Market Designs for the Primary Frequency Response Ancillary Service—Part I: Motivation and Design

Ela, Erik; Gevorgian, Vahan; Tuohy, Aidan; Kirby, Brendan; Milligan, Michael; O’Malley, Mark

doi:10.1109/tpwrs.2013.2264942

Cited by 172 publications

(110 citation statements)

References 29 publications

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“…This sub-section demonstrates the benefits of recognizing the inertia capability of each generator in the scheduling process, which may inform the development of inertia-related markets, as proposed in [27]. For this purpose, 5 GW of CCGT plant is assumed to be characterized by higher inertia constant (8 s) and Table III suggest that if the inertia capability is explicitly considered, the scheduling process will commit more plants with higher inertia constant and their energy production will significantly increase, from around 4 TWh to 24 TWh in the study analyzed.…”

Section: E Recognition Of Different Inertia Capability Of Generatorsmentioning

confidence: 99%

Stochastic Scheduling With Inertia-Dependent Fast Frequency Response Requirements

Teng

Trovato

Štrbac

2016

IEEE Trans. Power Syst.

281

221

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Abstract-High penetration of wind generation will increase the requirement for fast frequency response services as currently wind plants do not provide inertial response. Although the importance of inertia reduction has been widely recognized, its impact on the system scheduling has not been fully investigated. In this context, this paper proposes a novel mixed integer linear programming (MILP) formulation for stochastic unit commitment that optimizes system operation by simultaneously scheduling energy production, standing/spinning reserves and inertia-dependent fast frequency response in light of uncertainties associated with wind production and generation outages. Post-fault dynamic frequency requirements, 1) rate of change of frequency, 2) frequency nadir and 3) quasi-steady-state frequency are formulated as MILP constraints by using the simplified model of system dynamics. Moreover the proposed methodology enables the impact of wind uncertainty on system inertia to be considered. Case studies are carried out on the 2030 Great Britain system to demonstrate the importance of incorporating inertia-dependent fast frequency response in the stochastic scheduling and to indicate the potential for the proposed model to inform reviews of grid codes associated with fast frequency response and future development of inertia-related market.

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Section: E Recognition Of Different Inertia Capability Of Generatorsmentioning

confidence: 99%

Stochastic Scheduling With Inertia-Dependent Fast Frequency Response Requirements

Teng

Trovato

Štrbac

2016

IEEE Trans. Power Syst.

281

221

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“…This model optimizes the operation of all generating units to achieve minimum overall system operation costs while maintaining demand-supply balance and meeting frequency response and reserve requirements. As the results clearly suggest that there would be a significant benefit from frequency response support from WPs, a market framework, similar to the inertia market in [31] and compensation schemes for lost opportunity cost in [32], should be developed to provide appropriate compensation to the owners of WPs for the provision of SI and FPR and corresponding opportunity cost. Moreover, as WPs are operated under subsidy schemes, the intersection between the market designs and the subsidy schemes requires further investigation.…”

Section: F Value Of Combined Provision Of Si and Pfr From Wpsmentioning

confidence: 99%

Assessment of the Role and Value of Frequency Response Support From Wind Plants

Teng

Štrbac

2016

IEEE Trans. Sustain. Energy

140

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-High penetration of wind generation causes concerns over frequency stability, as currently wind plants do not provide frequency response support. Extensive research has been conducted to investigate alternative designs of controllers to facilitate the provision of synthetic inertia and primary frequency response from wind plants. However, frequency response support from wind plants differs from that provided by conventional plants and its impact on the system's economic performance is not yet fully understood. In this context, this paper develops a novel methodology to incorporate the frequency response support from wind plants into generation scheduling, thus enabling the benefits of alternative control strategies to be quantified. Studies are carried out on the future Great Britain power system with different wind energy penetration levels and frequency response requirements. The impact of the uncertainty associated with the quantity of wind plants being online and the energy recovery effect are also analysed. The results demonstrate that the benefits of frequency response support from wind plants may be significant, although these are system specific. The proposed model could also inform the development of grid codes, market mechanisms and business cases associated with the frequency response support from wind plants.Index Terms-Wind generation, inertia response, primary frequency response, unit commitment, power system dispatch.

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“…In fact, to enhance grid stability, many ancillary services markets pay utilities more money for providing power reserve (so that increases in power are possible) than for providing the maximum power available. 26,27 One approach to achieving this power reserve would be to de-rate the wind turbine through the pitch controller, by reducing the rated speed of the turbine and initiating pitch control at a lower power; however, there are some tradeoffs to using the pitch controller for this purpose. The advantages of using this approach are that it is rather direct to implement and because de-rating through pitch control is itself a strategy for load reduction, 28 the effect on turbine loads should be either limited or perhaps beneficial.…”

Section: Introductionmentioning

confidence: 99%

Effects of power reserve control on wind turbine structural loading

et al. 2015

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As the penetration of wind energy in worldwide electrical utility grids increases, there is a growing interest in the provision of active power control (APC) services from wind turbines and power plants to aid in maintaining grid stability. Recent research has focused on the design of active power controllers for wind turbines that can provide a range of APC services including inertial, primary frequency and secondary frequency control. An important consideration for implementing these controllers in practice is assessing their impact on the lifetime of wind turbine components.In this paper, the impact on the structural loads of a wind turbine providing a power reserve is explored by performing a load suite analysis for several torque-based control strategies. Power reserve is required for providing those APC services that require the ability of the wind turbine to supply an increase in power. To study this, we performed a load suite on a simulated model of a research turbine located at the National Wind Technology Center at the National Renewable Energy Laboratory. Analysis of the results explores the effect of the different reserve strategies on turbine loading. In addition, field-test data from the turbine itself are presented to augment and support the findings from the simulation study results. Results indicate that all power-reserve strategies tend to decrease extreme loads and increase pitch actuation. Fatigue loads tend to be reduced in faster winds and increased in slower winds, but are dependent on reserve-controller design. Copyright

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Market Designs for the Primary Frequency Response Ancillary Service—Part I: Motivation and Design

Cited by 172 publications

References 29 publications

Stochastic Scheduling With Inertia-Dependent Fast Frequency Response Requirements

Stochastic Scheduling With Inertia-Dependent Fast Frequency Response Requirements

Assessment of the Role and Value of Frequency Response Support From Wind Plants

Effects of power reserve control on wind turbine structural loading

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