Competive Power
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Transcript of Competive Power
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COMPARATIVE OVERVIEW OF ENERGY COST IN SHORT
TERM OPEN ACCESS MARKET AMONG ADVANCE, FIRST-CUM-FIRST-SERVE, DAY AHEAD AND CONTINGENCIES
TRANSACTIONS AND COLLECTIVE TRANSACTION
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ORGANIZATION
Power System Operation Corporation Limited
Eastern Regional Load Despatch Centre
Kolkata
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Presentation Outline
Open Access Concept
Power Trading Concepts
Short Term Open Access
Bilateral Transaction
Collective Transaction
Project
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DEFINITION OF OPEN ACCESS IN THEELECTRICITY ACT, 2003
. Open Access means the non-discriminatoryprovision for the use of transmission lines ordistribution system or associated facilities withsuch lines or system by any licensee, orconsumer, or a person engaged in generation in
accordance with the regulations specified by theAppropriate Commission.
Section 2(47) of Electricity Act 2003
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INTRODUCTION
Open Access is necessary for utilization of short timesurpluses.
Efficient Market Mechanism to address supply / demandmismatches
Encourage investment in Transmission
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Agencies involved in Short-Term Open Access
Transaction
RLDC (s)
SLDC (s)
CTU STU (s)
Buyer
Seller
Trader
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Categorization of
Open Access customers The transmission customers divided into three categories:
(a) Long-term Access customers (LTA)- Thecustomers availing or intending to avail access to theinter-state transmission system for a period of 12 years to25 years shall be the long-term customers.
(b) Medium-term Open Access customers (MTOA)-The persons availing or intending to avail open access tothe inter-state transmission system for a period of 3months to 3 years shall be the medium-term customers.
(c) Short-term Open Access customers (STOA) -The persons availing or intending to avail open access tothe inter-state transmission system upto a period of 3months but 1 month at a time.
STOA are categorized into two different ways: Bilateral Transaction
Collective Transaction
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Criteria for - Transmission Access
Long Term Open access: In accordance with the Transmission Planning criteria as per
IEGC
Short Term Open access
Inherent design margins Margins available due to variation in power flow schedule
Margins available due to in-built spare transmission capacitycreated to cater future load growth
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NODAL AGENCY
For Long-Term and Medium Term Customers Central Transmission Utility (CTU), if its system is used
For Short-Term Customers RLDC of the Region in which the drawal point is located.
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SHORT TERM OPEN ACCESS
CERC REGULATIONS, 2008
Regulation, 2008 w.e.f 01.04.08
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CERC/Regulations on Open Access
Final Order issued : 30.01.2004
Final Regulations issued : 30.01.2004
Gazette Notification : 06.02.2004
CERCs Order effective from 06.02.2004
Amendments on 21-02-2005
Revised Regulations for Open Access in ISTS issued on 25.1.2008.
These revisions effective from 1.4.2008.
Amendments on 20.05.2009
Amendments on 28.10.2009
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Highlights of CERC Regulations 2008 on Short-Term Open Accessand Amendment thereof
S. No. Regulations, 2009 and Amendments thereof
1. Transmission Charges: Bilateral:
- Injection POC charges- Drawal POC charges
Collective Transactions():
- Injection POC charges
- Drawal POC charges
2. Retention by CTU- 25% to be retained by CTU
- Balance adjusted with long term payment.
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3. RLDC Charges :
Bilateral:
a. Application feeRs. 5000/-
b. Scheduling Charges
Rs. 2000/day for each RLDC involved
c. Regional/State Transmission Charges
Collective Transactions:
a. Application feeRs. 5000/-
b. Scheduling ChargesRs. 5000/day to NLDC for each State involved
- NLDC retains Rs. 2000 and to Share Rs. 500 with each RLDCs.
c. Regional/State Transmission Charges
4. Open Access Duration
Bilateral
Advance (upto 3 months separate application for each month)
FCFS
Day Ahead
Contingency
Collective:
Only Day ahead
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Case Study
Short-Term Open Access transaction
by Captive Power Plants
A typical example:
From : SAIL Durgapur Steel Plant (DVC),To : SAIL Bhilai Steel Plant (CSEB)
Quantum : 20 MW
Source : SAIL
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Network Involved
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Transmission Losses
Injection POC
Loss 3.2 %
Withdrawal POC
Loss 5.5 %
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PROCEDURE FOR SCHEDULING OF
OPEN ACCESS (BILATERAL
TRANSACTION)
Advance, FCFS, Day-Ahead & Contingency
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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 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)
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Time Line for Advance Scheduling
M0 M1 M2 M3
510 5
Last Day for
submission of
Applications for
transactions in
M1, M2, M3
Processing timefor RLDCs
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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
Applicants getting less quantum than applied shall pay the charges quoted byhim.
Applicant getting equal quantum of what sought by him shall pay the chargesquoted by the last Applicant getting approval of its full scheduling request.
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e-Bidding ProcedureCase Study:
Margin available in a corridor = 200 MW
Bid Submitted by the applicants are as followed:
Sl.
No.
Applicant
NameBid Amount (MW)
Bid Amount
(Rs.)
1 A 100 200
2 B 50 1503 C 100 100
4 D 50 100
Sl.
No.
Applicant
Name Bid cleared (MW)
Bid cleared price
(Rs.)
1 A 100 150
2 B 50 150
3 C 33.33 100
4 D 16.67 100
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FIRST-COME-FIRST-SERVED BASIS Scope
FCFS shall be considered only when transactions arecommencing & terminating in the same calendar month.
Separate Application for each month To be submitted 4 days prior to date ofScheduling
Processing time 3 days Processed on FCFS basisApplication Received upto 17:30 Hrs in a day tobe processed together same priority
Application Received after 17:30 Hrs. - consideras received on next day Congestion Management pro-rata (proportional)
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DAY-AHEAD BILATERAL TRANSACTION
Applications received within 3 days prior to the day ofScheduling and up to 15:00 Hrs. of the day immediatelypreceding the day of scheduling shall be treated as samepriority.
Processing will be done only after processing of theCollective Transactions of the Power Exchange (s).
Congestion Management Pro-rata (proportional)
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SCHEDULING OF BILATERAL
TRANSACTION IN A CONTINGENCY
Applications received within 15:00 Hrs. to 18:00
Hrs. of the immediately preceding the day of
scheduling shall be treated as same priority.
Congestion ManagementPro-rata (proportional)
Applications received after 18:00 Hrs. of the
immediately preceding the day of scheduling to 6th
time block prior to scheduling shall be considered.
Congestion ManagementFirst Cum First Serve basis
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DOWNWARD REVISON OF SCHEDULE In case of Advance Scheduling or First-Cum-First Served
basis
Minimum two (2) clear days notice.
Transmission Charges and Operating Charges for 2 days.
In case of all the accepted bilateral subject to the following
condition as per I.E.G.C. clause 6.5.19 The injecting utility is a generator of unit capacity of 100 MW and
above.
At the time of applying for STOA the said unit of the generating
station was mentioned in the application.
The expected time of synchronization is mentioned in the
application of revision.
Margin Available could be utilized for scheduling of other
Open Access Transactions
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Example: For 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 theclock basis (i.e. for 2400 MWh per day). If this Applicant, on or before
18th 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 TransmissionCharges for 2400 MWh per day for the period from 21st to 22nd day
of the month. Whereas for the period from 23rd 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 20th day ofthe month, his request will be implemented from 23rd day of the
month. He shall pay Transmission charges for 2400 MWh per day for
2 days i.e. from 23rd to 24th day of the month and for the
remaining period he shall pay the Transmission Charges based
on 1200MWh per day.
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CURTAILMENT IN CASE OF
TRANSMISSION CONSTRAINTS
Transmission constraint or to maintain gridsecurity
Curtailed in the manner, which in the opinion ofRLDC, would relieve transmission constraints/enhance grid security
Open Access Bilateral Transactions wouldgenerally be curtailed first followed by the
Collective Transactions Pro-rata refund of Transmission Charges
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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 Applicantin future until such time the default is cured.
Simple interest at the rate of 0.04 % for each day ofdefault from the Due Date of Payment
If cheque has been dishonored No cheque payment - next three (3) months
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DISBURSAL OF PAYMENT
Reconcile the Open Access Charges Nodal RLDC will reconcile the Open Access Charges collected during the previous
month and disburse the Transmission Charges and Operating Charges by 7 working
days from the issuance of monthly Regional Energy Accounting by the respective
Regional Power Committees.
Transmission Charges and Operating Charges for StateSystem Concerned STUs/SLDCs
For ISTS To be disbursed to CTU
Refund due to curtailment Within 15th day of the next month
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PROCEDURE FOR SCHEDULING OFOPEN ACCESS (COLLECTIVETRANSACTION)
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Agencies involved in Short-Term Open Access
Collective Transaction
Power Exchanges (IEXL & PXIL)
NLDC
RLDC (s) SLDC (s)
CTU
STU (s)
Buyer
Seller
Trader
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Collective Transactions (through PX) Nodal Agency
National Load Despatch Center
Both Buyers and Sellers of Collective transactions to beartransmission charges.
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Outline STOA- Collective
CERC Regulations on Open Access in inter-State
Transmission, 2008 and amendments thereof
Applicable for Scheduling of Open Access (Collective
Transactions) w.e.f. 01.07.2011
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Bidding procedure Time Line for submission of bid
10 a.m. to 12 a.m. of preceding day NLDC communicates the margin to PX at 11:00 hrs. During the bid hours the bid can be revised or cancelled. Volume and price of the bid submitted by market players are stored
in central order book. Matching of bids for each 15 minute time block in carried out.
Price Determination Process (Provisional)The aggregate supply and demand curves will be drawn on Price-Quantity axes. The intersection point of the two curves will give Market ClearingPrice (MCP) and Market Clearing Volume (MCV).
Successful members will be provided with clearing price and volume. After working out of provisional obligation funds available in the
settlement account of the Members shall be checked with the
Clearing Banks. In case sufficient funds are not available in the settlement account ofthe Member then his bid (s) will be deleted from further evaluationprocedure.
Requisition for capacity allocation will be sent to NLDC at 13:00 hrs.
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Bidding procedure
NLDC at 14:00 hrs. send the available margin to the PXs. Power Exchange at 14:30 hrs. will run the fresh iteration
for final MCP and MCV.
Obligations will be sent to the bank of buying members at
14:30 hrs. for settlement.At 15:00 hrs. cleared volume will be send to NLDC for
incorporation in schedules.
At 16:00 hrs. NLDC sends the cleared volume to respective
RLDCs.
At 17:30 hrs. NLDC shall confirm the accepted schedule to PX.
At 18:00 hrs. RLDC issues schedule Rev-0.
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Time Line for PX transaction
1210 14
Bid submission
by applicants
13 15 1611
NLDC
sends
the
margin
to PX
PX sends the cleared
volume of different
control area to NLDC
NLDC informs
about thecongestion in
any link
PX submits
applicationto NLDC
NLDC communicates
to all RLDC about the
cleared volume
17:30
RLDCs communicates toNLDC and NLDC
confirms the schedule to
PX
18
RLDC
issuesschedu
le Rev
0
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Congestion Management- Market Splitting
In deficit area the already cleared (provisionally) buyersbid get rejected on following criteria:
Lower price
Less volume
Time priority
Surplus
partDeficit part
ATC < Margin Cleared
Congest
ed link
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area 1
price
MWh
area 2
price
MWh
(exchange volume)area surplus
atMCP
(exchange volume)area deficit
atMCP
neededcapacity
neededcapacity
availablecapacity
availablecapacity
availablecapacity
availablecapacity
price forarea 1
price forarea 2
Systemprice
Congestion Management : Market Splitting
SCHEDULE OF PARTICULAR ENTITY (BUYER/SELLER)
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SCHEDULE OF PARTICULAR ENTITY (BUYER/SELLER)
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Project
COMPARATIVE OVERVIEW OF ENERGY COST IN
SHORT TERM OPEN ACCESS MARKET AMONG
ADVANCE, FIRST-CUM-FIRST-SERVE, DAY
AHEAD AND CONTINGENCIES TRANSACTIONS
AND COLLECTIVE TRANSACTION FOR BUYER
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What have we done ??
Select all the major power purchase utility across the
country (25 states).
Take the power transaction of the power purchase utility in
Open Access for both bilateral and collective transaction.
Categorize the power purchase cost for both bilateral and
collective transaction across all the states taken.
Evaluate and analyse the data and plot the graph
accordingly.
Analyse the graph.
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Purchase Price of various STOA Bilateral
and Collective transaction for the state of
Assam
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Weighted Average Purchase Price of
Various STOA Bilateral Transaction for the
state ofAssam
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Inferences
From the above two charts it is clear that, state Assam
should reduce power purchase from FCFS and Advance as
the price is maximum in that category and should go for
either DAM market or power exchange. So that their
average cost of purchase reduces.
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