment valuation often includes expected cash flows from future price-based unit commitment policies. A price-based unit commitment policy has to consider market price uncertainty and the information revealing nature of electricity markets. For this environment stochastic programming models are suggested to derive the optimal unit commitment policy. For the considered day-ahead price electricity market stochastic and deterministic unit commitment policies are comparable suggesting an application of easier implementable deterministic models. In order to identify suitable unit commitment and forecasting policies, deterministic unit commitment models are applied to actual day-ahead electricity prices of a whole year. As a result, a robust forecasting model should consider the unit commitment planning period. This robust forecasting models result in expected cash flows similar to realized ones allowing a reliable investment valuation.

Reserve Requirements for Wind Power Integration: A Scenario-Based Stochastic Programming Framework

We present a two-stage stochastic programming model for committing reserves in systems with large amounts of wind power. We describe wind power generation in terms of a representative set of appropriately weighted scenarios, and we present a dual decomposition algorithm for solving the resulting stochastic program. We test our scenario generation methodology on a model of California consisting of 122 generators, and we show that the stochastic programming unit commitment policy outperforms common reserve rules.

Production costing with explicit recognition of unit duty cycle effects

A novel probabilistic production costing algorithm called the OPCOST method is presented which recognizes the stochastic nature of the duty cycle of a unit and models the generation system with explicit consideration of such operating characteristics as the system generation reserve policy, unit start-up delay, unit start-up failure, unit commitment policy, and unit outage postponability. The OPCOST method has been used to compute production costs for EPRI synthetic generating system E, reduced version. The studies of the sample system have been carried out for two production costing methods, the OPCOST method and a traditional method. A comparison of the results obtained using the traditional method and the OPCOST method shows significant differences in the energies produced by the various categories of units. >

Optimal and Secure Short-Term Thermal Unit Commitment

The paper presents a three-step scheduling method for determining the optimal and secure short-term thermal generating unit commitment policy. For obtaining economic unit commitment in the step one of the algorithm two of the important methods viz. dynamic programming and branch and bound technique are employed and their relative merits and demerits are discussed. Random load variations are also considered. The paper also gives a comparison of two-state and three-state reliability models used for security assessment in the step two of the algorithm developed. The algorithm developed is demonstrated through a sample system study carried out on an IBM 1130 digital computer.

Operating Considerations in Generation Reliability Modeling-An Analytical Approach

The paper presents a new analytical approach to the calculation of generating system reliability indices. The new approach makes it possible to relax idealizing assumptions and to explicitly model the effects of operating considerations such as: (1) unit duty cycles reflecting load cycle shape, reliability performance of other units, unit commitment policy, and operating reserve policy; (2) start-up failures; (3) start-up times; and (4) outage postponability. The models presented can also be used to consider the effects of basic energy limitations and to give production cost estimates.