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Regional transmission organisations and independent system operators include different types of security requirements to approximate system security issues. Transmission line contingencies are well handled in state-of-art market models with line outage distribution factors and, at the same time, the impacts of transmission line contingencies are reflected in energy prices. However, there is a lack of efficient mechanisms to handle generator contingencies and reflect the impacts of generator contingencies on energy prices. In this study, a set of security constraints to withstand single-generator-failure contingencies are presented and the market implications are studied. A new component of locational marginal prices, a marginal security component, which is a weighted shadow price of the security constraints, is proposed to better represent energy prices. A 3-bus system example is given to illustrate the market implications. The results are confirmed on a 73-bus system test case. [ABSTRACT FROM AUTHOR]

Regional transmission organisations and independent system operators include different types of security requirements to approximate system security issues. Transmission line contingencies are well handled in state‐of‐art market models with line outage distribution factors and, at the same time, the impacts of transmission line contingencies are reflected in energy prices. However, there is a lack of efficient mechanisms to handle generator contingencies and reflect the impacts of generator contingencies on energy prices. In this study, a set of security constraints to withstand single‐generator‐failure contingencies are presented and the market implications are studied. A new component of locational marginal prices, a marginal security component, which is a weighted shadow price of the security constraints, is proposed to better represent energy prices. A 3‐bus system example is given to illustrate the market implications. The results are confirmed on a 73‐bus system test case. [ABSTRACT FROM AUTHOR]

Transmission switching, as a power flow control mechanism that can reduce costs and improve reliability, has gained a lot of attention during the last decade. Despite its benefits, industry adoption has been very limited due to its computational complexity, stability and AC performance concerns. Pennsylvania New Jersey Maryland (PJM) has published a list of corrective switching solutions to relieve actual and post‐contingency network violations. The list is developed based on operators' prior knowledge and offline studies. This study employs a fast AC‐based real‐time contingency analysis (RTCA) tool with corrective transmission switching (CTS) functionality to analyse PJM's switching solutions with actual PJM data. The results show that the RTCA CTS tool is almost always able to find solutions that perform better than, or equally as well as, PJM's solutions. The results also show that PJM's list identifies solutions for only 3% of the problematic contingencies with post‐contingency violations over the course of one week. The RTCA CTS tool, however, is able to find corrective TS solutions for almost all the cases. The results suggest that CTS is ripe for industry adoption. The tool provides significant savings and would pave the road towards a smarter transmission network as an essential ingredient of the future smart grid. [ABSTRACT FROM AUTHOR]

The means for transporting more power through an existing transmission corridor have been given considerable attention in recent studies. Reconductoring a path with a conductor that has a higher thermal capacity, such as a high temperature low sag (HTLS) conductor, is one possible option with minimal structural modification and out-of-service time. Parallel line additions or HTLS parallel line additions are other options that can increase transfer capabilities and reduce operating costs. Thermal constraint relaxation is another option, which is an operational based method that allows the line flow to exceed the steady-state line rating for a certain penalty price. Since such operation may deteriorate the expected service time of the conductor, the penalty price should be determined properly. In this study, the above options are captured to create the proposed transmission expansion planning model. In addition, a conductor degradation model is introduced to capture the associated degradation costs due to operating conductors at elevated temperatures. Numerical simulations conducted on the IEEE-24 and IEEE-118 bus system indicate the effectiveness of the proposed approach to increase system capacity while preserving current right-of-ways (ROWs). [ABSTRACT FROM AUTHOR]

The means for transporting more power through an existing transmission corridor have been given considerable attention in recent studies. Reconductoring a path with a conductor that has a higher thermal capacity, such as a high temperature low sag (HTLS) conductor, is one possible option with minimal structural modification and out‐of‐service time. Parallel line additions or HTLS parallel line additions are other options that can increase transfer capabilities and reduce operating costs. Thermal constraint relaxation is another option, which is an operational based method that allows the line flow to exceed the steady‐state line rating for a certain penalty price. Since such operation may deteriorate the expected service time of the conductor, the penalty price should be determined properly. In this study, the above options are captured to create the proposed transmission expansion planning model. In addition, a conductor degradation model is introduced to capture the associated degradation costs due to operating conductors at elevated temperatures. Numerical simulations conducted on the IEEE‐24 and IEEE‐118 bus system indicate the effectiveness of the proposed approach to increase system capacity while preserving current right‐of‐ways (ROWs). [ABSTRACT FROM AUTHOR]

This study focuses on developing an integrated transmission and distribution framework that couples the two sub‐systems together with due consideration to conventional demand flexibility. The proposed framework ensures accurate representation of the system resources and the network conditions when modelling the distribution system in the transmission optimal power flow and vice‐versa. It is further used to develop an accurate pricing mechanism (distribution‐based location marginal pricing), which is reflective of the moment‐to‐moment costs of generating and delivering electrical energy, for the distribution system. By accurately modelling the two sub‐systems, the authors can improve the economic efficiency and the system reliability, as the price sensitive resources can be controlled to behave in a way that benefits the power system as a whole. [ABSTRACT FROM AUTHOR]