Point of Connection Transmission Charges

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Transmission Char es


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Outline Introduction

Data Acquisition & Basic Network Preparation Truing up of Yearly Transmission Charge

Computation of AC Load Flows on the Basic

Network Validation of Results

Network Reduction

Zoning of Nodes

Determination of Transmission Charges


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Introduction

What is Point of Connection Transmission charge?

, .

,thus the whole electricity market place.


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activity (generators, loads), pay a single chargein Rs/MW towards network usage. This chargeis decided by the connection level of that

particular entity [1].


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a a cqus on as c e wor repara on[2]

elements and the generation (MW) and load (MW &MVAr) at the various network nodes shall be submittedby all concerned entities including DICs, transmissionlicensees, as per the Regulations, and Procedure forObtainin data b Im lementin A enc fodetermination of PoC transmission charges.


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withdrawal forecast information based on thelong term and medium term contracts underrepresentative blocks of months for peak and

other than peak conditions.


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In the event of a DICs failin to rovide its

requisition for demand or injection for anApplication Period, the last demand or injection

by the Implementing Agency shall be considered

to be A roved Withdrawal o A rovedInjection, as the case may be, for the ApplicationPeriod.


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fails to provide its requisition for demand/Injection or Network Data, then IA shall assumethe data based on the following:

a) Long Term & Medium Term Datab) Database of RLDC/NLDC

c) CTU Database (If required)


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/group of nodes in a zone on which DICs shallsubmit the forecasted injection and withdrawal.

This shall be available on the website of

Implementing Agency.


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The list of lines which forms a art of the Inte

State Transmission System (ISTS) Network forthe next application period shall be furnished to

i. ISTS Lines

.

iii. Non-ISTS Lines (Certified by RPC as being


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list of lines in each financial year. In case ofDeemed ISTS and Certified non-ISTS lines, theowners shall also submit a copy of

approval/certificate obtained from thees gna e au or y as e case may e.


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(YTC) of the entire network along with thebreakup of substation cost shall be provided bythe Transmission Licensees of ISTS, Deemed

ISTS and Certified non-ISTS lines.


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In the subse uent ears Transmission

Licensees of ISTS, Deemed ISTS andCertified non-ISTS lines shall submit data and

transmission asset in the next financial year and

thei YTC a roved b Commission.


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rung up o eary ransmss on arge[2]

Truing up of YTC shall be done on yearly basisto adust unde o ove recover of the reviousapplication period.

As line wise YTC is an in ut fo calculation ofPoC charges, the truing up cost shall beadjusted to each line on pro-rata basis.


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ompu a on o oa ows on e as cNetwork [2]

IA shall run AC load flow on the Basic Network(separately fo NEW and SR Grid) based on the

technical data obtained from the DICs, NLDC,.


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The real owe eneration at the enerato

nodes in the Basic Network shall be based onthe long term and Approved medium term

the ISTS or the injection submitted by the DICs,

where such nodes are embedded in thenetworks of the DIC. Such contracts aregenerally with reference to the installed capacity

.


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on the basic network, the IA may require tomake certain adjustments in the load/generationat various buses to ensure load generation

balance.


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Validation of Results [2]

The Basic Network, nodal injection, nodalwithdrawal and the load flow results fo thesubsequent application period for each grid

condition shall be validated by the Validationcommittee.


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Subsequent to the validation from ValidationCommittee Basic Network nodal inectionnodal withdrawal and the load flow results shall

be presented to the Commission for its approval.


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The approved Basic Network, nodal injection,nodal withdrawal alon with the load flow resultsshall be made available on the website of the IA

immediately after its approval by theCommission.


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e wor e uc on [2]

The Basic network for each grid condition andseason shall be reduced as e the uidelinesset out by the Commission.


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computation of Marginal Participation Factor.The simulations shall be carried out by the IA byusing software duly audited and made available

by CERC.


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Annual Average YTC (after truing up) of eachline shall then be attributed to eak and othethan peak periods of each season depending

upon the hours of peak and other than peak.


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The annual average YTC (of each period in

attributed to the total change in flow in each line.

Rs/MW/Hour at each node in each block of

months shall then be com uted.


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Zoning of Nodes [2]

Based on the charges fo each node, IA shallaggregate the charges for geographically and

create zones. Zones shall contain relevant

nodes whose costs are within the same ran e.


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The demand zones shall normally be the statecontrol areas exce t in the case of NorthEastern States, which are considered as a single

demand zone. Generation zones are formed bycombining the generators connected to theISTS.


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Transmission char es fo thermal owe

generators either directly connected with ISTS orthrough pooling stations that are designed to

MW for inter-state transfer shall be determined

as char es at these s ecific nodes (such nodesshall be considered as separate generationzones) and not clubbed with other generator

.


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generators either directly connected with ISTS orthrough pooling stations that are designed tohandle generation capacity of more than 500

MW for inter-state transfer shall be determinedas c arges a ese spec c no es suc no esshall be considered as separate generation

nodes in the area.


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Zone shall normally be fixed for an applicationeriod. Howeve in case of si nificant chan es

in power system during a year, rezoning shall be

done with prior approval fromthe Commission.


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e ermna on o ransmss on arges [2]

shall be determined by computing the weightedaverage of nodal charges at each node in thezone. This shall be used to calculate the PoC

charges of a zone.


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the respective node in the 400 kV truncatednetwork.

Ten (10) such values shall be first obtained for

each zone corresponding to peak and off peakconditions fo the five seasons. These ten valuesshall then be used to determine the annual POC

.


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The PoC charge of a zone shall be sum ofn orm c arge an ona arge n e

proportion as specified by the Commission.

Example:

PoC Charge (PoC) = m * Uniform Charge (UC) + n *Zonal Charge(ZC)

where m and n are the constants specified in the regulation

w c s . or n a wo years.


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The Uniform Char e com onent of PoC char e shall becalculated as follows:

UC = Total ARR/ (Sum of Approved Injection +Sum of Approved

Withdrawal)

This shall be worked out separately for the NEW grid.


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Unless or otherwise revised by the Commission,PoC Char e shall com rise of 50% of UniformCharge and 50% Zonal Charge.


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The under/over recovery on account of revenuere uirement of intervenin assets PoC char esshall be scaled on pro-rata basis.


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Generating stations connected at 220 kV andbelow which are not featurin in the reducednetwork shall be charged at the zonal charges

determined for the regions where suchgenerators are physically located.


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e erences

[1] Anjan Roy, A. R. Abhyankar, P. Pentayya, S. A. Khaparde,Electricity transmission pricing :Tracing based Point of Connection

tariff for Indian power system, Power Engineering Society GeneralMeeting,2006.

[2] Report on Procedure for computation of point of connection (PoC)

transmission charges, prepared by National Load Despatch Centreew e mpemen ng gency n accor ance w en ra

Electricity Regulatory Commission, J uly, 2010.

Point of Connection Transmission Charges

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