Now that California has AMI, what can the state do with it?

Woo, Chi-Keung; Kollman, E.; Orans, Ren; Price, S.; Horii, Brian

doi:10.1016/j.enpol.2007.12.018

Cited by 55 publications

(18 citation statements)

References 30 publications

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“…EDRP is a voluntary program that pays strictly for energy; while SCR provides an up-front payment for capacity, a payment for load reductions when dispatched, but includes the threat of penalties for noncompliance with capacity obligations during declared program events. 3 The DADRP is an economic DR program that allows participants to submit load curtailment (i.e., supply) offers into the NYISO's Day-Ahead Market, where they compete side-by-side with generators. If a DADRP participant's offer is accepted, that participant is obligated to curtail the committed amount the following day, or else covers any open position it has at the higher of the real-time or day-ahead location-based marginal price (LBMP).…”

Section: Participationmentioning

confidence: 99%

“…[1,2] 1 This concept of demand response can be traced to the beginnings of the U.S. electric power industry (circa early-to mid-1890s), where system engineers and utility executives debated the optimal pricing regime for this new found service: Hopkinson's demand charge or time-of-day differentiated rates [6]. The universe of time-based retail rates has expanded significantly from these early days of the industry to now include real-time pricing (RTP), critical peak pricing (CPP) and variations thereof [2,3,7,8].…”

Section: Introductionmentioning

confidence: 99%

“…As our definition suggests, U.S. utilities have also utilized incentive-based programs, often based on reliability differentiation, to elicit demand response from customers [3]. Utilities implemented load management (e.g.…”

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Demand response in U.S. electricity markets: Empirical evidence

Cappers

Goldman

Kathan

2010

Energy

354

163

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Section: Participationmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Demand response in U.S. electricity markets: Empirical evidence

Cappers

Goldman

Kathan

2010

Energy

354

163

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“…Unlike most generation units, loads can respond to control signals almost instantaneously [5] and the development of advanced metering infrastructure (AMI) [6] has made real-time load control achievable if appropriate control signals are provided. Many control strategies such as [7]- [10] adjust loads based on local frequency, enabling loads to mimic the natural response of synchronous generators.…”

Section: Introductionmentioning

confidence: 99%

“…where quadratic utility curves of flexible consumers and quadratic cost curves of generators are given in (6) and (7) respectively.…”

Section: B Optimal Power Flowmentioning

confidence: 99%

A practical integration of automatic generation control and Demand Response

Shiltz

Annaswamy

2016

2016 American Control Conference (ACC)

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Abstract-For a power grid to operate properly, electrical frequency must be continuously maintained close to its nominal value. Increasing penetration of distributed generation, such as solar and wind generation, introduces fluctuations in active power while also reducing the natural inertial response of the electricity grid, creating reliability concerns. While frequency regulation has traditionally been achieved by controlling generators, the control of Demand Response resources has been recognized in recent smart grid literature as an efficient means for providing additional regulation capability. To this end, several control methodologies have been proposed recently, but various features of these proposals make their practical implementations difficult. In this paper, we propose a new control algorithm that facilitates optimal frequency regulation through direct control of both generators and Demand Response, while addressing several issues that prevent practical implementation of other proposals. In particular, i) our algorithm is ideal for control over a large, low-bandwidth network as communication and measurement is only required every 2 seconds, ii) it enables Demand Response resources to recover energy lost during system transients, and iii) it accommodates both measured disturbances and unmeasured disturbances. We demonstrate the viability of our approach through dynamic simulations on a 118-bus grid model.

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Potential impact of recharging plug‐in hybrid electric vehicles on locational marginal prices

Wang

Lin

Chen

2010

Naval Research Logistics

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Plug-in hybrid electric vehicles (PHEVs), upon market penetration, will create additional recharging loads to the electric power systems. This article considers different recharging scenarios and uses game theoretic models to study the potential impact of the recharging loads on locational marginal prices (wholesale electricity prices). Computational results from a Pennsylvania-New Jersey-Maryland Interconnection case study show that, under the existing recharging infrastructures, even a small magnitude of load increase caused by PHEV recharging could have a significant undesirable impact on locational marginal prices. The impact could be mitigated to a varying extent by the availability of possible future recharging infrastructures, including realtime pricing recharging meters, battery stations, or vehicle-to-grid technology.

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Now that California has AMI, what can the state do with it?

Cited by 55 publications

References 30 publications

Demand response in U.S. electricity markets: Empirical evidence

Demand response in U.S. electricity markets: Empirical evidence

A practical integration of automatic generation control and Demand Response

Potential impact of recharging plug‐in hybrid electric vehicles on locational marginal prices

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