Pub Date : 2010-04-19DOI: 10.1109/TDC.2010.5484248
M. Henderson, D. Bertagnolli, D. Ramey
Planning Flexible Alternating Current Transmission Systems (FACTS) presents special technical and commercial considerations. More recent applications present additional challenges in systems with deregulated markets. This paper describes some of the successful installations and plans for FACTS in New England.
{"title":"Planning HVDC and FACTS in New England","authors":"M. Henderson, D. Bertagnolli, D. Ramey","doi":"10.1109/TDC.2010.5484248","DOIUrl":"https://doi.org/10.1109/TDC.2010.5484248","url":null,"abstract":"Planning Flexible Alternating Current Transmission Systems (FACTS) presents special technical and commercial considerations. More recent applications present additional challenges in systems with deregulated markets. This paper describes some of the successful installations and plans for FACTS in New England.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"89 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2010-04-19","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116457701","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840110
C. Potter, Allison Archambault, Kenneth J. Westrick
“Smart grid” is a relatively new term that refers to the application of information technology to power systems. Due to the complexity of such systems; the possibilities have yet to be clearly defined. Drawing a clear distinction between one grid configuration being “smart” and another failing the criterion is not realistic. Instead, it is much more practical to consider the “smart grid” as a term defining opportunities to improve the operation of the power system. One of the key features of a smart grid is the ability to utilize information to make better operational decisions. This paper proposes that significant improvements can be made to the operations of a smart grid by providing information about the likely behavior of renewable energy - through both online short-term forecasting and longerterm assessments.
{"title":"Building a smarter smart grid through better renewable energy information","authors":"C. Potter, Allison Archambault, Kenneth J. Westrick","doi":"10.1109/PSCE.2009.4840110","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840110","url":null,"abstract":"“Smart grid” is a relatively new term that refers to the application of information technology to power systems. Due to the complexity of such systems; the possibilities have yet to be clearly defined. Drawing a clear distinction between one grid configuration being “smart” and another failing the criterion is not realistic. Instead, it is much more practical to consider the “smart grid” as a term defining opportunities to improve the operation of the power system. One of the key features of a smart grid is the ability to utilize information to make better operational decisions. This paper proposes that significant improvements can be made to the operations of a smart grid by providing information about the likely behavior of renewable energy - through both online short-term forecasting and longerterm assessments.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"31 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115267180","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840010
Hee-yeol Jung, Dae-Jin Park, Hyo-Ryong Seo, Minwon Park, I. Yu
Dispersed power generation systems are expected as important electric power supply systems for the next generation. Wind power generation system (WPGS) is widely being introduced in the worldwide power utilities. The WPGS output power fluctuates due to wind speed variations. Hence, if a large number of wind power generators are connected to the grid system, their output can cause serious power quality problems, that is, frequency and voltage fluctuations may happen. In order to solve these problems, the smoothing control of wind power generator output is very important. In addition, Superconducting Magnet Energy Storage (SMES) is surely one of the key technologies to overcome these fluctuations. The SMES can compensate even small disturbances. With these points as background, this paper deals with power quality enhancement of grid-connected WPGS by pitch control and SMES. EMTDC and RTDS based simulations are performed for a small island power system including WPGS and the results are discussed in detail.
{"title":"Power quality enhancement of grid-connected wind power generation system by SMES","authors":"Hee-yeol Jung, Dae-Jin Park, Hyo-Ryong Seo, Minwon Park, I. Yu","doi":"10.1109/PSCE.2009.4840010","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840010","url":null,"abstract":"Dispersed power generation systems are expected as important electric power supply systems for the next generation. Wind power generation system (WPGS) is widely being introduced in the worldwide power utilities. The WPGS output power fluctuates due to wind speed variations. Hence, if a large number of wind power generators are connected to the grid system, their output can cause serious power quality problems, that is, frequency and voltage fluctuations may happen. In order to solve these problems, the smoothing control of wind power generator output is very important. In addition, Superconducting Magnet Energy Storage (SMES) is surely one of the key technologies to overcome these fluctuations. The SMES can compensate even small disturbances. With these points as background, this paper deals with power quality enhancement of grid-connected WPGS by pitch control and SMES. EMTDC and RTDS based simulations are performed for a small island power system including WPGS and the results are discussed in detail.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"24 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115709139","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840057
K. Hunter
The CIM standard (IEC 61970-301) is released on a yearly cycle. Major enhancements to the CIM are planned a few years into the future as part of a CIM road map. The CIM is also modified to address issues that are discovered as it is used in real world implementations. Issues are also uncovered during the yearly multi-vendor CIM interoperability tests. The current CIM road map will be discussed with particular emphasis on the next release. The issues resolution process and interoperability testing will also be covered.
{"title":"CIM model management","authors":"K. Hunter","doi":"10.1109/PSCE.2009.4840057","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840057","url":null,"abstract":"The CIM standard (IEC 61970-301) is released on a yearly cycle. Major enhancements to the CIM are planned a few years into the future as part of a CIM road map. The CIM is also modified to address issues that are discovered as it is used in real world implementations. Issues are also uncovered during the yearly multi-vendor CIM interoperability tests. The current CIM road map will be discussed with particular emphasis on the next release. The issues resolution process and interoperability testing will also be covered.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"8 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"123112095","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840196
Arif Karakaş, F. Li, S. Adhikari
This paper presents an aggregate model of multiple induction motors using a single equivalent circuit model, which simplifies the computation while simulating dynamic behavior of large power systems. The simulations and analysis are carried out using MATLAB-based software package. The performance of the aggregation model of multiple motors is verified by comparing the results obtained from the sum of individual induction motors and the aggregation model. The results obtained are satisfactory and reasonable.
{"title":"Aggregation of multiple induction motors using MATLAB-based software package","authors":"Arif Karakaş, F. Li, S. Adhikari","doi":"10.1109/PSCE.2009.4840196","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840196","url":null,"abstract":"This paper presents an aggregate model of multiple induction motors using a single equivalent circuit model, which simplifies the computation while simulating dynamic behavior of large power systems. The simulations and analysis are carried out using MATLAB-based software package. The performance of the aggregation model of multiple motors is verified by comparing the results obtained from the sum of individual induction motors and the aggregation model. The results obtained are satisfactory and reasonable.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"60 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"116974529","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840215
R. Bo, F. Li
In day-ahead power markets, the calculation of locational marginal price (LMP) relies on the load forecasting results. It is well known that short-term load forecasting results always contain certain degree of errors mainly due to the random nature of the load. At the same time, LMP step change exists at critical load level (CLL). Therefore, it is interesting to investigate the impact of load forecast uncertainty on LMP. With the assumption of distribution of actual load, this paper formulates the probability mass function of the random variable LMPt, LMP at time t, and then proposes the concept of probability-based expected LMP. Two useful curves, deterministic LMP versus forecasted load and expected LMP versus forecasted load, are presented. The first curve is designed to help identify the trustworthy regions of traditional LMP-Load curve. The second curve is demonstrated to be smooth and therefore eliminates the step changes in deterministic LMP simulation. The proposed concept and method are illustrated on a modified PJM 5-bus system.
{"title":"Impact of load forecast uncertainty on LMP","authors":"R. Bo, F. Li","doi":"10.1109/PSCE.2009.4840215","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840215","url":null,"abstract":"In day-ahead power markets, the calculation of locational marginal price (LMP) relies on the load forecasting results. It is well known that short-term load forecasting results always contain certain degree of errors mainly due to the random nature of the load. At the same time, LMP step change exists at critical load level (CLL). Therefore, it is interesting to investigate the impact of load forecast uncertainty on LMP. With the assumption of distribution of actual load, this paper formulates the probability mass function of the random variable LMPt, LMP at time t, and then proposes the concept of probability-based expected LMP. Two useful curves, deterministic LMP versus forecasted load and expected LMP versus forecasted load, are presented. The first curve is designed to help identify the trustworthy regions of traditional LMP-Load curve. The second curve is demonstrated to be smooth and therefore eliminates the step changes in deterministic LMP simulation. The proposed concept and method are illustrated on a modified PJM 5-bus system.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"25 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"117233747","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840220
J. R. Aguero, Richard Brown, J. Spare, Edmund Phillips, Le Xu, Jia Wang
this paper explains the development of a ten-year reliability improvement roadmap for a major distribution utility of the USA. First, a benchmark approach based on a survey of the reliability indices of 21 utilities of the USA and Canada was used to set the roadmap targets. Moreover, a historical outage analysis was performed to identify the main outage causes and potential reliability improvement options. Then, a detailed predictive reliability model was used to assess the cost-effectiveness of a broad set of reliability improvement projects for a pilot study area. Finally, the results of the study area were extrapolated to the utility distribution system by using a novel technique. Here, in order to consider the differences between the study area and the utility distribution system (representativeness error), the main characteristics of each feeder (length, number of customers per circuit mile, percentage of overhead and underground exposure, voltage level, etc) were taken into account. The reliability roadmap results for the utility system are presented and discussed.
{"title":"A reliability improvement roadmap based on a predictive model and extrapolation technique","authors":"J. R. Aguero, Richard Brown, J. Spare, Edmund Phillips, Le Xu, Jia Wang","doi":"10.1109/PSCE.2009.4840220","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840220","url":null,"abstract":"this paper explains the development of a ten-year reliability improvement roadmap for a major distribution utility of the USA. First, a benchmark approach based on a survey of the reliability indices of 21 utilities of the USA and Canada was used to set the roadmap targets. Moreover, a historical outage analysis was performed to identify the main outage causes and potential reliability improvement options. Then, a detailed predictive reliability model was used to assess the cost-effectiveness of a broad set of reliability improvement projects for a pilot study area. Finally, the results of the study area were extrapolated to the utility distribution system by using a novel technique. Here, in order to consider the differences between the study area and the utility distribution system (representativeness error), the main characteristics of each feeder (length, number of customers per circuit mile, percentage of overhead and underground exposure, voltage level, etc) were taken into account. The reliability roadmap results for the utility system are presented and discussed.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"98 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"124981013","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840099
Zhifeng Qiu, Geert Deconinck, R. Belmans
For decades researchers have developed various models and algorithms to look for the Optimal Power Flow (OPF) in different applications. Still research is ongoing to find OPF problems for the present day power system challenges such as a liberalized market or a large penetration of renewable energy source. Traditionally, classical mathematical optimization methods have been used to effectively solve conventional OPF problems. Due to emergence of a deregulated electricity market and consideration of dynamic system properties, however, the traditional concepts and practices of power systems are over-ruled by an economic market management. So the requirements for OPF have become more complex than it was. The purpose of this survey is to collect information from the previous research literatures and to classify different modeling and solving approach for OPF.
{"title":"A literature survey of Optimal Power Flow problems in the electricity market context","authors":"Zhifeng Qiu, Geert Deconinck, R. Belmans","doi":"10.1109/PSCE.2009.4840099","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840099","url":null,"abstract":"For decades researchers have developed various models and algorithms to look for the Optimal Power Flow (OPF) in different applications. Still research is ongoing to find OPF problems for the present day power system challenges such as a liberalized market or a large penetration of renewable energy source. Traditionally, classical mathematical optimization methods have been used to effectively solve conventional OPF problems. Due to emergence of a deregulated electricity market and consideration of dynamic system properties, however, the traditional concepts and practices of power systems are over-ruled by an economic market management. So the requirements for OPF have become more complex than it was. The purpose of this survey is to collect information from the previous research literatures and to classify different modeling and solving approach for OPF.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"1 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125869251","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840036
D. K. Jha, N. Yorino, Y. Zoka, Y. Sasaki, Y. Hayashi, K. Iwata, R. Oe
This paper proposes a backward search approach to incorporate excess stream inflows, in Stochastic Dynamic Programming (SDP) based reservoir scheduling, of hydropower plants. The aim is to reduce the amount of spill during operation of the reservoir. Energy maximization type Stochastic Dynamic Programming (SDP) model, with inflow process assumption considered as independent, is developed for a hydropower plant located in Japan. Reservoir operating policy consists of target storage levels at the end of a period, for each combination of beginning of the period storage levels and possible average inflow states during the period. The backward search approach has been incorporated in the SDP model, during the simulation, in order to identify the annual reservoir operation curve, with reduced spill. The storage guide curves identified with incorporation of backward search approach are compared with that from the normal SDP model. It has been found that the proposed approach serves better from the view point of spill reduction.
{"title":"Backward search approach to incorporate excess stream inflows in SDP based reservoir scheduling of hydropower plants","authors":"D. K. Jha, N. Yorino, Y. Zoka, Y. Sasaki, Y. Hayashi, K. Iwata, R. Oe","doi":"10.1109/PSCE.2009.4840036","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840036","url":null,"abstract":"This paper proposes a backward search approach to incorporate excess stream inflows, in Stochastic Dynamic Programming (SDP) based reservoir scheduling, of hydropower plants. The aim is to reduce the amount of spill during operation of the reservoir. Energy maximization type Stochastic Dynamic Programming (SDP) model, with inflow process assumption considered as independent, is developed for a hydropower plant located in Japan. Reservoir operating policy consists of target storage levels at the end of a period, for each combination of beginning of the period storage levels and possible average inflow states during the period. The backward search approach has been incorporated in the SDP model, during the simulation, in order to identify the annual reservoir operation curve, with reduced spill. The storage guide curves identified with incorporation of backward search approach are compared with that from the normal SDP model. It has been found that the proposed approach serves better from the view point of spill reduction.","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"497 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"125419713","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
Pub Date : 2009-03-15DOI: 10.1109/PSCE.2009.4840088
M. Rothleder
The CAISO is completing the implementation of it Market Redesign and Technology Upgrade (MRTU). Currently, the Ancillary Services at the CAISO is approximately a $300 million annual market. In conjunction with the Market Redesign, the CAISO is implementing a co-optimization of Energy subject to Transmission Constraints and Ancillary Services subject to resource constraints. Prior to MRTU, the CAISO procured Ancillary Services in the Day-Ahead Market sequentially after allocating transmission using a Ration Buyer approach. In addition the CAISO procures the incremental Ancillary Service needs in the Hour-Ahead market. There are currently three Ancillary Services that the CAISO procures via the market: 1) Regulation, 2) Spinning-Reserve (Available in 10 minutes for synchronized resources), 3) Non-Spinning Reserve (Available in 10 minutes). After MRTU is implemented, 100% of forecasted required reserves will be procured simultaneously in Day-Ahead Market with Energy. Any additional Ancillary Service required in Real-Time will be procured on a 15 minute interval basis simultaneously when making unit commitment decisions. Energy from regulation will be dispatched by Automated Generation Control (AGC) on a 4 second basis. Energy from procured Spinning and Non-Spinning reserves may be dispatched on a 5 minute basis if they are available if they are flagged as non-contingent. Spinning and Non-Spinning reserves that are flagged as contingency only are available to energy dispatch in case of a contingency event. Regional Ancillary Service constraints will be enforced to assure a minimum or maximum regional requirements are satisfied. In addition the import of Ancillary Services will compete with Energy for import intertie capacity. In order to assure that the highest quality service is procured if economic appropriate, the Regulation reserves can substitute for Spinning or Non-Spinning reserves. Spinning reserve can substitute for Non-Spinning reserves. As a result of this ability to substitute, the higher quality service in a region should be greater than or equal to the lower quality services in the same region. As result of the simultaneous optimization of the Energy and Ancillary Services, the Ancillary Price will reflect the marginal cost of the services as well as any lost opportunity cost as a result of having to not dispatching otherwise economic energy to meet the Ancillary Service requirements. The CAISO is considering introducing a 30 minute reserve product in the future to address the need to respond to contingency overloads. Other services such as Reactive Support and Black-Start capability are not currently procured via spot market mechanisms but rather procured as a result of Reliability Must Run agreements. The presentation we will provide a status update of implementation of the Energy and Ancillary Service co-optimization. We intend to present high level information how the Ancillary Service constraint is formulated. In addition, we will
{"title":"Using co-optimization to clear energy and ancillary services in MRTU market","authors":"M. Rothleder","doi":"10.1109/PSCE.2009.4840088","DOIUrl":"https://doi.org/10.1109/PSCE.2009.4840088","url":null,"abstract":"The CAISO is completing the implementation of it Market Redesign and Technology Upgrade (MRTU). Currently, the Ancillary Services at the CAISO is approximately a $300 million annual market. In conjunction with the Market Redesign, the CAISO is implementing a co-optimization of Energy subject to Transmission Constraints and Ancillary Services subject to resource constraints. Prior to MRTU, the CAISO procured Ancillary Services in the Day-Ahead Market sequentially after allocating transmission using a Ration Buyer approach. In addition the CAISO procures the incremental Ancillary Service needs in the Hour-Ahead market. There are currently three Ancillary Services that the CAISO procures via the market: 1) Regulation, 2) Spinning-Reserve (Available in 10 minutes for synchronized resources), 3) Non-Spinning Reserve (Available in 10 minutes). After MRTU is implemented, 100% of forecasted required reserves will be procured simultaneously in Day-Ahead Market with Energy. Any additional Ancillary Service required in Real-Time will be procured on a 15 minute interval basis simultaneously when making unit commitment decisions. Energy from regulation will be dispatched by Automated Generation Control (AGC) on a 4 second basis. Energy from procured Spinning and Non-Spinning reserves may be dispatched on a 5 minute basis if they are available if they are flagged as non-contingent. Spinning and Non-Spinning reserves that are flagged as contingency only are available to energy dispatch in case of a contingency event. Regional Ancillary Service constraints will be enforced to assure a minimum or maximum regional requirements are satisfied. In addition the import of Ancillary Services will compete with Energy for import intertie capacity. In order to assure that the highest quality service is procured if economic appropriate, the Regulation reserves can substitute for Spinning or Non-Spinning reserves. Spinning reserve can substitute for Non-Spinning reserves. As a result of this ability to substitute, the higher quality service in a region should be greater than or equal to the lower quality services in the same region. As result of the simultaneous optimization of the Energy and Ancillary Services, the Ancillary Price will reflect the marginal cost of the services as well as any lost opportunity cost as a result of having to not dispatching otherwise economic energy to meet the Ancillary Service requirements. The CAISO is considering introducing a 30 minute reserve product in the future to address the need to respond to contingency overloads. Other services such as Reactive Support and Black-Start capability are not currently procured via spot market mechanisms but rather procured as a result of Reliability Must Run agreements. The presentation we will provide a status update of implementation of the Energy and Ancillary Service co-optimization. We intend to present high level information how the Ancillary Service constraint is formulated. In addition, we will ","PeriodicalId":135418,"journal":{"name":"2009 IEEE/PES Power Systems Conference and Exposition","volume":"36 1","pages":"0"},"PeriodicalIF":0.0,"publicationDate":"2009-03-15","publicationTypes":"Journal Article","fieldsOfStudy":null,"isOpenAccess":false,"openAccessPdf":"","citationCount":null,"resultStr":null,"platform":"Semanticscholar","paperid":"115067053","PeriodicalName":null,"FirstCategoryId":null,"ListUrlMain":null,"RegionNum":0,"RegionCategory":"","ArticlePicture":[],"TitleCN":null,"AbstractTextCN":null,"PMCID":"","EPubDate":null,"PubModel":null,"JCR":null,"JCRName":null,"Score":null,"Total":0}
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