Optimal ReScheduled Generation using Participation Factors

Abstract

The objective of power systems operation and planning in the interconnected power system is to maximize the social welfare through minimizing total generation costs. This paper presents a novel approach for optimal generation considering stability limits. The paper examines two approaches for optimal generation. The first approach is based on analyzing their shares in increased load on system. The second approach is based on voltage stability consideration. An IEEE-6 bus test system is used to demonstrate the results. One of the modern power system analyzer MiPower software is used to model and solve the optimization problems involved and the MATLAB software is used to perform graphical representations through an interface between both programs.

Computationally efficient composite transmission expansion planning: A Pareto optimal approach for techno-economic solution

“…Thereafter, other optimal operating points are calculated for the reasonably small changes in loads (multiple demand scenarios) using GPF by GPF s = ((1/c s )/ P jeg (1/ c j )). Here, subscript s stand for bus, c s is the cost coefficient associated with the quadratic term of the generator's cost function at bus s [23,16] and j belongs to all generators in the power system. The change in sth generator's power (DG s ) subject to change in system demand (DD) is given by DG s = GPF s ⁄ D. Steps for calculating ELD of generators for multiple demand scenarios are:…”

“…A similar exercise for a 24-bus IEEE power system takes more than 14 days. To make it computationally efficient, linear sensitivity factors have been incorporated: (1) GPF (generation participation factor) to replace the iterative ELD calculation [23], (2) PTDF (power transfer distribution factor) matrix to replace multiple DC-load flow calculations [24], (3) LODF (Line outage distribution factor) and GLODF (generalized line outage distribution factor) matrix for transmission lines contingency analysis [25], and (4) BBIM (bus-branch incidence matrix) [16,26] for the calculation of ENS and GNS. The overall scheme is implemented on the modified IEEE-5 bus, IEEE-24 bus and IEEE-118 bus test power systems to show the generalization at large networks.…”

“…34-37, 55-56, 63-59, 60-61, 64-65, 68-116, 77-78, 80-97, 88-89, 94-100, 101-102, 110-111, 105-108, 104-105, 105-106, 89-90, 63-64,[22][23] are required, also, to update with 2900 MW capacity. Due to ROW constraints limit on lines capacity are 300 MW, however, most of the old lines have reached the prescribed maximum limit.…”