Transcript Procedure for Scheduling of Collective Transactions

Open Access
DEFINITION OF “OPEN ACCESS” IN THE
ELECTRICITY ACT, 2003
“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”
INTRODUCTION
• Open Access is necessary for utilization of short time
surpluses.
• Open Access will also create options for distribution
companies to buy power.
• Open Access will
provide means to the
traders/buyers/sellers.
• Non- discriminatory / Transparent Process
• Freedom to buy/sell power
• Efficient Market Mechanism to address supply /
demand mismatches
• Encourage investment in Transmission
Legal Framework
SECTION 38: (CTU Function)
• CTU to provide open access to Licensee or
Generating Company on payment of transmission
charge
• Any consumer when open access is provided by
State Commission on payment of surcharge in
addition to transmission charges.
• Surcharge shall be for meeting cross subsidy, and
to be progressively reduced and eliminated.
• Surcharge not payable in case of captive
generation and Distribution Companies.
• CTU can not engage in generation and trading
Legal Framework
Sections 39, 40 and 41
• Similar provisions for STU and Transmission
Licensee.
• STU can not engage in trading.
• Transmission Licensee can not engage in trading
Section 42
• State Commission to provide Open Access to all
consumers who required supply more than 1 MW
in 5 years.
Agencies involved in Short-Term Open Access
Transaction
•
•
•
•
•
•
•
RLDC (s)
SLDC (s)
CTU
STU (s)
Buyer
Seller
Trader
Open Access
– CERC Regulations, 2008
CERC Open Access Regulations, 2008
3. Subject to any other regulations specified by the
Commission, the long-term customer shall have first
priority for using the inter-State transmission system for
the designated use. These Regulations shall apply for
utilization of surplus capacity available thereafter on the
inter-State transmission system by virtue of(a) Inherent design margins;
(b) Margins available due to variations in power flows;
(c ) Margins available due to in-built spare transmission
capacity created to cater to future load growth or
generation addition:
Evolution of Open Access Regulations
OA Regulations 2004
STOA
LTOA
OA Regulations 2008
STOAbilateral
STOAcollective
OA Regulations 2010
Connectivity
LTOA
MTOA
Duration of STOA,MTOA and LTA
12 years-25 years
3 months-3 years
3 months
STOA
MTOA
LTOA
CERC Open Access Regulations, 2008
• Effective 01.04.2008
• Amended in 01.05.2009
• Regulations cover only Short-term Open Access
• Transactions categorized as Bilateral and Collective
(through PX)
• Earlier Products of Short-Term retained under
Bilateral Transactions
• Nodal Agency
– Bilateral : Drawing RLDC
– Collective : NLDC
Open Access in ISTS:
CERC OA Regulations 2008
• Both Buyers and Sellers of Collective transactions
to bear transmission charges and absorb
transmission losses
• Inter-Regional links -No Separate treatment.
• Emphasis on “Scheduling” rather than
“Reservation”
• SLDC consent mandated along with application
• In case of Congestion – e-Bidding without Price Cap
• Exit Option provided with payment of up to 2 days
open access charges.
• Moving towards empowerment of SLDCs
Open Access in ISTS
CERC OA Regulations 2008
• Products –
Short term Access
- Advance
- First Come First Serve
- Day ahead
- Contingency
Long term Access
Provisions relating to Long Term as per the Open Access
Regulations, 2004 to continue, till CERC further notifies.
Comparison of CERC Regulations on Short-Term Open Access (Regulation
2004, Amendment 2005 and Regulations 2008)
S.
No.
Old Regulations
(06.05.2004 to 31.03.2005)
Amended Regulations
(w.e.f. 01.04.2005 to
31.03.2008)
1.
Open Access Duration
Open Access Duration
- Up to One year
- Up to Three Months
maximum
max.
- single application possible
- single application
possible
2.
ST Rate
- in Rs/MW/Day
- Min. Charges for one
day
Regulations, 2008
(w.e.f. 01.04.2008)
Open Access Duration
Bilateral
-Up to 3 months
- separate application for
each month
Collective:
- Only Day ahead
ST Rate
Rate
- in Rs./MW/Day
-in Rs/MWh
-Charges as per continuous - Based on Scheduled
block of up to 6 hours,
Energy rather than
12 hours, and more
reservation of transmission
than 12 hours
capacity
Comparison of CERC Regulations on Short-Term Open Access (Regulation
2004, Amendment 2005 and Regulations 2008)
S.
No.
Old Regulations
(06.05.2004 to 31.03.2005)
Amended Regulations
(w.e.f. 01.04.2005 to
31.03.2008)
Regulations, 2008
(w.e.f. 01.04.2008)
3.
Transmission Charges
a. Intra Regional – 25% of
Long Term Charges
b. Inter Regional – 25% of
Long Term Charges
Transmission Charges
a. Intra Regional – 25% of
Long Term Charges
b. Inter-Regional - 50% of
Long Term Charges
Transmission Charges: Bilateral:
- Rs.30/MWh – intra- regional
- Rs.60/MWh – Between adjacent regions
- Rs90/MWh – Wheeling through one or more
region
Collective Transactions (Px):
-Rs. 30/MWh for each point of injection and
drawal
4.
Operating Charges
a. Application fee – Rs. 5000/b. Scheduling Charges
– Rs. 3000/day for each
RLDC involved
– Rs. 3000/day for each SLDC
involved
c. Handling &Service Charges
- 2% of total charges
Operating Charges
a. Application fee – Rs.
5000/b. Scheduling Charges
– Rs. 3000/day for each
RLDC involved
– Rs. 1000/day for each
RLDC involved
c. Handling & Service
Charges
– Nil
Operating Charges
Bilateral:
a. Application fee – Rs. 5000/b. Scheduling Charges
– Rs. 2000/day for each RLDC and SLDC
involved
c. Handling & Service Charges -Nil
Collective Transactions:
a. Application fee – Rs. 5000/b. Scheduling Charges
– Rs. 5000/day to NLDC for each State
involved ; -NLDC to Share with RLDCs
Comparison of CERC Regulations on Short-Term Open Access (Regulation
2004, Amendment 2005 and Regulations 2008)
S.
No.
Old Regulations
(06.05.2004 to 31.03.2005)
Amended Regulations
(w.e.f. 01.04.2005 to
31.03.2008)
Regulations, 2008
(w.e.f. 01.04.2008)
5.
OA Application types :
- Advance
OA Application types :
- Advance
- FCFS
- Day Ahead
- Same Day
OA Application types :
- Advance
- FCFS
- Day Ahead
- Contingency
6.
Time Frame
Time Frame :
20th of the month
Time Frame :
-10days
STOA RATES
2004, 2005 & 2009
649.86
516.03
NORTHERN
REGION
233.32
447.73
WR-NR
ER-NR
919.71
NORTHEASTERN
REGION
WESTERN
REGION
270.49
433.09
339.98
359.68
ER-WR
SR-ER
SR-WR
881.49
1128.39
SOUTHERN
REGION
STOA CASE
967.58
1795.11
700.91
614.15
313.93
434.42
EASTERN
REGION
NER-ER
460.41
859.05
1462.44
2433.39
Transmission Charges: Bilateral:
Rs.80/MWh – intra- regional
Rs.160/MWh – Between adjacent regions
Rs240/MWh – Wheeling through one or more region
Collective Transactions (Px):
-Rs. 100/MWh for each point of injection and drawal
Short Term charges
2004
2005
2008
2009
As per
Regional
charges in
Rs/MW/day
As per
Regional
charges in
Rs/MW/day
In blocks
Rs/MWh
Rs/MWh
30
60
90
30 PoC
80
160
240
100 PoC
Scheduling Charges Rs/Day)
RLDCs
SLDCs
3000
3000
3000
1000
2000
2000
2000
2000
Handling Charges
2%
NIL
CTU charges
intra- regional
Adjacent region
Wheeling in 1 or more Region
Collective
NIL
STU charges as decided by SERCs
IR link charges done away with
CTU charges moved from Region specific charges to generic ones
Transmission charges changed from Rs/MW/day Rs/MW/block of dayRs/MWh
Power Exchange transactions necessitated Point of Connection charges
Procedure for Scheduling of
Open Access (Bilateral Transaction)
SUBMISSION OF APPLICATION
• Nodal Agency
– RLDC where point of drawal is situated
• Application Contents
– Details -Buyer /Seller /Point of injection/point of
drawal/Contracted power at supplier interface/date/time
period
• Application Fee (Rs. 5000/-)
– Along with application
– With in 3 working days ( for same day or next day
transaction)
• Endorsement
– Concerned SLDCs
CONCURRENCE OF GRID OPERATORS
• Available Transfer Capability
• SLDC – ( congestion in intra-State TS)
– concurrence -along with Application
• RLDC - ( congestion in Regional TS)
– To be obtained by Nodal RLDCs
• Refusals /Curtailed Concurrence
– Reasons to be mentioned in writing
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 M0 – for transaction in M1, M2, M3)
– Cut-off time : 17:30 Hrs. of last day (Day 0)
– Request for concurrence (RLDC) – by 12:00 Hr. next day (Day 1)
– Concurrence - by 20:00 Hrs (Day 1)
– Congestion Information to Applicant – next day 12:00 Hrs (Day 2)
– Revised Request – next day 11:00 HRs. (Day3)
– E-bidding – in case of Congestion (next day) (Day 4)
– Acceptance/Refusal of Scheduling Request – (Day 5)
Time Line for Advance, FCFS, DA and
Contingency Scheduling
D-3
D-2
D-1 D0
1500hrs 1.5hrs
Deadline for
submission of
DA Applications
for transactions
on D0
Deadline for
submission of
Contingency
Applications for
transactions
during D0
M0
M1
M0
Last Day for
submission of
Applications for
transactions in
M1, M2, M3
5
M2
M3
5
Processing time
for RLDCs
e-Bidding Procedure
• Invitation of Bids
– period of congestion
– RTS/IR corridor – overstressed
• 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
Part Acceptance – Price as quoted by the bidder
Full Acceptance – Price quoted by last bidder getting full acceptance
“FIRST-COME-FIRST-SERVED” BASIS
• Scope
– Current Month
– Next Month ( during last 10 days of end of current month)
•
•
•
•
•
Separate Application for each month
To be submitted 4 days prior to date of Scheduling
Processing time – 3 days
Processed on FCFS basis
Application Received in a day to be processed
together – same priority
• Application Received after 17:30 Hrs. - next day
• Congestion Management – pro-rata
DAY-AHEAD BILATERAL TRANSACTION
•
•
•
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 having been received together
for processing and shall have same priority.
Processing only after processing of the
Collective Transactions of the Power Exchange
(s).
Congestion Management – Pro-rata
SCHEDULING OF BILATERAL
TRANSACTION IN A CONTINGENCY
•
•
•
•
Only Buying Utility 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 – scheduling from 6th
time block
Congestion Management – Pro-rata
INCORPORATION IN DAILY SCHEDULES
•
RLDCs to incorporate in Daily Schedules of the
Regional Entities
Average energy losses -estimated on weekly basis
•
–
–
•
RLDCs – ISTS
SLDC – intra-State TS
resolution of 0.01 MW at each State/interRegional boundaries.
ramp-up
•
–
•
at the time of commencement of the transaction
ramp-down
–
at the time of termination of the transaction
Start
Is the
applicatio
n Day
ahead /
Contingen
cy
Is the
application
(Day ahead /
Same Day) or
(AR/FCFS)
Is the
applicatio
n is
Advanced
Booking
A
R
D
A
Co
n.
FC
Transaction
Processing
Payment
Calculation
Payment
Disbursement
& refund
STOP
DA
Is Application
Received before
15:00 hrs
Yes
Collect All Applications
received till 15:00 hrs with
time stamp and details.
Submit all applications for
Consent from concerned
SLDC
Check for the final consent
from other SLDC.
No
Contingency
DA
Is Application
Received before
15:00 hrs
Yes
Collect All Applications
received till 15:00 hrs with
time stamp and details.
Submit all applications for
Consent from concerned
SLDC
Check for the final consent
from other SLDC.
No
Contingency
AR
Is application
received in time
in respect of 1st ,
2nd & 3rd month
Is application
within stipulated
time
Yes
Applications are submitted
for Consent from RLDC
Check for Consent
Process as FCFS
application for next month
for applications made for
the 1st month
Reject
Application
No
Is
requested
capacity
available?
Applicants are informed about
the congestion and allowed to
reduce their requirements/reroute
Yes
Is
requested
capacity
now
available?
Distribute the Capacity
according to the current
request.
No
Yes
Bids are invited for congested
element
Distribute the
Capacity following
the bidding rules.
Stop
Process application if
applicant wants to
surrender or Revise the
schedule. Consider
curtailment by SLDC
Bi
d
Applications have to bid for the congested
element in the multiple of Rs.10/MWh and
minimum bid is Rs.10/MWh
Ranking from highest bidding
to lowest bidding
Allot the highest
bidder first (in asc
order). In case of
same bid by 2 or
more parties,
allocate on pro rata
basis between
those
Is Margin
available?
If more than one
person gets the
full requested
power
Yes
Lowest price among those
bidding is considered for all who
got full requested power
Stop
No
Calculate the
Actual
FC
Is Margin
Available
?
Receive the Applications
for FCFS
No
Send a Negative Report
to the Applicant
Yes
Applications are sent for
Consent from ERLDC
Application is Approved
and approval is updated.
Get Consent from
other ERLDC
Is consent
positive ?
In Case of Curtailment,
Applicant is timely
intimated
No
Schedule the Capacity as
Requested on FCFS basis
Send a negative
report to the client
Yes
Stop
In case of revision in
Schedule reprocess the
application.
REVISON OF SCHEDULE
• Only in case of “Advance Scheduling” or
“First-Cum-First Served basis”
• minimum five (2) days notice (5days in 2008 Regn)
• Transmission Charges and Operating
Charges for 2 days (5days in 2008 Regn)
• Margin Available – could be utilized for
scheduling of other Open Access
Transactions
Example:
• Say an Applicant has been scheduled for 10 days from 21st day of a
month to 30th day of a month for 100 MW on round the clock basis (i.e.
for 2400 MWh per day). If this Applicant, on or before 15th day of that
month, submits request for revision of schedule to 50MW on round the
clock basis (i.e. 1200 MWh per day), the revised schedule will get
implemented from the beginning of the transactions (i.e. 21st day of the
month). The Applicant shall pay the Transmission Charges for 2400
MWh per day for the period from 21st to 25th day of the month. Whereas
for the period from 26th day to 30th day of the month, Transmission
Charges shall be payable for 1200MWh per day.
•
However, if the Applicant requests for such revision on
17th day of the month, his request will be implemented from 23rd day of
the month. He shall pay Transmission charges for 2400 MWh per day for
5 days i.e. from 23rd to 27th day of the month and for the remaining
period he shall pay the Transmission Charges based on 1200MWh per
day.
CURTAILMENT IN CASE OF
TRANSMISSION CONSTRAINTS
• Allocation/Reallocation of ISGS power
• Transmission constraint or to maintain grid
security
• curtailed in the manner, which in the opinion of
RLDC, would relieve transmission constraints/
enhance grid security
• Open Access Bilateral Transactions would
generally be curtailed first followed by the
Collective Transactions
• Rerouting allowed without curtailment
• Pro-rata refund of Transmission Charges
COMMERCIAL CONDITIONS
• All Payment related to Open Access ST Charges
– by Applicant to the Nodal RLDC
– within three working days from the date of acceptance
• Energy charges to be settled among the parties
• Losses adjusted in kind
• Application Fees (as per Para 7 of Regulation)
– non-refundable fee of Rupees five thousand (Rs.5000/-) only
• Transmission charges (Para 16 of Regulation)
– Intra-region (Rs.80/MWh)
– Adjacent Region (Rs. 160/MWh)
– Wheeling (Rs.240/MWh)
– STU charges – as specified by respective SERCs or Rs. 80/MWh
• Operating charges (as per Para 17 of Regulation)
– Rs. 2000/- per day each RLDCs/SLDCs involved
DEFAULT IN PAYMENT OF OPEN
ACCESS CHARGES
•
Nodal RLDC, at its discretion
–
–
–
•
may not schedule the transaction or
may cancel the scheduling of already scheduled
transaction or
may not entertain any Application of such Applicant in
future until such time the default is cured.
simple interest at the rate of 0.04 % for each day
of default from the Due Date of Payment
Cheque has been dishonored
•
–
No cheque payment - next three (3) months
DISBURSAL OF PAYMENT
• Disburse the Open Access Charges
– 10th day of the next month
• Transmission Charges and Operating Charges –
for State System
– Concerned STUs/SLDCs
• For ISTS
– 25% to be retained by CTU
– 75% to be directly paid to Long Term customers
• Refund due to curtailment
– 15th day of the next month
• Reconcile the Open Access Charges
GENERAL CONDITIONS
• “One- Time” information as per enclosed format
• For embedded utilities :
– UI rate 105% for overdrawl /under injection
– & 95% for over injection under drawl
– Reactive charges as per SERC
• 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
STOA – SUCCESS STORY
• Developed in consultation with all stakeholders
• Applications Processed (Since Beginning)
20,000 No.
>
• Volume (Approved Energy) (Since Beginning) > 90BUs
• Applications Approved > 95 %
– Refusal/Non-consent by SLDCs > 3 - 4 %
– Refusal due to system constraints < 0.5 %
STOA – SUCCESS STORY
• Robust Financial Settlement System
• Dispute free implementation
• Logistics/infrastructure -In-house
• Confidence Building & Dissemination of
knowledge
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 State Load Despatch Centre
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 underdrawals or over generation) of UI rate at the periphery of
regional entity.
STOA CHARGES COLLECTED BY RLDCS
DURING THE YEAR 2007-08
All figures in Crores of Rs.
RLDC
PROCESSING
FEE
RLDC
Operating Charges
CTU
Charges
NRLDC
2.20
9.43
149.75
SRLDC
0.50
1.78
44.33
ERLDC
0.09
0.48
3.90
NERLDC
0.05
0.39
2.70
WRLDC
1.95
4.82
61.16
TOTAL
4.80
16.90
261.85
Issues
• Invoking of Sec 11 by state Govt. barring
export from IPPs in the state
• URS of ISGS under STOA (as per CERC
order 11-01-10)
– Among the beneficiaries
– Across the regions
– Revision if original beneficiary recalls
Revision of STOA under forced outage of Injecting
unit>100MW (as per IEGC cl. 6.4.19)
– Intimate SLDC/RLDC reg. reduced availability,
estimated restoration time, transaction wise revision
19. Notwithstanding anything contained in Regulation 6.5(18), in case of forced outage
of a unit for a Short Term bilateral transaction, where a generator of capacity of
100 MW and above is seller, the generator shall immediately intimate the same
along with the requisition for revision of schedule and estimated time of restoration
of the unit, to SLDC/RLDC as the case may be. With the objective of not affecting
the existing contracts, the revision of schedule shall be with the consent of the buyer
till 31.07.2010. Thereafter , consent of the buyer shall not be a pre-requisite for
such revision of schedule. The schedule of the generator and the buyer shall be
revised, accordingly. The revised schedules shall become effective from the 4th time
block, counting the time block in which the forced outage is declared to be the first
one.. The RLDC shall inform the revised schedule to the seller and the buyer. The
original schedule shall become effective from the estimated time of restoration of
the unit. However the transmission charges as per original schedule shall continue
to be paid for two days.
ST charges under OA
• Under going changes frequently
• In CERC Regulations on “Sharing
Transmission Charge and Losses” w.e.f
01.01.11, ST charges as per Point of
Connection charge philosophy ie. as per the
Zonal charges for Injection and Drawl of
the concerned Injecting and drawing utility
• Losses be adjusted in kind as per the
applicable Zonal losses