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Chapter - 6
CONGESTION MANAGEMENT
6.1. INTRODUCTION
Transmission system congestion in a competitive electricity market refers to the
overloading of lines or transformers due to market settlement In the deregulated
cavironmmt, the customers would like to purchase electricity from the cheapest available
sources. Hence the chanca of congestion in the deregulated market are quite high as
compared to the monopolistic marka. The congestion is undesirable in the system and
should be alleviated for the secure opaation of the systm. In deregulated environment,
them may be a large number of different buya and seller c o m b i o n s entering a
Scheduling ChrdinaIor's (SC) market through bilatnal and multilataal transactions.
Whencva electricity is traded the transmission and distribution losses occur. To keep the
balaace in the system, additional production is needed to meet the losses. But due to tbe
whaling transactions, there is a possibility of congestion occurring in the transmission
system. The transmission congestion is to be handled by a thud who is neither a
buyer nor a sella of the electric energy. To coordinate among the independent trades and
to opaple the system in a secure state, a daegulated system ha an IS0 that monitors and
opaatc~ the inkrco~ccted pow= system. It maintains tbe powa flow balance
kouglnu tbc network, includes the transmission losses and permits the feasible
In r regulated powa market, the scheduling of genaation is done by the optunal
powa flow (OPF) algorithm lbat awns the gmcntion and hansmisslon line limits [29].
With tbc and of m increasing number of wheeling transactions in the open access
market, the possibility of imutlicicnt resources leading to network congestion may be
unavoidable. Singh e( al. modelled power transactions in a deregulated market under
open transmission access as pool dispatch and bilateral dispatch [SI] to relieve the
congestion basal on nodal pricing h e w o k Real-time transmission congestion can be
d e f d as the opaating condition in which there will not be enough transmission
capability to implement all the traded transactions simultaneously due to some
unexpected contingencies. It may be alleviated by incorporating line capacity mnstraints
in the dispatch and scheduling pmess. This may involve redispatch of genaation or load
~lntailment
That arc two broad paradigms that may be employed for congestion
management. They an the cost-fnc means aad the not-cost frae means [39]. The former
includcs actions like outagmg of congestal lines or operation of transformer taps, phase
shiftas or FACTS devices. These means arc formed as cost-fne only because the
marginal co~ts involved in their usage arc nominal. Srivastava a al. [I091 have well
pr*lcnted the congestion management using an optimal power dispatch model for a
practical powa system nehvork to minimize the curtailment of the contracted powas in a
powa market having bilateral. multilataal as well as h contnrts. The net-cost fm
mums include rescheduling h e gcnantion [I261 aod curtailment of loaddtransactions
[I 131. A pamnda tamed as willingness-bpy to avoid curtailment was inlmducai in
1331 md it settles the transaction curtailment slrategies which may then be incorporated
in the ophmJ powa flow framework. This factor brought the new set of bansactions
closa ca the dcsind tmwztions within the security region. Yu ad Uic proposed
c@oa clustas m&ad to readjust the transactions in the rrstructud powa market.
But this mahod is based on DC load flow involving the acsumpions of lwrsless system
and unity voltage magnitudes at all the buses [19]. Ashwani Kumar d al. proposed a
d coogestiw managanent approach based on the real and reactive power flow
mitivity indices to reschedule the gcnaators as demomated on practical power
syst- PI.
The rrrtnrcturing of the electric power industry has involved paradigm shifts in
the d time control activities of the power grids. Managing dispatch is one of the
important control activities in a power system. OPF has perhaps the most significant
technique for obtaining minimum cost generation patiems in a power system with
existing transmiasion and operational conshakits. The mle of an IS0 in a wmpecitive
market envimnmmt would be to facilitate the wmpldc dispatch of the power tbat gas
contrackd among the market players. With the bmd of an increasing number of bilateral
contracts being signed for electricity market hadcs the possibility of insufficient
ICSOIUC~~ leading to actwork congestion may be unavoidable. In this scenario congestion
management with OPF hamwork becomes an impacant issue. Relieving congestion
process may involve rodispalch of genaation or load currailmcnt. The wntingary-
bared congestion management was explained by the m h m Alomoush a.4. [2] with
a minimum number of adjustments in p f d scheduls.
In Chis work. Evolutionary Rogramrmng algorithm is proposed to solve
cmgestion problem in a dcrrgulated mvironmmL The p r c f d schedules of the
g c a d o l l r of tbc amcqodng S O ate obtained in the CEED environrnmt. The SCs
may submit their incrnaend and decrunend bidding prices in a real-time balancing
muLa to d c v e umgcstioa. Thest can th be implemented in tbe OPF problem to yield
change in the generator outputs. EP based OPF will give a least cost fornulation to
relieve the congestion by having minimum possible adjustments to p n f d schedules.
The proposed algorithm is tested on IEEE-30 bus and Wan utility-62 bus systsms.
63. PROBLEM FORMULATION
An OPF formulation for congestion management combines the following three
objativa:
(i) Minimizing the cost of generation.
(ii) Maximizing the benefit of customers.
(iii) Minimizing the deviation of generations from their prefemdlschedulcd values of generation.
6.2.1. Base car (Optimal preferred generation rbedule)
For Ihc congestion management, the buyers and sellas can submit the adjustment
bids (both incremental and dccrancntal bids). System opcrator selects their bids and
d a i d a the amount of deviations from the prcfemd schedule. In this work preferred
schcdula of the gcnaamrs arc obtained in CEED enviment .
A f a the pefemd schedule is received by the system opaator From the
exchange, it pcrfonns the contingency analysis to identify the critical contingmcis
which will result in the congestion or insure opaation of the system. For ttus purpose.
some s m d d critical contingencies arc identified and system operator prepares the
sckdule for thc wagestion management. The rnatbamhcal modelling of wheeling
tmsdom is given in h e following d o n .
The conceptual modelling of wheeling bansactions is that sellers and buy-
encourage tbe trading between them without violating the transmission constraints.
Mathematically, each bilataal transaction betwan a seller at bus-i and powa purchaser
at bus-j satisfies the following power balance relationship.
Pi-P4=0 (6.1)
In the case of multilateral trsnsaction, the summation of powa injected in diffaent b w s
(i) is equal to the summation of load powers taken out at various b w s (i).
Whm P, and Pg represent the powa injection into the seller bus-i and the power taken
out at buya bus-j, 4: is the total number of transactions.
6.23. Congation Management
The congestion management problem can be formulated as an optimization
problem with an objective to minimize the total adjustment price. This is formulated to
minimize the total cod of the adjustment bid utilized from all the SCs for the congestion
management. The ponfolios of all the SCs are optimized and kept under balance. The
objcstive function for the congestion management problem can be formulated as,
whac C', and C, an vectors of incranental and decmental bids submitted by the
gmcntors at oodc i under scheduling coonhator in for redispatch during congestion. AF'
be the change in prefarcd schedule and N, is the gcnaators of the umesponding
Scheduling Coordinator and C is the total congestion cost.
Subjected to the SC's portfolio b a l m equation
Where Phi is the power taken at node i under Scheduling Coordinator m and operating
limits on powa injection at each node is given by
P-7 2 P,, 5 P-7 (6.5) Thcsc transactions arc then brought to the notice of IS0 with a q u e s t that transmission
facilities for the relevant amount of powa transferred be provided. If there is no violation
of Sits, IS0 simply dispatches all the qucsted transactions, otherwise it carries out
twcheduling and the comsponding congestion chargcs arc levied on the customers. In
this w o k Evolutionary Programming algorithm is used to reschedule the generations to
relieve the congestion which is explained in the following section.
63 . EP-BASED CONGESTION MANAGEMENT (EPCM)
Evolutionary programming is a probabilistic sesrch technique, which generates
the initial parent vectors distributed uniformly in intavals within the limits and obtains
global optimal solution ova a number of iterations. The main stages of this technique arc
initialization. creation of off-spring vector by mutation and competition and selection of
bcst vectors to evaluate bcst fimess solution. The implementation of EP algorithm is
given below.
63.1.Idthll.lintion
The initid poplation (number of parent vectors) is g-ed after satisfying the
constmints given in (6.4) and (6.5). The elements of parent vectm ( P , ) arc the real
power outputs of genaating units distributed uniformly betwm their minimum and
maximum limits.
63.2. Mutation
An offspring P', is created from each parent vector by adding gaussian random
variable with zero mean and standard deviation q denoted as N(0, di).
P'*,= P,i + N(0, a,') fori =1 ,2 ,... p - 1 (6.6)
.-I
whae a, = f3 c (C, / C,)' (P&- - Pmi? 3.1
(6.7)
where p is the d i n g factor, Ci is the total congestion cost ad C- is the minimum
value of congestion cost in the corresponding generation.
In this work, mutation is carried out with non-linear scaling factor. The concept of
non-linear scaling factor was explained briefly in the chapter 2. The created offspring
vector must satisfy the minimum and maximum generation limits of the units and Line
flow constlaints.
633. Competition and W e d o n
The computed parent and offspring vectors are competed for the nwival ad the
best vectors are wlccted in each generation. Initialization and mutation are repeated until
there is no appreciable improvement in the obtained congestion cost. The step-by-step
cornputatid flowchart is given in Fig.6. I .
C l r p L . (b r M d Q pr.a naa rhch r l m crqrrm d K d m Ilrmrucmplmam-4b
' Flg. 6.1. Flowchart for EP b a d Congalioa, Mumgemat
6.4. SIMULATION RESULTS
When the system is insecure and there arc power flow violations in the system,
the objcctive of IS0 is to eliminate the system overload and come up with the corrective
rescheduling to eliminate the violations as f& as possible. Mnimum operating cost,
minimum number of controls, or minimum shift from the optimum opaation may be
uacd as the objective function. Ench Schedule Coordinator may trade hansaction with
ohax before submitting prefmed schedules to the ISO. Thse parties may trade powa
again when preferred schedules arc rrturncd to them for revision. in this wo& the
prcfemd schedules of generation arc obtained in CEED environment. In this procts$
adjustment bids (incmental and darcmental) reprcpmt the economic information on
which the IS0 will base its decisions to relieve congestion. Adjustment of bids include
suggested deviations from preferred loads and genaation schedules provided by SCs. At
each bus, ranges of powa deviations along with deviations in price are submined to the
ISO. An OPF will be solved for the test systems to detcrmiae the preferred schedules of
generation that satisfy the objective of minimizing deviations from the desired
bansaction. In this w o k Evolutionary Programming algorithm is used to reschedule the
generations and to minimirt the congestion cost. The developed EP-based congestion
management is demonstrated on IEEE-30 bus and Indian utility-62 bus systems.
6.4.1. IEEE-30 bus system
It consists of six gcnaating units, 41 traasmission lines, 4 tap changing
tramformas md two VAR SOUIUS. The generator, bus, line, cost and emission data of
the IEEE-30 bus syltan arc given in Appcadix A. To incorporare the resbucturcd marlrel
gcnaaton arc grouped unda two echeduling coodinatom. Two garaabrs GI., and (31.2
refm to SCI and the total load is about 96.7 MW. Four genrmtors Gz.l, G22, G2.3 & 02.4
refer to gemration of SC2 and the total load is about 186.7 MW. The prefarcd schedules
obtained 6um conventional OPF in CEED environrnart an givm in Table 6.1. It also
gives the ~ e n W d c c r a n e n t a l bids submitted by the gcncrntors of cmrcsponding
scheduling coordinator. Four bilatanl transactions and a rnultilatcral hansaction an
carried out to meet out the i n c h demand. The buyer snd seller buss involving in the
wire business and their magnindes clrc given in Table 6.2 & 6.3. Afta the permitted
wheeling bansactions, it was found that lines 2 and 5 were congested
Table 6.1. Pnfemd Sebedula and InJDce Bids - IEEE30 Bus System
Table 63. Dctalls of Bilateral Tmnuctious - IEEE-30 Bus System
Table 63. Details of MdtiLteral Trauudol~ - lEEE -30 Bus System
T n u u d o n
TI TI f 3
7.4
"'Iue O&M*dOn
17 10 15 20
From BU No.
14 16 2s IS
To Bus No.
22 08 0s 24
To relieve the congestion, the gcnetations of SCs are adjusted from the pnfemd
schedules. In the same time, SCs must satisfy the total generation and load profils at all
the times. In this pspa, evolutionary programming algorithm is used to obtain the new
schedules of genetations at each SC by satisfying the power balance equation. The
proposed algorithm uses the incmentaVdccrcrnental bids to relieve the congestion at
minimum cost The rescheduling of genmtom must satisfy the minimum and maximum
limits of genmtors. The obLained minimum congestion cost to reschedule the genmtors
to permit the above whetling tmsrctions is S 279.450. The prefnred schedules and
reschedules of generators of comsponding SCs an given in Fig. 6.2.
6.43. lndira Utility-62 bas System
To validate the performance of the proposed algorithm, Indian utility42
bus system consisting of 19 gennators, 89 (220 kV) lines with I1 tap changing
transformers has been considaed. The total system demand is 2909 MW. The total
system load is md by h e Scheduling Coordinators and their comsponding load
demaads an 906.423 MW, 531.210 MW & 1471.351 MW qmtively. The bus, line,
generator, load, cost and emission data of the tcst system are given in Appcnd~x.B. The
genaator p n f d schedules in CEED environment and incmental and decmental
b i b to relieve the congestion are given in Table 6.4. Two multilataal bansactions arc
carried out in the above test system and the details ~IX given in Table 6.5. It was obscrved
that lina 3 and 6 got c o n g d when the whaling transactions arc pnmined.
Evolutionary ppmming algorithm is applied to relieve the congestion by altaing the
schadula of g d o n and obtllincd congestion cost is Rs. 21 12.462.
Fig. 6.2. Preferred and Rescheduled Genemtor Powen - IEEE - 30 Bus System
Table 6.4. Preferred Sebcduln and lndDec Bids - Indim Utility - 62 Bus System
98
Table 6.5. DeWh of Multilnternl Tnnuetion8 - Indian Utility - 62 Bus System
65. CONCLUSION
The work reported in this chapta deals with an o p W power flow basad
congestion management carried out with bilateral and multilateral hansactions. It was
found lhat the kansmission system was overloaded when the wheeling transactions were
carried out. This congestion was relieved by adjusting the generator setlings with rrspect
to their bids. The proposed congestion management algorithm was demonstrated on IEEE
and Indian utility systems with evolutionary programming algorithm.