Open Access
In
Interstate Transmission system
Principal Regulation 2008( 25th Jan’2008)
Amendment Regulation 2009(20th May’2009)
Order-Removal of difficulties,(28th June,2011)
Order-Amendment to CTU procedure 28th Oct,2009
P. S.Das, Ch.Manager
ERLDC, POSOCO
3/23/2016
ERLDC: POSOCO
1
• Markets & Evolution-Overview
Contents
• Definitions
• Legal provisions
• Regulations 2-28 & CTU procedures
• Sample calculations- STOA Losses & charges
• Typical State OA procedures
3/23/2016
ERLDC: POSOCO
2
Evolution of Power Market in India
Capacity
Market
Ancillary
Market
PX
2008
Open Access
2004
ABT
2002-03
IEGC
Feb.’2000
INDIA
3,287,263 sq. km area
More than 1 Billion people (2001 census)
Installed Capacity of
141.08 GW (Jan-08)
August 2006
North synchronized
With Central Grid
March 2003
West synchronized
With East & Northeast
NEW Grid
South
Grid
October 1991
East and Northeast
synchronized
Central Grid
North
West
East
Northeast
South
Five Regional Grids
Five Frequencies
Merging of markets along with
synchronization of regions
Present Market at a Glance
Long Term
Market
12-25 Yr
Medium
Term
Market
3months
-3Years
Short Term Open Access
Bilateral
Transaction
3 month
ahead
Contingency
Transaction
Collective
Transaction
Day Ahead
Transaction
Day Ahead
ahead
After
On the day of
Clearance of operation
PX
Term
ahead
Schedules
Balancing Market ( UI )
( Real Time Operation )
DEFINITION OF “OPEN ACCESS” IN THE
ELECTRICITY ACT, 2003
.
“Open Access” means the non-discriminatory
provision for the use of transmission lines or
distribution system or associated facilities with
such lines or system by any licensee, or
consumer, or a person engaged in generation in
accordance with the regulations specified by the
Appropriate Commission”.
• Section 2(47) of Electricity Act 2003
LEGAL FRAMEWORK [SECTION-9(2)]
• Every person, who has constructed a captive
generating plant and maintains and operates such
plant, shall have the right to open access for the
purposes of carrying electricity from his captive
generating plant to the destination of his use
• Provided that such open access shall be subject to
availability of adequate transmission facility and such
availability of transmission facility shall be determined
by the Central Transmission Utility or the State
Transmission Utility, as the case may be
Legal Framework(Sections 38/39/40/42)
CTU / STU/ Distribution licensee
Transmission licensee-functions & duties
/
• To provide non-discriminatory open access to its
transmission system for use by(i) any licensee or generating company on payment of the
transmission charges; or
(ii) any consumer as and when such open access is provided by
the State Commission under sub-section (2) of section 42, on
payment of the transmission charges and a surcharge thereon,
as may be specified by the Central Commission:.
• CTU can not engage in generation/trading.
• STU can not engage in trading
• Transmission Licensee can not engage in trading
Regulation 2: Definitions
• “bilateral transaction” means a transaction for exchange
of energy (MWh) between a specified buyer and a
specified seller, directly or through a trading licensee or
discovered at power exchange through anonymous
bidding, from a specified point of injection to a specified
point of drawl for a fixed or varying quantum of power
(MW) for any time period during a month
• “collective transaction” means a set of transactions
discovered in power exchange through anonymous,
simultaneous competitive bidding by buyers and sellers;
• “regional entity” means a person whose metering and
energy accounting is done at the regional level;
•
“intra-State entity” means a person whose metering and
energy accounting is done by the State Load Despatch
Centre or by any other authorized State utility;
Regulation 2: Definitions….contd
• “short-term customer” means a person who has
availed or intends to avail short term open access
• “short-term open access” means open access for a
period up to one (1)month at one time
• “regional entity” means a person whose metering
and energy accounting is done at the regional level;
• Short term market means a market with contracts for
a period not exceeding one year
from :: Power markets 2010 Regs
• Short term access applications allowed upto 3
months in advance considering visibility & ATC/TTC
issues.
Regulation 2: Definitions….contd
• “State network” means network owned by the State
Transmission Utility, distribution licensee or any other
person granted licence by the State Commission to
construct, operate and maintain the transmission
system;
• “State utility” means a State Transmission Utility, or a
State Electricity Board,or Electricity Department of the
State, or a State Government organization authorized to
sell or purchase electricity on behalf of the State;
•
“time block” means 15 minutes time period specified in
the Grid Code for the purposes of scheduling and
despatch; and
Regulation 3: Scope
• The long-term-customer and the medium-term
customer shall have priority over the short-term
customer for use of the inter-State transmission
system.
• The short-term customer shall be eligible for shortterm open access over the surplus capacity
available on the inter-State transmission system
after use by the long-term customer and the
medium-term customer, by virtue of
• inherent design margins;
• margins available due to variation in power flows; and
• Margins available due to in-built spare transmission
capacity created to cater to future load growth or
generation addition.
Regulation 4: Detailed Procedure
•
Subject to the provisions of these regulations, the
Central Transmission Utility, till the Regional Load
Despatch Centre is operated by it and thereafter
the Government company or any authority or
corporation notified by the Central Government
under subsection (2) of Section 27 of the Act:
shall, after obtaining prior approval of the
Commission, issue the detailed procedure to
operationalise open access and on any residual
matter not covered under these regulations
Regulation 5: Nodal Agency
• The nodal agency for bilateral
transactions shall be the Regional Load
Despatch Centre of the region where
point of drawal of electricity is situated
and in case of the collective
transactions, the nodal agency shall be
the National Load Despatch Centre.
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NODAL AGENCY
• For Short-Term Customers
– RLDC of the Region in which the drawal
point is located.
• For Long & Medium Term Customers
– Central Transmission Utility (CTU), if its
system is used
– Transmission Licensee/ STU of the region
in which the drawl point is located when
CTU system is not involved.
Regulation
6:
Submission
of
STOA
Application
• A short-term customer or the power exchange (on behalf of buyers and
sellers) intending to avail of STOA for use of the transmission lines or
associated facilities for such lines on the ISTS, shall make an application
to the nodal agency
• The application for a bilateral transaction shall contain the details, such
as
– names and location of supplier and buyer,
– contracted power (MW) to be scheduled and interface at which it is
referred to,
– point of injection,
– point of drawal,
– starting time block and date,
– ending time block and date, and
– such other information that may be required in the detailed
procedure.
• The application for a collective transaction shall contain the requisite
details in accordance with the detailed procedure.
GENERAL CONDITIONS/APPLICATION SUBMISSION
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• As per OA regulations Dtd. 25/01/08 w.e.f 01/04/08 &
OA Amendment Regulations Dtd. 20/05/09 &
as per order-amendment to CTU procedure Dtd.28/10/09
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• RLDC will check if connectivity with CTU/ ISTS or STU system (as
the case may be) is established, necessary metering,protection,
communication are in place, transfer capability upto the CTU
network for power flow of the quantum of injection/drawal
applied for is available on the date of application and whether the
applicant has undertaken to abide by the Central Electricity
Authority (Technical Standards for Connectivity to the Grid)
Regulations, 2007.
• Application to be submitted to::
– Nodal RLDC where point of drawal is situated
– & also to all RLDCs involved in the transaction
• Application Contents
– Details:: Buyer / Seller / Point of injection/ point of drawal /
Contracted power at supplier interface/ date/ time period (as
per
(Format-I-Application
for
scheduling)
alongwith
application fee/SLDC concurrance
Regulation 7: Application Fee
• An application made for each bilateral
transaction or the collective transaction shall be
accompanied by a non-refundable fee of Rupees
five thousand
(` 5000/-)only
• Provided that the fee for bilateral transaction on
the day of the application or on the day
immediately following the day of the application
may be deposited within three working days of
submission of the application.
Regulation 8: Concurrence of SLDC for bilateral and collective
transactions
• When a Proposed bilateral transaction has a State
utility or an intra-State entity as a buyer or a seller
– concurrence of the SLDC shall be obtained in advance and
submitted along with the application to the nodal agency in
the form as in the detailed procedure.
• When a State utility or an intra-State entity proposes
to participate in trading through a power exchange, it
shall obtain
– a “no objection” or a prior standing clearance from the
SLDC in the form as in the detailed procedure, specifying
the MW up to which the entity may submit a buy or sell bid
in a power exchange.
Regulation 8: Concurrence of SLDC for bilateral and
collective transactions…..contd
3(a) For obtaining concurrence or ‘no objection’ or prior
standing
clearance :
• Application before the SLDC
• Acknowledgement receipt of the application, either by email or fax, or any other recognised mode ,
• within twenty four hours
• At the time of submission in case submitted in person
3(b) SLDC shall verify the following, namely(i) existence of infrastructure necessary for time-block-wise
energy metering and accounting in accordance with the
provisions of the Grid Code in force, and
(ii) availability of surplus transmission capacity in the State
network.
3(c)
SLDC to concur ‘no objection’ / prior standing clearance
• Within three (3) working days if infrastructure exists
• Within seven (7) working days for a first time STOA
Customer
• Within two (2) working days for a defective/incomplete
application
Regulation 8: Concurrence of SLDC for bilateral and
collective transactions…..contd
• In case of SLDCs refusal ( Application is in order)
– To be communicated, within the period of three (3)
working days or seven (7) working days
– Reasons for such refusal:
• In case of no Communication by SLDC
– STOA shall be deemed to have been granted:
• In case of deemed STOA grant by SLDC
– the applicant while making application shall submit
to the nodal agency an affidavit (in the format
provided in the detailed procedure), duly notarised,
declaring that –
• (a) the SLDC has failed to convey any deficiency
or defect in the application or its refusal or
concurrence or ‘no objection’ or prior standing
clearance
Regulation 8: Concurrence of SLDC for bilateral and
collective transactions…..contd
• (b) necessary infrastructure for time-block-wise energy
metering and accounting in accordance with the
provisions of the Grid Code in force, is in place; and
enclosing with the affidavit –
– (i) a copy of the complete application after
removal of deficiency or rectification of
defects, if any communicated, made to the
SLDC for seeking concurrence or ‘no
objection’ or prior standing clearance, as the
case may be, and
– (ii) a copy of the acknowledgement, if any,
given by the SLDC, or any other evidence in
support of delivery of the application.
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SUBMISSION OF APPLICATION
• SLDC concurrance
– Concerned SLDCs concurrence in advance
(Format - II-Concurrance from SLDC)
– In case of deemed concurrance the applicant
alongwith the application shall submit duly
notarized affidavit (Format-IIA-Affidavit-Deemed
concurrance from SLDC
• RLDC concurrance
- Bilateral Transaction having a State Utility or an intrastate Entity as a Buyer/Seller in other region::
concurrence of the concerned Regional Load
Despatch Centre(s).
- Nodal applications to be considered first before
giving other concurrance
- Reasons for refusal
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SUBMISSION OF APPLICATION
• Affidavit for deemed SLDC concurrance:
• (a) the State Load Despatch Centre has failed to convey any
deficiency or defect in the application or its refusal or
concurrence or ‘no objection’ or prior standing clearance, as
the case may be, within the specified time(3/7days)
• (b) necessary infrastructure for time-block-wise energy
metering and accounting in accordance with the provisions of
the Grid Code in force, is in place; and enclosing with the
affidavit –
• (i) a copy of the complete application after removal of
deficiency or rectification of defects, if any communicated for
seeking concurrence or ‘no objection’ or prior standing
clearance, as the case may be, and
• (ii) a copy of the acknowledgement, if any, given by the State
Load Despatch Centre, or any other evidence in support of
delivery of the application to the State Load Despatch Centre.”
Categories & Time Line For Open Access
M0
M1
DL-10
Adv
Application for
M1
DL-5
DL
DL+5
M2
DOP-4
M3
DOP
DOP-1
FCFS
CONTINGENCY
Adv Application
for M2,
Approvals for
M1
Adv Application
for M3,
Approvals for
M2
Approvals for
M3
Day Ahead /
PX
LEGEND:
DOP : Day of Operation
DL : Last day of M0
Regulation 9:
Procedure for Advance Scheduling
for bilateral transactions
ADVANCE SCHEDULING
• Advance Scheduling – 3 months in advance
• Separate Application –
– Month wise - each transaction
• Time Line for submission
– Last date for submission ( -10 / -5 / 0 days prior to end of current
month MO – for transaction in M1, M2, M3)
– Cut-off time of application: 17:30 Hrs. of last day (Day 0)
– Request for concurrence (RLDC) – by 12:00 Hrs.(Day 1) (Format- III)
– Concurrence - by 20:00 Hrs (Day 1)
– Congestion Information to Applicant – 12:00 Hrs (Day 2)-FormatIV(Congestion information-Advance scheduling)
– Revised Request/re-routing – 11:00 HRs. (Day3)-Format-V-Request
for revision due to congestion)
– E-bidding – in case of Congestion (Day 4)
– Acceptance/Refusal of Scheduling Request – (Day5)-Format-VIAcceptance for scheduling
Application for advance scheduling
M0
M1
M2
M3
Applicatio
n
Separate application shall be made for each month,
and for each transaction.
Time Line for Advance Scheduling
M1
M0
10 5
M2
M3
5
Processing time
for RLDCs
Last Day for
submission of
Applications for
transactions in
M1, M2, M3
Regulation 10 Congestion Management :
e- Bidding Procedure
• Invitation of Bids from the concerned applicant
– period of congestion
– RTS/IR corridor expected to get over stressed
• Only Registered Users
– User ID & Password
– Electronic submission – website of CTU
– Bid Closing time as specified
– Single Price Bid
– No Modification/withdrawal once submitted
• Bid Price
• – In addition to Open Access Transmission charges
- Multiples of Rs. 10/ MWh . ( Min. Rs. 10/MWh)
• Mandatory - Non-participation – Rejection of Application
• Acceptance - Decreasing order of Price Quoted
• Equal Price Bids – Pro-rata
• Applicant getting approval < request  Charges as quoted
• Applicant getting approval=request  Charges as paid by last
applicant getting approval = request
Regulation 11,12,&13
Procedure for FCFS, Day ahead &
Contingency bilateral transactions
“FIRST-COME-FIRST-SERVED”(FCFS)
• Scope
– FCFS shall be considered only when transactions are
commencing & terminating in the same calender month.
• Separate Application for each month
• To be submitted 4 days prior to date of Scheduling
• Processing time – 3 days on FCFS basis
• Applications received during last 10 / 5 days of month of M0 for M1/M2
would be considered only after complete processing of Advance
transactions for M1 & M2
• Application Received upto 1730 hrs in a day to be processed together
– same priority
• Application Received after 17:30 Hrs. - to be considered as received
next day
• Congestion Management – pro-rata
Application for FCFS scheduling
M1
M0
D-04 D-03 D0
17:30 Hrs
M2
M3
Processing time
Application
Separate application shall be made for each transaction.
Regulation 12: DAY-AHEAD
•
Applications received within 3 days prior to the
day of Scheduling and up to 15:00 Hrs. of the day
immediately preceding the day of scheduling shall
be treated as same priority
•
Processing only after processing of the Collective
Transactions of the Power Exchange (s)
•
Congestion Management – Pro-rata
Application for Day ahead scheduling
M1
M0
D-03
D0
M2
M3
Processing time
Application
Approval after Collective
Separate application for each transaction.
Regulation 13: CONTINGENCY
•
Buying Utility/Trader on its behalf to make an Application
to the Nodal RLDC
•
To be considered after 1500 hrs of the day immediately
preceding the day of scheduling
•
In case of intra-day/same day –
scheduling from 6th time block
•
Congestion Management – Pro-rata
Regulation 14: Revision of Schedule
•
Only in case of “Advance Scheduling” or “First-Cum-First Served basis”
•
Accepted schedule for Day-Ahead & Contingency transaction shall not be revised
or cancelled except for tripping of generators > 100MW as per Cl.6.5.19 of IEGC.
Revision w.e.f 4th time block of intimation to RLDC
Generator to furnish expected restoration time from which original schedules
would become effective.
•
•
•
For
period
of
revision/cancellation
transmission/operating charges
upto
two
days::
Original
•
For period of revision/cancellation > two days:: Transmission Charges and
Operating Charges for the period beyond two (2) days shall be payable as per the
revised accepted schedule and for the first two (2) days as per the original
schedule.
•
Margin Available – released for scheduling of eligible Open Access Transactions
EXAMPLE OF DOWNWARD REVISION
INITIAL APPLICATION
R0
From date
20-Mar-11
To Date
31-Mar-11
From time To Time
00:00 24:00
Operating charges
R1
From date
20-Mar-11
MW
MWh
100
28800.00
Scheduled MWh
28800.00
Billed MWh 28800.00
12 days
APPLICATION FOR REVISION ON 17TH March
App. Date : 17th
To Date
From time To Time
MW
MWh
50
14400.00
Scheduled MWh
14400.00
Billed MWh 16800.00
Operating charges
12 days
additional charge =(100-50)*24*2 for 20th & 21st March
2400.00
R1
From date
20-Mar-11
23-03-2011
31-Mar-11
00:00 24:00
APPLICATION FOR REVISION ON 2OTH March
App. Date : 20th
To Date
From time To Time
MW
MWh
22-Mar-11
31-03-2011
00:00 24:00
00:00 24:00
100
7200.00
50
10800.00
Scheduled MWh
18000.00
Billed MWh 20400.00
Operating charges
12 days
additional charge =(100-50)*24*2 for 23rd & 24th March
2400.00
Regulation 15:: CURTAILMENT IN CASE OF
TRANSMISSION CONSTRAINTS
• Transmission constraint or to maintain grid security
• Curtailed in the manner, which in the opinion of RLDC, would relieve
transmission constraints/ enhance grid security
• Curtailment priority ::
STOA(bilat)Collective(PX)MTOALTA
• In case of reallocation of GOI share leading to corridor constraints
• Rerouting allowed without curtailment of existing transactions
• Pro-rata refund of Transmission Charges
• No revision of operating charges
Regulation 16: Transmission Charges [repealed by 19(1)
of Regulations on sharing of iSTS charges-2010]
Type of Transaction
Rs./ MWh
Bilateral, intra-regional
80
Bilateral , Between
adjacent regions
Bilateral, wheeling through
one or more regions
Collective
160
240
100
(per each point of injection and
each point of drawal)
Transmission Charges …. contd
• The intra-State entities shall pay the transmission charges for use of
the State network as fixed by the respective State Commission in
addition to the charges specifie
• Provided that in case the State Commission has not determined the
transmission charges, the charges for use of respective State network
shall be payable at the rate of Rs.80/MWh for the electricity
transmitted:
• Provided further that non-fixation of the transmission charges by the
State Commission for use of the State network shall not be a ground
for refusal of short –term open access:
• Provided also that the transmission charges payable for use of the
State network shall be conveyed to the Regional Load Despatch
Centre concerned who shall display these rates on its web site:
• Provided also that the transmission charges payable for use of the
State network shall not be revised retrospectively.
Application of POC methodology
for STOA transactions
Calculation of Nodal POCs
Input
Network Parameters
Load & Generation Data
Load Flow Studies
Converged Network
Network
Reduction
Reduced Network
Line wise YTC
Software for PoC
Charge & Loss
Computation
Output
Nodal PoC
Charges and
LAF
Application of POC Transmission Charge methodology
for STOA transactions
• Nodal POCs zoned to form Zonal POC for each Control area
• Slabbing done to fall into either high, Average or Low slab
For New Grid:
• High  Rs. 1,00,000/Mw/month
Average  Rs. 85,000/MW/Month Low
Rs.70,000//MW/Month
• Converted to High  14paise/unit Average  12 paise/unit Low 
10paise/unit
• Hence STOA rates applicable are Rs.140/MWH, Rs.120/MWh, Rs.100/MWh for
High, average, Low slab respectively
For SR Grid :
• Slab rates are Rs. 150/MWh, 130/MWh, 110/MWH for High, Average, Low slabs
respectively
•
•
Total No. of combinations possible(not permutations as order does not
matter) :
NC + N = N(N+1)/2
[considering N additional cases for same POC
2
injection/withdrawal rates]
Thus increase in total number of stamp rates for various transactions have
risen from 3 to 21
Application of POC Transmission Charge methodology
for STOA transactions
• Transmission charges payable by Entity X injecting 100MW RTC power to
Entity Y
• Assume X falls in high injection slab in NEW Grid while Y fall in low
withdrawal slab in SR Grid
• Hence POC injection for X  Rs 140/MWH
• Withdrawal POC for Y  Rs.110/MWh
• Transmission charges payable for injection would be :
= 2400MWh x 140
• Transmission charges payable for withdrawal would be:
= 2400MWh X 110
• Total charges payable by Trader to Nodal RLDC:
= 2400*(140+110) Rs.
• STU charges would be payable in addition
Regulation 16: Transmission Charge as per POC
regulations
Regulation 16: Transmission Charge as per POC
regulations
Regulation 16: Transmission Charge as per POC
regulations
Regulation 16: Transmission Charge as per POC
regulations
Regulation 17: Operating Charges
• Bilateral Transaction
– Rs.2000/- per day or part of the day/transaction /RLDC
– Rs.2000/- per day or part of the day/transaction /SLDC
• Collective Transaction
– Rs.5000/- per day or part of the day/state to NLDC
– Rs.2000/- per day or part of the day/transaction for each
SLDCs involved
– NLDC to share operating charges with each RLDC
• NLDC keeps Rs.2000/- and Rs.3000/- divided amongst 5
RLDCS @ Rs.600/RLDC
– Clubbing of buyers & sellers within a state
– Each group be considered as single entity for Operating
charges and for scheduling by NLDC
– Each point of drawal & injection shall be counted separately for
the purpose of intra-state transmission charges
Regulation 18:
Payment of transmission charges and
operating charges
• Bilateral transaction:
– the applicant to deposit with the nodal agency
transmission charges and operating charges
within three (3) working days of grant of
acceptance
• Collective transactions:
– the power exchange shall deposit with the nodal
agency these charges by the next working day
falling after the day on which its application was
processed
– the transmission charges for use of State network
and operating charges for SLDC shall be settled
directly by the power exchange with respective
SLDC.
Regulation 19: Default in payment of STOA charges
• Default in payment of the application fee or
specified charges :
– charges the nodal agency may decide not to
schedule the transaction, or
– to cancel the scheduling of already scheduled
transaction or
– not to entertain any application of such persons
in future until such time the default is cured
• The person committing default in payment
– Shall pay simple interest at the rate of 0.04% for
each day of default.
DEFAULT IN PAYMENT OF OPEN ACCESS
CHARGES – Additional Pts
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Cheque has been dishonored
– No cheque payment - next three (3) months
– Payment to be made by electronic
transfer/demand draft
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INCORPORATION IN DAILY SCHEDULES
•
Incorporation in Daily Schedules of the Regional
Entities
•
Average energy losses - estimated on weekly basis
and converted to Tier I, II, III slabs
– RLDCs – ISTS (Inter State Control area)
– SLDC – (Intra-State/Control area)
•
Resolution of 0.01 MW at each State/inter-Regional
boundaries.
•
Losses on the system to be compensated by
Drawing utility (net drawal schedule after deducting
losses) till 30th Sep,2011
•
W.e.f 1st October,2011 losses to apportioned to both
buyers & sellers
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COMMERCIAL CONDITIONS (SUMMARY)
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– Payment to be made by Applicant to the Nodal
RLDC
– within three working days from the date of
acceptance
– Payment as per MWh contract value
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– Along with application (for Advance/FCFS
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– With in 3 working days ( for same day or next day
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transaction)
submission.
from
the
date
of
application
• Operating charges:: Rs. 2000/- per day for each
RLDCs/SLDCs involved and Rs.5000/- per day per
entity for collective
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COMMERCIAL CONDITIONS (SUMMARY)CTD..
• If State utility is Buyer/Seller, Transmission Charges
shall not include the charges for that State network
and the Operating Charges for that State Load
Dispatch Center. A certificate in this regard from the
concerned STU(s)/SLDCs shall be submitted by the
Applicant
• The transaction wise payment details shall be
submitted as per enclosed format[FORMAT-VII:
“Details of Payment”].
Regulation 20:: Unscheduled Inter- change
(UI) Charges
• All transactions for State utilities and for intra-State entities scheduled
by the nodal agencies shall be accounted for and included in the
respective day-ahead net interchange schedules of the concerned
regional entity issued by the RLDC
• Based on net metering on the periphery of each regional entity,
composite UI accounts shall be issued for each regional entity on a
weekly cycle and transaction-wise UI accounting, and UI accounting
for intra-State entities shall not be carried out at the regional level.
• The State utility designated for the purpose of collection /
disbursement of UI charges from / to intra-State entities shall be
responsible for timely payment of the State’s composite dues to the
regional UI pool account.
Regulation 20:: Unscheduled Inter- change
(UI) Charges
• Any mismatch between the scheduled and the actual drawal at drawal
points and scheduled and the actual injection at injection points for
the intra-State entities shall be determined by the concerned SLDC
and covered in the intra-State UI accounting scheme.
• Unless specified otherwise by the concerned State Commission, UI
rate for intra-State entity shall be 105% (for over-drawals or under
generation) and 95% (for under-drawals or over generation) of UI rate
at the periphery of regional entity.
• No charges, other than those specified under these regulations shall
be payable by any person granted short-term open access under these
regulations.
Regulation 21: Reactive Energy Charges
• No separate reactive energy charge accounting for
STOA transactions shall be carried out at inter-State
level:
Provided that the State Utility designated for the
purpose shall be responsible for timely payment of the
State’s composite dues to the regional reactive charge
account in accordance with the provisions of the Grid
Code.
• The reactive energy drawals and injections by the intraState entities shall be governed by the regulations
applicable within the State concerned.
Regulation22: Special Energy Meters
1. Special Energy Meters shall be installed by the Central
Transmission Utility for and at the cost of the regional
entities and by the State Transmission Utility for and at
the cost of the intra-State entities.
2. Special Energy Meters installed shall be capable of timedifferentiated measurements for time block wise active
energy and voltage differentiated measurement of
reactive energy in accordance with Annexure – 2 to
Chapter–6 of the Grid Code.
3. Special Energy Meters shall always be maintained in
good condition.
4. Special Energy Meters for the regional entities shall be
open for inspection by any person authorized by the
Central Transmission Utility or the Regional Load
Despatch Centre.
Regulation23:: Transmission losses
1. The buyers and sellers of the electricity shall absorb
apportioned energy losses in the transmission system as
estimated by the Regional Load Despatch Centre and the State
Load Despatch Centre concerned, and applied in accordance
with the detailed procedure.
2. The energy losses shall be accounted for by providing a
differential between schedules at the points of supply, interutility transfer and drawal of electricity.
3. The applicable transmission losses for the regional
transmission system as well as for State network shall be
declared in advance and shall not be revised retrospectively.
Regulation23:: Transmission losses- Amendment of
procedures by CTU
•
Nodal POC losses found from Webnetuse software
•
Zoning done to form loss for each scheduling entity
•
Assume POC injection loss of X = a% & POC withdrawal loss of B = y%
•
For 100Mw injection transaction from X to Y:
Upto 30th September,2011 losses to be absorbed by Buyers only
Point of contract  Sellers periphery
Injection schedule of X = -100Mw
Withdrawal schedule of Y = 100*(1-a/100)*(1-b/100) rounded off to 2 decimals
After 1st October,2011 losses to be apportioned to both buyer & Seller 
Point of contract  Regional periphery where entity located
Injection schedule of X = -100/(1-a/100) rounded to 2 decimals
Withdrawal schedule of Y = 100*(1-b/100) rounded to 2 decimals
•
Losses classified as Tier-I , II , II according to Low, Average or High slab.
Loss calculation-Amended CTU loss procedures
•
•
If W current week, loss of week W-1 is estimated & applied for week W+1
If a = losses as per SEM data for W-1 losses for Tier I, II, III slabs would be
Low(Tier-I) = [a/2-0.3]%
Average(Tier-II)= a/2
High(Tier-III) =
[a/2+0.3]%
E.g. estimated loss for w-1 for ER = 3.90%
Low(Tier-I) = 1.65%
Average(Tier-II)= 1.95%
High(Tier-III) =2.25%
The Tier-I, II, II slabs are fixed as per studies & are constant for the review period
are as below 
•
Similiarly injection/withdrawal losses for all other regions are calculated
CERC Approved Results – Loss slabs
CERC Approved Results – Loss slabs
CERC Approved Results – Loss slabs
• Regulation 24::Compliance of Grid
Code
– The buyers and sellers of energy shall
comply with the provisions of the Grid
Code in force from time to time.
Regulation 25: Collection and Disbursement of Transmission Charges
and Operating Charges(previous)
• The transmission charges and the operating charges payable by the
persons allowed short-term open access shall be collected and disbursed
by the nodal agency, except for transmission charges for State network
and operating charges for SLDC in the case of the collective transaction
• Operating/Transmission charges for SLDCs/STUs to be settled directly by
PX with the concerned SLDC/STU
• The transmission charges collected by the nodal agency for use of the
transmission system other than State network, for a bilateral transaction
shall be directly disbursed to the long-term customers
– 25% of the Tr. Charge to the CTU
– Intra-regional bilateral transaction: 75% of the transmission charges to
the region concerned.
– bilateral transaction between adjacent regions: 37.5% of the
transmission charges for each region.
– bilateral transaction through one or more intervening regions: 25% of
the transmission charges for each of importing and exporting each
region and remaining 25% of the transmission charges to be allocated
equally among all intervening regions.
Reg.25(previous)…Ctd
• The transmission charges collected for use of the transmission
system other than State network for a collective transaction for
each point of injection and each point of drawal shall be
disbursed by the nodal agency in the following manner,
namely– Central Transmission Utility: 25%
– Long-term customers of the region of point of injection or
drawal, as the case may be, is situated: 75%
• The transmission charges shall be disbursed to the long-term
customers inproportion to the monthly transmission charges
payable by them.
• The transmission charges for use of State network shall be
disbursed to the State Transmission Utility concerned.
• In case a State utility is the short-term customer, the operating
charges and the transmission charges collected by the nodal
agency shall not include the charges for use of the State
network and operating charges for the State LoadDespatch
Centre.”
Collection and Disbursement of Transmission Charges and Operating
Charges (amended vide CERC order Dtd. 28th June,2011)
• The transmission charges and operating charges payable by the persons
allowed short-term open access shall be collected by the nodal agency,
except for transmission charges for state network and operating charges
for State Load Despatch Centre in the case of the collective transaction.
• The transmission charges collected by the nodal agency for use of the
transmission system other than State network, for both bilateral and
collective transaction shall be given to the CTU for further disbursement
to long-term customers in accordance to Central Electricity Regulatory
Commission (Sharing of Inter State Transmission Charges and Losses)
Regulations, 2010, and the approved detailed procedure there under for
Billing, Collection and Disbursement.
Collection and Disbursement of Transmission Charges and Operating
Charges (amended vide CERC order Dtd. 28th June,2011)
• The transmission charges collected for use of the transmission system
other than State network for a bilateral or collective transaction for each
point of injection and each point of drawal shall be disbursed by the CTU
after adjusting against the charges for Long Term Access without
identified beneficiaries in the same region in accordance with detailed
procedure for Billing, Collection and Disbursement in the following
manner, namely(a) Central Transmission Utility: 25%
(b) Long-term customers of the synchronously connected grid: 75%
• The transmission charges for use of State network shall be disbursed to
the State Transmission Utility concerned.
• In case a State utility is the short-term customer, the operating charges
and the transmission charges collected by the nodal agency shall not
include the charges for use of the State network and operating charges
for the State Load Despatch Centre.”
Billing, Collection & Disbursement Procedures Approved by CERC Vide
order dtd.29th April,2011 – Para &(3) b & c
• For STOA, DIC shall have to pay applicable transmission charges to the
RLDC/NLDC at the time of application. The payment made for the STOA
charges for varying quantum and varying duration with respect to (i)
bilateral transactions to the region of LTA granted and (ii) all collective
transactions, shall be credited to that DIC in the next month billing subject
to the upper limit of the amount paid as LTA charges after accounting for
the MTOA charges, if any, as per 7.2 (b) above, provided that the STOA is
in the direction of the targeted regions mentioned in the LTA granted to
the DIC by the CTU.
• If the STOA is other than the targeted regions mentioned in the LTA, then
such STOA, PoC charges shall not be adjusted against the LTA granted
by the CTU and a separate applicable PoC charges shall have to be paid
by the DIC.
Billing, Collection & Disbursement Procedures Approved by CERC Vide
order dtd.29th April,2011 – Para &(3) b & c
• Provided that this adjustment shall not be done for collective transaction
and bilateral transactions done through portfolio trader.
• For STOA transactions not qualifying for aforementioned credit, the STOA
charges after disbursing 25% of such transmission charges to the CTU in
accordance with the CERC (Open Access) in inter-State Transmission
Regulation 2008 and amendment thereof, shall be adjusted with respect to
the paying DICs (for the respective applicable month) by the next 30 days
of receipt of such payments.
BCD Procedures-Amendment order Dtd.15th June,2011
• For STOA, DIC shall have to pay applicable transmission charges to the
RLDC/NLDC at the time of application. The payment made for the STOA
charges for the quantum with respect to bilateral transactions upto the
LTA for the specific Region of LTA granted without identified
beneficiaries,, shall be credited to that DIC in the next month billing after
accounting for the MTOA charges, if any, as per 7.2 (b) above.
• Provided that the STOA is in the direction of the targeted regions
mentioned in the LTA granted to the DIC by the CTU. If the STOA is other
than the targeted regions mentioned in the LTA, then such STOA, PoC
charges shall not be adjusted against the LTA granted by the CTU and a
separate applicable PoC charges shall have to be paid by the DIC.
• Provided that this adjustment shall not be done for bilateral transactions
done through portfolio trader.”
C
T
U
DISBURSAL OF PAYMENT – Additional Pts
• Nodal RLDC :: Reconcile the Open Access Charges
collected
for
previous
month
&
disburse
the
P
Transmission/Operating Charges
R • Transmission Charges and Operating Charges – for State
System
O
– Concerned STUs/SLDCs
C
E • Refunds due to curtailment/revision in previous month
D
– 15th day of the current month
U • No responsibilty for payment dishonour: Disbursement only
to extent of receipt
R
E
S
Short-Term Open Access transaction
by embedded utilities
EXAMPLE
From
To
Quantum
Path
: TATA Steel , DVC
: NDPL Discom, Delhi
: 100 MW
: ER – WR - NR
Source : SAIL
Loss calculation Methodology (upto 30th Sep,2011)
Contract value  100MW
Transaction  Tata steel- DVC - ER – WR – NR – DTL- NDPL
DVC STU loss  3%
DVC Inj POC loss  1.5%
Delhi withdrawal POC loss  2%
DTL STU loss  1.5%
97MW
100MW
CONTRACT
TATA
STEEL BDY
ER
95.55MW
REGIONAL
BDY
DVC BDY
93.64MW
DTL BDY
TATA
STEEL
WR
NDPL
92.24MW
NDPL BDY
NR
RLDCs need to
show schedules
only upto requisite
control area
periphery
Hence schedule
values only upto
DVC boundary &
DTL boundary need
be shown by
RLDCs.
Accordingly, all
STU losses are not
required. [Values
are shown for
understanding
only].
Loss calculation Methodology (w.e.f 1st October,2011)
Contract value  100MW
Transaction  Tata steel- DVC - ER – WR – NR – DTL- NDPL
DVC STU loss  3%
DVC Inj POC loss  1.5%
Delhi withdrawal POC loss  2%
DTL STU loss  1.5%
101.52MW
104.66MW
ER
100MW
CONTRACT
DVC BDY
98MW
TATA
STEEL BDY
DTL BDY
TATA
STEEL
WR
NDPL
96.53MW
NDPL BDY
NR
RLDCs need to
show schedules
only upto requisite
control area
periphery
Hence schedule
values only upto
DVC boundary &
DTL boundary need
be shown by
RLDCs.
Accordingly, STU
losses are not
required w.e.f
01/10/11 [Values
are shown for
understanding
only].
STOA charges calculation Methodology:: Tata Steel-DVC-ER-WR-NR-DTL-NDPL
Contract value  100MW RTC power x 5 days  12000MWh(total contracted energy)
Transaction  Tata steel- DVC - ER – WR – NR – DTL- NDPL
DVC injection POC  14p/unit  Rs.140/MWh
Delhi withdrawal POC  10p/unit  Rs.100/MWh
DVC STU
transmission
charges = 80 x
12000
DVC SLDC
operating
charges =
2000 x 5
Delhi
withdrawal
POC
transmission
charges =
100 x 12000
DTL STU
transmission
charges =
41.85 x
12000
NRLDC
operating
charges =
2000 x 5
DTL SLDC
operating
charges =
2000 x 5
TATA
STEEL
ERLDC
operating
charges =
2000 x 5
WR
100MW
CONTRACT
VALUE
WRLDC
operating
charges =
2000 x 5
ER
DVC injection
POC
transmission
charges = 140
x 12000
NDPL
NR
ALL OF ABOVE
+
NON REFUNDABLE APPLICATION FEES  Rs.5000/-
Upto 30th
Sep,2011
Contract value
at sellers’
periphery. No
change in
calculations
Sample bill for
the transaction
FORMAT - VI
OPEN ACCESS (BILATERAL TRANSACTION) - ACCEPTANCE FOR SCHEDULING
Nodal RLDC : NRLDC
Acceptance No. : ERLDC/BILAT/2011-12/
Ref : Original Application No. :
556 F
TPTCL/OA/2011-12/3072
TPTCL
Date
:
9/6/2011
Date
:
9/6/2011
1
Name of applicant :
2
Name of Injecting Entity / State / Region :
TATA STEEL / DVC/ ER
3
Name of Drawee Entity / State / Region :
NDPL / DTL / NR
4
5
Wheeling Region(s) :
NIL
Open Access Scheduling Accepted :
Date
Hours
From
To
From
To
0:00
24:00
15/Jun/2011
Registration Code :
ER0000TPTC
Schedule (MW)
Requested Accepted
100
100
Route
ER , WR, NR
19/Jun/2011
Total Mwh
6
12000
0
0
0
0
0
12000.00
Bidding Details :
Transmission System
7
Mwh
Payment Schedule :
i) Transmission Charges
Transmission System
STU / DVC
STU / Delhi
POC DVC injection
POC Delhi Withdrawal
Date
From
Hours
To
From
Applicable Bid Rate
( Rs. / Mwh )
To
Payment Due Date :
Rate (Rs./Mwh)
80
41.85
140
100
Mwh
12000
12000
12000
12000
9/10/2011
Total ( Rs )
960000
502200
1680000
1200000
0
4342200.0
Bidding
Total of (i) :
ii) Operating Charges
SLDC, DVC
SLDC DELHI
ERLDC
NRLDC
WRLDC
8
9
Rate (Rs./ Day)
2000
2000
2000
2000
2000
Number of Days
5
5
5
5
5
Total of (ii) :
Total ( Rs )
10000
10000
10000
10000
10000
50000
5000
4397200
iii) Non Refundable application fee ( if not paid earlier )
Grand Total ( I + ii + iii )
A curtailed acceptance is being granted on account of
Nil
This acceptance is subject to provisioning of CERC (Open Access in inter-State Transmission) Regulations,2008.
POSOCO Portion :
To: 1. Applicant:
35000
4362200
OTHERS :
TPTCL, Mahalxmi Bldg, Lower parel, Mumbai--400013
Fax :022-66310849
2. NRLDC, New Delhi
3. SLDCs:
SLDC, DVC
4. SLDCs:
SLDC, DTL, New Delhi, Th' NRLDC
Signature
Name
Designation
:
:
:
पूर्वी क्षेत्रीय भार प्रेषण केन्द्र
Regulation 25A:: STOA Not To Be Granted
• When so directed by the Commission, the National Load
Despatch Centre or the Regional Load Despatch Centre, as
the case may be, shall not grant short-term open access to
the entities and associates of such entities,
– who consistently and willfully default in payment of
• Unscheduled Interchange charges,
• transmission charges,
• reactive energy charges,
• congestion charges and
• fee and charges for National Load Despatch Centre or
Regional Load Despatch Centre
• including the charges for the Unified Load Despatch and
Communication Scheme
Regulation 26::Redressal Mechanism
• All disputes arising under
these regulations shall be
decided by the Commission
based on an application made
by the person aggrieved.
C
T
U
P
R
O
C
E
D
U
R
E
S
GENERAL CONDITIONS
• Entities which are making Application for the first time must
submit the “One- Time” information as per enclosed format
(FORMAT-VIII: “Registration Form) to the concerned nodal
RLDC.
• Application - through Post / fax
• Any amendment/modification
– fresh Application
• Applications not accorded the Acceptance:
– stand disposed off with suitable intimation to the concerned
Applicant(s)
• All costs/expenses/charges associated with the Application,
including Bank Draft, shall be borne by the Applicant.
• Incomplete / vague Application
– summarily rejected
• No charges payable for a transaction shall be adjusted by
against any other payments/charges.
• The Applicant shall abide by the provisions of The Electricity
Act, 2003, Indian Electricity Grid Code and CERC Regulations,
as amended from time to time
• Applicant shall keep each of the SLDCs/ RLDCs indemnified
Regulation 27:: Information System–NLDC &
RLDCs
National Load Despatch Centre and each Regional Load
Despatch Centre shall post the following information on their
websites in a separate web-page titled “Open access
information”:
a) These regulations;
b) The detailed procedure
c) A list of bilateral transactions accepted by the nodal agency, to be
displayed till the end of the month in which transactions are scheduled,
indicating:
(i) Name of customers;
(ii) Period of the short-term open access granted
(start date end date);
(iii) Point or points of injection;
(iv) Point or points of drawal;
(v) Transmission systems used (in terms of regions
and States);
(vi) Accepted schedule (MW) with start time and
end time
Regulation 27A::Information System– SLDCs
•
•
•
•
•
•
Each State Load Despatch Centre, shall within 60 days of coming into force of these
regulations, develop its website and post the following information on separate web-page
titled “information on Inter-State Open Access”:
(a) List of bilateral transactions for which concurrence has been granted and
list of entities to whom concurrence or “no objection” or prior standing
clearance, as the case may be, has been granted till the end of the month in
which such concurrence or no objection or prior standing clearance has
been granted, indicating:
– (i) Name of customer;
– (ii) Period of concurrence or “no objection” or standing clearance, as the
– case may be, (start date and end date);
– (iii) Point or points of injection and drawal,; and
– (iv) Accepted schedule (MW).
(b) Average transmission losses for the State network for the immediately
preceding 52 weeks;
(c) Applicable transmission charges and transmission losses for the State
network;
(d) List of applications where concurrence or “no objection” or standing
clearance, as the case may be, was not granted, along with reasons for
refusal, to be displayed till one month after the scheduling period given in
the application; and
(e) A list of applications pending for decision.]
Regulation 28 ::Savings and Repeal
• The provisions of the Central Electricity Regulatory Commission
(Open Access in inter-State Transmission) Regulations, 2004
shall not apply to the short-term open access] customers whose
applications are processed under these regulations.
• The provisions relating to long-term customers as contained in
the Central Electricity Regulatory Commission (Open Access in
inter-State Transmission) Regulations, 2004 shall continue to
apply till Commission notifies separate regulations covering
aspects relating to long-term customers.
• The provisions relating to short-term open access as contained
in the Central Electricity Regulatory Commission (Open Access
in inter-State Transmission) Regulations, 2004 shall stand
repealed on 1.4.2008.
OA FROM STATES’ PERSPECTIVE
Aspects to be covered
• FOR(Forum
of
Regulators)
website

www.forumofregulators.gov.in
• Model Terms & conditions for Intra State OA
Regulations released by FOR on Sep’2010
• Topics to be discussed to be limited to following
aspects:
–
–
–
–
–
–
Connectivity
Eligibility for OA
Categories for OA
Open Access Charges applicable
Limited STOA customer
Sample OA charges calculations
Connectivity
• Only a consumer having load of 10 MW and above or a
Generating Station having capacity of 10 MW and above shall be
eligible to obtain connectivity to the intra-State transmission
system, unless already connected, and shall apply for
connectivity, in accordance with the provisions in this chapter
• Generating Station having installed capacity less than 10 MW
shall be eligible to obtain connectivity to the Distribution system
and shall apply for connectivity as per the provisions of these
regulations, unless already connected, in accordance with the
provisions in this chapter.
Eligibility for OA
• Licensees, generating companies, captive generating plants and
consumers shall be eligible for open access to the intra-State
transmission system of the State Transmission Utility or any
transmission licensee on payment of transmission and other charges
as may be determined by the Commission
• Licensees, generating stations, captive generating plants and
consumers shall be eligible for open access to distribution system of
a distribution licensee on payment of the wheeling and other charges
as may be determined by the Commission
• Open access shall be permissible to the consumers seeking open
access capacity upto which SERC has introduced open access and
are connected through an independent feeder emanating from a
substation of licensee or industrial feeder provided that all the
consumers on such industrial feeder opt for open access and having
simultaneous schedule of drawal under such open access:
Eligibility for OA
• Provided that the consumers who are not on independent
feeders, shall be allowed open access subject to the condition
that they agree to rostering restrictions imposed by utility on the
feeders serving them
• Provided further that duties of the distribution licensee with
respect to such open access consumers shall be of a common
carrier providing non-discriminatory open access as per section
42(3) of the Act
• A person having been declared insolvent or bankrupt or having
outstanding dues against him for more than two months billing
of distribution/transmission licensee at the time of application
shall not be eligible for open access.
Categories for OA customers
•
The application procedure, application fee and the time frame of processing
request by eligible consumers seeking Open Access shall be based on the
following criteria:
•
(1) System to which connected
– (a) Intra-State transmission system
– (b) Distribution system
(2) Inter-se location of drawal and injection points
– (a) Both within the same distribution system
– (b) within the State but in different distribution systems
– (c) In different States
(3) Duration of Open Access
– (a) Long term access
– (b) Medium-term open access
– (c) Short-term open access
•
•
•
The period of Access for categorization of LT cusyomers is not yet uniform
across States e.g for WB >= 15 Yrs, Orissa >=25Yrs, Jharkhand >=10years
OA charges-Transmission charges
• Inter State charges as applicable
• Intra-State charges calculated as follows:
Transmission Charges = ATC/(PLST X365) (in Rs./MW-day)
Where,
ATC= Annual Transmission Charges determined by the Commission
for the State transmission system for the concerned year.
PLST= Peak load projected to be served by the State transmission
system in concerned year
• Transmission charges shall be payable on the basis of contracted
Capacity/ Scheduled Load or actual power flow whichever is higher.
• For Open Access for a part of a day, the transmission charges shall be
payable on pro-rata basis:
• Where a dedicated transmission system used for open access has been
constructed for exclusive use of an open access customer, the
transmission charges for such dedicated system shall be worked out by
transmission licensee for their respective systems and got approved by
the Commission and shall be borne entirely by such open access
customer till such time the surplus capacity is allotted and used for by
other persons or purposes.
OA charges-Scheduling & System Operation charges
• Intra-State charges for above other than Inter-State as decided
by CERC as follows:
• Long-term access and medium-term open access
– SLDC charges determined by the Commission under subsection (3) of section 32 of the Act
• Short-term open access 
– A composite operating charge @ Rs.2,000/- per day or part of
the day shall be payable by a short-term open access
customer for each transaction to the SLDC or as determined
by the Commission from time to time.
– The operating charge includes fee for scheduling and system
operation, energy accounting, fee for affecting revisions in
schedule on bonafide grounds and collection and
disbursement of charges.
OA charges-Wheeling Charges
• Wheeling Charges = (ARR – PPC – TC) /(PLSD X365) (in Rs./MWDay)
• ARR= Annual Revenue Requirement of the distribution licensee
in the concerned year
• PPC= Total Power Purchase Cost of distribution licensee in the
concerned year
• TC = Total transmission charges paid by distribution licensee
for State and Inter-State transmission system for the concerned
year
• PLSD= Total Peak load projected to be served by the concerned
distribution system in the concerned year
• Provided that Wheeling charges shall be payable on the basis of
contracted Capacity/ Scheduled Load or actual power flow
whichever is higher.
• For Access for a part of a day, the wheeling charges shall be
payable on prorata basis:
OA charges-Wheeling Charges
•
Provided further that where a dedicated distribution system used for open
access has been constructed for exclusive use of an open access customer,
the wheeling charges for such dedicated system shall be worked out by
distribution licensee for their respective systems and got approved by the
Commission and shall be borne entirely by such open access customer till
such time the surplus capacity is allotted and used for by other persons or
purposes;
•
Provided also that an open access customer connected to the STU system
shall be liable to pay the wheeling charges determined under this regulation,
if such customer was paying wheeling charges directly or indirectly before
availing open access.
•
In case an Open Access customer continues to pay the fixed charge and
such fixed charge can be attributed to wheeling/distribution network related
cost, partly or fully, SERC may provide for adjustment of such fixed charges
against the wheeling charges determined as above
OA charges-Cross Subsidy Surcharge
•
•
•
•
•
•
•
•
•
•
If open access facility is availed of by a subsidising consumer of a distribution
licensee of the State, then such consumer, in addition to transmission and/or
wheeling charges, shall pay cross subsidy surcharge determined by the
Commission.
Cross subsidy surcharge determined on Per Unit basis shall be payable, on
monthly basis, by the open access consumers based on the actual energy drawn
during the month through open access. The amount of surcharge shall be paid to
the distribution licensee of the area of supply from whom the consumer was
availing supply before seeking open access.
Cross Subsidy Surcharge formula:
S = T – [ C (1+ L / 100) + D ]
S is the surcharge
T is the Tariff payable by the relevant category of consumers;
C is the Weighted average cost of power purchase of top 5% at the margin
excluding liquid fuel based generation and renewable power
D is the Wheeling charge in per kWh basis (to be derived from the wheeling
charge in Rs./MW-Day
L is the system Losses for the applicable voltage level, expressed as a
percentage
Provided that in case the above formula gives negative value of surcharge, the
same shall be zero:
OA charges-Cross Subsidy Surcharge
•
Provided further that the Commission may fix a lower surcharge in the
situation of shortages and load shedding by the distribution licensee:
•
Provided also that such cross subsidy surcharge shall not be levied in case
distribution access is provided to a person who has established a captive
generation plant for carrying the electricity to the destination of his own use.
•
Cross subsidy surcharge so determined by the Commission shall be reduced
by 20% every year at a linear rate, taking the year in which the Commission
has allowed open access to a category of consumers as the first year.
e.g. Cross subsidy surcharge of 1 Rs./ kWh determined in the first year will be
80 Paise/kWh in second year and 60 paise/ kWh in third year and so on:
•
•
Provided that in case power supply position or the consumer load seeking
open access changes substantially, the Commission may review the Cross
Subsidy Surcharge as and when required
•
Provided further that the revised cross subsidy surcharge so determined by
the Commission in subsequent years shall be applicable only to the new
Open Access applicants.
OA charges-Additional surcharge
•
•
•
•
•
•
Additional surcharge shall become applicable only if the obligation of the
licensee in terms of power purchase commitments has been and continues to
be stranded or there is an unavoidable obligation and incidence to bear fixed
costs consequent to such a contract. However,the fixed costs related to
network assets would be recovered through wheeling charges.
The distribution licensee shall submit to the Commission on six monthly
basis, a detailed calculation statement of fixed cost which the licensee is
incurring towards his obligation to supply.
The Commission shall scrutinize the statement of calculation of fixed cost
submitted by the distribution licensee and obtain objections, if any, and
determine the amount of additional surcharge:
Provided that any additional surcharge so determined by the Commission
shall be applicable only to the new open access customers.
Additional surcharge determined on Per Unit basis shall be payable, on
monthly basis, by the open access consumers based on the actual energy
drawn during the month through open access:
Provided that such additional surcharges shall not be levied in case
distribution access is provided to a person who has established a captive
generation plant for carrying the electricity to the destination of his own use
OA charges-Standby charges
• In cases of outages of generator supplying to open access customer
under open access, standby arrangements should be provided by the
distribution licensee for a maximum period of 42 days in a year,
subject to the load shedding as is applicable to the embedded
consumer of the licensee and the licensee shall be entitled to collect
tariff under Temporary rate of charge for that category of consumer in
the prevailing rate schedule subject to the condition that such tariff
shall not exceed the highest consumer retail tariff in the prevailing rate
schedule:
• Provided that in cases where temporary rate of charge is not available
for that consumer category, the standby arrangements shall be
provided by the distribution licensee for a maximum of 42 days in a
year and on payment of fixed charges of 42 days and energy charges
for that category of consumer in the prevailing rate schedule:
• Provided further that in case of stand by arrangements sought by
continuous process industries, the licensee shall charge on the basis
of actual costs involved in arranging power:
• Provided also that open access customers would have the option to
arrange stand-by power from any other source.
OA charges-Imbalance Charges
• In case of deviation by open access consumers with load of less than
10 MW, the difference between the applicable sanctioned Open Access
load and the actual drawal shall be accounted through the Time of Day
(ToD) Meters on monthly basis and settled at the rate of the imbalance
charge as determined by the Commission (where imbalance charge
has not been determined by the Commission, UI charges as specified
by the Central Commission shall be applicable).
• In case of underdrawal as a result of non availability of the distribution
system or unscheduled load shedding, the open access consumer
shall be compensated by the distribution licensee at the average
power purchase cost of the distribution licensee.
• Deviations between the schedule and the actual injection/drawal in
respect of open access consumers with load of 10 MW and above and
the Generating Stations irrespective of the capacity, shall be settled
based on the composite accounts for imbalance transactions issued
by SLDC on a weekly cycle based on net metering in accordance with
the charges specified by the State Commission.
• Where the imbalance charges are not specified by State commission
UI charges specified by the Central Commission to be used.
OA charges-Imbalance Charges
• Payment of imbalance charges shall have a high priority and the
concerned constituents (including the licensees or the open access
customers as the case may be) shall pay the indicated amounts within
10 (ten) days of the issue of the statement, into a State imbalance pool
account operated by the SLDC.
• Recipient would then be paid out from the State imbalance pool
account, within three (3) working days.
• If payments against the above imbalance charges are delayed by more
than two days, i.e., beyond twelve (12) days from the date of issue of
statement, the defaulting party shall have to pay simple interest @
0.04% for each day of delay.
• The interest so collected shall be paid to the person who had to
receive the amount, payment of which got delayed.
• Persistent payment defaults, if any, shall be reported by the SLDC to
the Commission, for initiating remedial action.
OA charges- Reactive Energy charges
• In respect of open access consumer having a load of 10 MW or above,
the payment for the reactive energy charges by open access
consumers shall be in accordance with provisions stipulated in the
State Grid Code.
• Where the reactive energy charges are not specified by the State
Commission, charges as per provisions stipulated in the IEGC shall
be applicable
• In respect of open access consumers of load less than 10 MW,
reactive energy charges shall be calculated on Power Factor basis as
specified by the Commission.
OA charges- Limited STOA customer
• Subject to the provisions of these regulations, any consumer of the
distribution licensee having contracted load upto which open access
has been allowed by the Commission and connected through an
independent feeder emanating from a grid sub-station of licensee or
industrial feeder provided that all the consumers on such industrial
feeder, may apply for Limited short-term open access and having
simultaneous schedule of drawal under such open access.
• Subject to the provisions of these regulations, in case of any Limited
short-term open access consumer, the minimum schedule for drawl of
power through open access in each time slot during the day shall not
be less than maximum demand recorded during previous month or
80% of its contracted load whichever is higher.
• “Time slot” means each 30 minutes time block which is the minimum
period for which the Time-of-day meter is capable of integrating the
maximum demand.
OA charges- Limited STOA customer
• Limited short-term open access consumers shall be exempted from
payment of transmission charges, wheeling charges, cross subsidy
surcharge and additional surcharge.
• However, they shall continue to pay other charges namely energy
charge, demand/fixed charge, minimum consumption guarantee etc.,
applicable to them as per the rate schedule in the tariff order:
• Provided that energy charges shall be payable as per balance
energy/consumption calculated over & above the contracted load X
No. of Hrs of OA availed
• Limited short-term open access consumers shall also be liable to pay
composite operating charges @ Rs.2,000/- per day or part of the day
for each transaction to the SLDC or as determined by the Commission
from time to time.
• Inter-State charges if applicable additionally payable
• Special conditions for Imbalance settlement
• Nodal agency  SLDC
State OA charges- Sample calculations for Transmission charges
only
State
West
Bengal
Methodology of calculation of LT & ST transmission LT & ST Transmission charge calculations
charges
LT customer = [TSC/ Av_CAP]/12 [Rs/MW/Month]
WBSETCL(F.Y.2010-11)
Revenue Recoverable through Tariff Rs.
ST customer = 0.25 X [TSC/ Av_CAP] / 365 67284.35 Lakhs
[Rs./MW/day]
Average System Demand on the basis of average
of the daily peak
i)Up to 6 hours in a day in one block:: 1/4 of above
4205.42 MW
ii)>6 hours and up to 12 hours in a day in one block:: ½ LT charges 
of above
Rs. 67284.35 lakh / (4205.42x12) = Rs.
iii)>12 hours and up to 24 hours in a day in one block = 1,33,329/MW/month
above ST charges
Rate for short-term users
[Rates as mentioned above will not be applicable to Rs. (1,33,329 x 0.25)/30 =
those short-term customers who have their drawal 1111.08Rs./MW/day
point within the State of West Bengal and injection RLDCS  Rs.80/MWH as not declared in Rs./MWH
point outside the State]
format
State OA charges- Sample calculations for Transmission charges
only
State
Orissa
Methodology of calculation of LT & ST transmission LT & ST Transmission charge calculations
charges
LT rate =[ Net approved transmission cost(NATC) /
OPTCL(F.Y 2011-12)
Average demand in the State(MW)]/365
Net Annual Revenue Requirement (Rs. cr.)
572.50
ST_RATE = 0.25 x LT rate (Rs./MW/day)
Power flow (equivalent of 22877 MU) in MW
2612MW
i)Up to 6 hours in a day in one block:: 1/4 of above
Long term Open Access Charges in terms of
ii)>6 hours and up to 12 hours in a day in one block:: ½ Rs./MW/Day 6005 rounded to 6000/- OR
of above
Rs.250/MWh
iii)>12 hours and up to 24 hours in a day in one block = Short term Open Access Charges in terms of
above ST charges
Rs./MW/Day 1500 OR Rs.62.5/MWh
25% of the charges collected from the short-term
customers shall be retained by the transmission RLDCs initially Rs.62.5 MWH as declared by
licensee and the balance 75% shall be adjusted ORIERC
towards reduction in the transmission charges payable Rs.80/MWH taken In view of revocation of above
by the long-term customers.
& declaration in Rs/MW/day format
QUESTIONS?
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