This paper presents a market-based multi-period generation-transmission expansion planning (GTEP) along with fixed series compensation (FSC) allocation. FSCs can dispatch power more efficiently over the transmission network as well as trading opportunities for market participants and thus improve market surplus and reduce the total transmission investment. The proposed planning may accordingly enhance network efficiency and improve social welfare for all participants. The proposed model is structured as a mixed integer linear programming (MILP) problem. The CPLEX solver, as a commercial solver, is used to solve this MILP problem. Moreover, to find a reliable and viable optimal topology, N-1 security criterion is employed through the proposed model. This criterion is used to take into account any unanticipated operating condition due to unexpected transmission line failures. The proposed model is applied to the Garver and IEEE 24-bus systems as well-known systems to show the effectiveness of FSC in dynamic GTEP. Keywords Dynamic generation-transmission expansion planning Á Fixed series compensation Á Social welfare Á Mixed integer linear programming List of symbols Variables p tie D nm Power consumed by mth block of nth consumer in scenario i, condition e, and year t p tie G hj Power generated by jth block of hth generator in scenario i, condition e, and year t f tie pq;r

This paper presents a model for multi-period generation and transmission expansion planning (G&TEP) problem in the presence of uncertainties in the strategies of market participants. The effects of demand response (DR) and fixed series compensation (FSC) devices allocation are considered for peak shaving purposes and optimal utilization of transmission capacity, respectively. This may cutback the generating expansion capacity and transmission investment costs. The optimal expansion plan is achieved while the uncertainties in the generators' offers and demands' bids are considered in the market model. In this model, the DR preferences are integrated into the market clearing process of the independent system operator (ISO), which is applied to the load aggregators according to the locational marginal and market clearing prices. Shifting the demand, curtailing the peak, and onsite generation are considered as load reduction strategies in the demand response program. The ISO optimizes the decision submitted by generating companies and load aggregators in the presence of uncertainties. The proposed model is applied to the Garver, single-, two-, and four-area IEEE-RTS 24-bus systems to show the effectiveness of the multi-optional DR program and the FSC devices in the dynamic G&TEP problems.

SUMMARY Transmission network expansion planning (TNEP) is one of the most important parts of power system studies. An optimal expansion of a transmission system should also capable of facilitating forecasted load patterns as well as future generation. Mathematically, TNEP is a mixed integer nonlinear programming as a non convex problem that can be solved by either conventional or heuristic optimization algorithms. This paper proposes a methodology for choosing the optimal transmission expansion plan considering less computational effort. The proposed methodology is composed from combination of Modified Scatter Search Algorithm and Constructive Heuristic Algorithm (CHA) considering New Load Shedding Index (NLSI). The proposed NLSI is implemented without generation rescheduling in order to decrease the number of linear programming obtaining an optimal solution. The algorithm is applied to different cases: Garver, 24‐Bus IEEE systems and Southern Brazilian System of 46 Buses system. The simulation result shows a significant performance of the proposed method in comparison with some studies addressed in literature. Copyright © 2012 John Wiley & Sons, Ltd.

This paper presents a model for multi-period generation and transmission expansion planning (G&TEP) problem in the presence of uncertainties in the strategies of market participants. The effects of demand response (DR) and fixed series compensation (FSC) devices allocation are considered for peak shaving purposes and optimal utilization of transmission capacity, respectively. This may cutback the generating expansion capacity and transmission investment costs. The optimal expansion plan is achieved while the uncertainties in the generators' offers and demands' bids are considered in the market model. In this model, the DR preferences are integrated into the market clearing process of the independent system operator (ISO), which is applied to the load aggregators according to the locational marginal and market clearing prices. Shifting the demand, curtailing the peak, and onsite generation are considered as load reduction strategies in the demand response program. The ISO optimizes the decision submitted by generating companies and load aggregators in the presence of uncertainties. The proposed model is applied to the Garver, single-, two-, and four-area IEEE-RTS 24-bus systems to show the effectiveness of the multi-optional DR program and the FSC devices in the dynamic G&TEP problems.

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