CERC Sharing Regulations
The CERC has issued the Sharing of Inter-State Transmission Charges and Losses regulations dated 15th June 2010 and new regulations dated 4th May 2020. The primary purpose of these regulations is to develop and implement a national transmission tariff framework which is sensitive to distance, direction and quantum of flow of electric energy.
Sharing of Inter-State Transmission Charges and Losses Regulations, 2010
Resolution By
CERC
Notification No. and date
L-1/44/2010-CERC Dated 15th June 2010
Objectives
To develop and implement a national transmission tariff framework sensitive to distance, direction and quantum of flow
Regulations called as
Central Electricity Regulatory Commission (Sharing of Inter State Transmission Charges and Losses) Regulations, 2010
Effective Control period
These regulations shall come into force from 1.1.2011 and shall remain in force for a period of 5 years from the date of commencement
[clause 1.3]
[clause 1.3]
Applicability
Yearly Transmission Charges, revenue requirement on account of foreign exchange rate variation, changes in interest rates etc. as approved by the Commission and Losses shall be shared amongst the following categories of Designated ISTS Customers who use the ISTS:
a. Power Stations / Generating Stations that are regional entities
b. State Electricity Boards / State Transmission Utilities connected with ISTS
c. Any bulk consumer directly connected with the ISTS
d. Any designated entity representing a physically connected entity
[clause 3]
a. Power Stations / Generating Stations that are regional entities
b. State Electricity Boards / State Transmission Utilities connected with ISTS
c. Any bulk consumer directly connected with the ISTS
d. Any designated entity representing a physically connected entity
[clause 3]
Principles of sharing transmission charges
1. Based on the Yearly Transmission Charges of ISTS Transmission Licensees and transmission losses in the ISTS network, the Implementing Agency shall compute the
Point of Connection charges and Loss Allocation Factors for all DICs
2. The sharing of ISTS transmission charges between Designated ISTS Customers shall be computed for an Application Period and shall be determined in advance and shall
be subject to periodic true-up
3. The mechanism for sharing of ISTS charges shall ensure that:-
i. The Yearly Transmission Charge of the ISTS Licensees are fully and exactly recovered
ii. Any adjustment towards Yearly Transmission Charge on account of change in commissioning schedule of elements of the power system and change in factors approved by the Commission shall be fully and exactly recovered
4. The Point of Connection transmission charges shall be computed in terms of Rupees per MegaWatt per month. The POC transmission charges for short term open access transactions shall be in terms of Rupees per MegaWatt per hour and shall be applicable for the duration of short term open access approved by the RLDC/NLDC
5. The schedule of electricity of Designated ISTS Customers shall be adjusted to account for energy losses in the transmission system as estimated by the RLDC and the SLDC concerned
6. The applicable transmission losses for the ISTS shall be declared in advance and shall not be revised retrospectively
[CHAPTER 3]
Point of Connection charges and Loss Allocation Factors for all DICs
2. The sharing of ISTS transmission charges between Designated ISTS Customers shall be computed for an Application Period and shall be determined in advance and shall
be subject to periodic true-up
3. The mechanism for sharing of ISTS charges shall ensure that:-
i. The Yearly Transmission Charge of the ISTS Licensees are fully and exactly recovered
ii. Any adjustment towards Yearly Transmission Charge on account of change in commissioning schedule of elements of the power system and change in factors approved by the Commission shall be fully and exactly recovered
4. The Point of Connection transmission charges shall be computed in terms of Rupees per MegaWatt per month. The POC transmission charges for short term open access transactions shall be in terms of Rupees per MegaWatt per hour and shall be applicable for the duration of short term open access approved by the RLDC/NLDC
5. The schedule of electricity of Designated ISTS Customers shall be adjusted to account for energy losses in the transmission system as estimated by the RLDC and the SLDC concerned
6. The applicable transmission losses for the ISTS shall be declared in advance and shall not be revised retrospectively
[CHAPTER 3]
Processes of sharing transmission charges and losses
1. The Implementing Agency shall collect the Basic Network data pertaining to the network elements and the generation and load at the various network nodes from all concerned entities
2. Nodal generation information shall be based on the forecast provided by Designated ISTS Customers
3. Forecast demand data shall be submitted by the Designated ISTS Customers for each node or a group of nodes in a zone, identified by Implementing Agency
4. Approved Basic Network, nodal generation and nodal demand data shall form the base for computation of Marginal Participation factors and loss allocation factors
5. Overall charges to be shared among nodes shall be computed based on the Yearly Transmission Charge apportioned to each of the lines of the ISTS Licensees
6. In order to give proper signals towards transmission charges based on distance and direction, the transmission charge per circuit kilometre shall have to be made uniform for each voltage level and conductor configuration
7. The loss allocation factors shall be computed for each season using the Hybrid method. The loss allocation factors shall be applied to the total losses
8. The losses shall be attributed to the Designated ISTS Customers by suitably adjusting their scheduled MWs
9. The Implementing Agency shall aggregate the charges for geographically and electrically contiguous nodes on the ISTS to create zones, in order to arrive at uniform zonal charge in Rs/MW/month
10. No transmission charges for the use of ISTS network shall be charged to solar based generation.
11. No transmission losses for the use of ISTS network shall be attributed to solar based generation.
[CHAPTER 4 clause 7]
2. Nodal generation information shall be based on the forecast provided by Designated ISTS Customers
3. Forecast demand data shall be submitted by the Designated ISTS Customers for each node or a group of nodes in a zone, identified by Implementing Agency
4. Approved Basic Network, nodal generation and nodal demand data shall form the base for computation of Marginal Participation factors and loss allocation factors
5. Overall charges to be shared among nodes shall be computed based on the Yearly Transmission Charge apportioned to each of the lines of the ISTS Licensees
6. In order to give proper signals towards transmission charges based on distance and direction, the transmission charge per circuit kilometre shall have to be made uniform for each voltage level and conductor configuration
7. The loss allocation factors shall be computed for each season using the Hybrid method. The loss allocation factors shall be applied to the total losses
8. The losses shall be attributed to the Designated ISTS Customers by suitably adjusting their scheduled MWs
9. The Implementing Agency shall aggregate the charges for geographically and electrically contiguous nodes on the ISTS to create zones, in order to arrive at uniform zonal charge in Rs/MW/month
10. No transmission charges for the use of ISTS network shall be charged to solar based generation.
11. No transmission losses for the use of ISTS network shall be attributed to solar based generation.
[CHAPTER 4 clause 7]
Specific transmission charges applicable for a Designated ISTS Customer
1. Based on the Yearly Transmission Charges determined by the Commission, the Implementing Agency shall determine the charges applicable to each Designated
ISTS Customer for use of the ISTS to the extent of the Approved Withdrawal or Approved Injection in the ISTS
2. In the case of the Approved Withdrawal or Approved Injection not materialising either partly or fully for any reason whatsoever, the Designated ISTS Customer shall
be obliged to pay the transmission charges allocated
3. For Long Term customers availing supplies from inter-state generating stations, the charges payable by such generators for such Long Term supply shall be billed directly
to the respective Long Term customers based on their share of capacity in such generating stations
[clause 8]
ISTS Customer for use of the ISTS to the extent of the Approved Withdrawal or Approved Injection in the ISTS
2. In the case of the Approved Withdrawal or Approved Injection not materialising either partly or fully for any reason whatsoever, the Designated ISTS Customer shall
be obliged to pay the transmission charges allocated
3. For Long Term customers availing supplies from inter-state generating stations, the charges payable by such generators for such Long Term supply shall be billed directly
to the respective Long Term customers based on their share of capacity in such generating stations
[clause 8]
Accounting of charges
1. Monthly Transmission Accounts applicable for various Designated ISTS Customers in each region shall be prepared by the respective RPC on the basis of:
a. Approved Withdrawal / Injection (MW) for peak and other than peak hours
b. Zonal Point of Connection charge (Rs / MW / month)
c. Approved Additional Medium Term Withdrawal / Injection (MW) to be received from RLDC / NLDC
d. Processed meter reading from all SEMs for computation of deviations from the sum of the Approved withdrawal /Injection, Approved Additional Medium Term Withdrawal/Injection and Approved Short Term Withdrawal/Injection (MW) and time blocks for which such deviation is recorded
[clause 10]
a. Approved Withdrawal / Injection (MW) for peak and other than peak hours
b. Zonal Point of Connection charge (Rs / MW / month)
c. Approved Additional Medium Term Withdrawal / Injection (MW) to be received from RLDC / NLDC
d. Processed meter reading from all SEMs for computation of deviations from the sum of the Approved withdrawal /Injection, Approved Additional Medium Term Withdrawal/Injection and Approved Short Term Withdrawal/Injection (MW) and time blocks for which such deviation is recorded
[clause 10]
Billing
1. The CTU shall be responsible for raising the transmission bills, collection and disbursement of transmission charges to ISTS transmission licensees.
2. The billing for ISTS charges for all Designated ISTS Customers shall be on the basis of Rs./MW/Month
3. The first part of the bill shall recover charges for use of the transmission assets of the ISTS Licensees based on the Point of Connection methodology.
4. The second part of the bill shall recover charges for Additional Approved Medium Term Open Access
5. The third part of the bill shall be used to adjust any variations in interest rates, FERV, rescheduling of commissioning of transmission assets, etc
6. Deviations shall be billed separately by the CTU
7. This part of the bill shall be raised on first working day of September and first working day of March for the previous six months.
8. Revenue from Approved Additional Medium term open access that was not considered in the Approved Injection/Approved Withdrawal shall be used for truing up the YTC
[clause 11]
2. The billing for ISTS charges for all Designated ISTS Customers shall be on the basis of Rs./MW/Month
3. The first part of the bill shall recover charges for use of the transmission assets of the ISTS Licensees based on the Point of Connection methodology.
4. The second part of the bill shall recover charges for Additional Approved Medium Term Open Access
5. The third part of the bill shall be used to adjust any variations in interest rates, FERV, rescheduling of commissioning of transmission assets, etc
6. Deviations shall be billed separately by the CTU
7. This part of the bill shall be raised on first working day of September and first working day of March for the previous six months.
8. Revenue from Approved Additional Medium term open access that was not considered in the Approved Injection/Approved Withdrawal shall be used for truing up the YTC
[clause 11]
Transmission Service Agreement (TSA)
The Designated ISTS Customers and the CTU shall enter into new transmission services agreement or modify the existing Bulk Power Transmission Agreements to incorporate the new tariff and related conditions
[clause 13]
[clause 13]
Corrigendum/ Amendment, if any
a. dated 24/11/2011
b. dated 28/03/2012
c. dated 01/04/2015
d. dated 03/07/2015
e. dated 14/12/2017
f. dated 27/03/2019
g. dated 04/05/2020
b. dated 28/03/2012
c. dated 01/04/2015
d. dated 03/07/2015
e. dated 14/12/2017
f. dated 27/03/2019
g. dated 04/05/2020
CERC ISTS Regulations, 2010 (1st Amendment)
Resolution By
CERC
Notification No. and date
L-1/44/2010-CERC Dated 24st November, 2011
Regulations called as
Central Electricity Regulatory Commission (Sharing of inter-State Transmission Charges and Losses)(First Amendment) Regulations, 2011.
Effective Control period
These regulations shall come into force from the date of publication in the Official Gazette.
Applicability
Amendment in Regulation 3 of the Principal Regulations
1. In clause b, the scope of regulation extended to State Electricity Boards/State Transmission Utilities connected with ISTS or designated agency in the State.
1. In clause b, the scope of regulation extended to State Electricity Boards/State Transmission Utilities connected with ISTS or designated agency in the State.
Processes of sharing transmission charges and losses
Amendment to Regulation 7 of Principal Regulations
1. Sub clause 1 (l) :The total Yearly Transmission Charges (YTC) of their transmission assets are to be recovered through the PoC mechanism in the application period along with circuit kilometers at each voltage level and for each conductor configuration. Further, YTC shall be revised on a six monthly basis.
2. Sub-clause 1 (m) shall be deleted.
3. A new provisions are is added under sub-clause 1(o)
[page 3]
1. Sub clause 1 (l) :The total Yearly Transmission Charges (YTC) of their transmission assets are to be recovered through the PoC mechanism in the application period along with circuit kilometers at each voltage level and for each conductor configuration. Further, YTC shall be revised on a six monthly basis.
2. Sub-clause 1 (m) shall be deleted.
3. A new provisions are is added under sub-clause 1(o)
[page 3]
Billing
Amendment in Regulation 11 of Principal Regulations.
1. In clause 4, the first part of the bill shall recover charges for use of the transmission assets of the ISTS Licensees based on the Point of Connection methodology. Further, the list of transmission assets along with the approved transmission charges shall be enclosed with the first part of the bill. Also, The charges for the quantum of long term access to a target region shall comprise the Injection POC charges and lowest of the Demand POC charges among all the DICs in the target region
2. In clause 5, the second part of the bill shall recover charges for Additional Approved Medium Term Open Access. The revenue collected from the approved additional MTOA customers which has not been considered in the Approved Injection/Approved Withdrawal, shall be reimbursed to the DICs having Long-term Access
3. Clause 8 shall be deleted
1. In clause 4, the first part of the bill shall recover charges for use of the transmission assets of the ISTS Licensees based on the Point of Connection methodology. Further, the list of transmission assets along with the approved transmission charges shall be enclosed with the first part of the bill. Also, The charges for the quantum of long term access to a target region shall comprise the Injection POC charges and lowest of the Demand POC charges among all the DICs in the target region
2. In clause 5, the second part of the bill shall recover charges for Additional Approved Medium Term Open Access. The revenue collected from the approved additional MTOA customers which has not been considered in the Approved Injection/Approved Withdrawal, shall be reimbursed to the DICs having Long-term Access
3. Clause 8 shall be deleted
CERC ISTS Regulations, 2010(2nd Amendment)
Resolution By
CERC
Notification No. and date
L-1/44/2010-CERC Dated: 28th March 2012
Regulations called as
Central Electricity Regulatory Commission (Sharing of inter-State Transmission Charges and Losses) (Second Amendment) Regulations, 2012.
Effective Control period
These regulations shall come into force with effect from the date of their publication in the Official Gazette.
Processes of sharing transmission charges and losses
Amendment to Regulation 7 of Principal Regulations
1. In sub-clause 1(i) (1), The Basic Network studies shall be validated by validation Committee and presented for approval to the Commission three months before the revision of the YTC.
2. In sub-clause (l) of clause (1), Overall charges to be shared among nodes shall be computed based on the Yearly Transmission Charge apportioned to each of the lines of the ISTS Licensees. There shall be three slab rates for injection and demand PoC charges for the year upto 2013-14, after which the same shall be rationalized in the year 2014-15 based on a review by the Commission.
3. In sub-clause (t) of Clause (1), The Implementing Agency shall aggregate POC charges for the geographically and electrically contiguous nodes on the ISTS to create zones within the geographical boundary of the State, to arrive at uniform zonal rate in Rs/MW/ month.
4. In Para (iv) under sub-clause 1(t), Any inter-State Generating Station directly connected to the 400 kV inter- State Transmission System shall be treated as a separate zone and shall not be clubbed with other generator nodes in the area, for the purpose of calculation of PoC injection rate
1. In sub-clause 1(i) (1), The Basic Network studies shall be validated by validation Committee and presented for approval to the Commission three months before the revision of the YTC.
2. In sub-clause (l) of clause (1), Overall charges to be shared among nodes shall be computed based on the Yearly Transmission Charge apportioned to each of the lines of the ISTS Licensees. There shall be three slab rates for injection and demand PoC charges for the year upto 2013-14, after which the same shall be rationalized in the year 2014-15 based on a review by the Commission.
3. In sub-clause (t) of Clause (1), The Implementing Agency shall aggregate POC charges for the geographically and electrically contiguous nodes on the ISTS to create zones within the geographical boundary of the State, to arrive at uniform zonal rate in Rs/MW/ month.
4. In Para (iv) under sub-clause 1(t), Any inter-State Generating Station directly connected to the 400 kV inter- State Transmission System shall be treated as a separate zone and shall not be clubbed with other generator nodes in the area, for the purpose of calculation of PoC injection rate
Accounting of charges
Amendment to Regulation 10 of Principal Regulations
1. In clause (1), RPCs shall issue Regional Transmission Accounts on the next working day of the issue of Regional Energy Account for the previous month.
1. In clause (1), RPCs shall issue Regional Transmission Accounts on the next working day of the issue of Regional Energy Account for the previous month.
Billing
Amendment to Regulation 11 of Principal Regulations
1. The word ‘charge’ appearing in the computation formulae shall be substituted with the word ‘rates’
1. The word ‘charge’ appearing in the computation formulae shall be substituted with the word ‘rates’
CERC ISTS Regulations, 2010 (4th Amendment)
Resolution By
CERC
Notification No. and date
L-1/44/2010/CERC Dated 3rd July, 2015
Regulations called as
The Central Electricity Regulatory Commission (Sharing of inter-State Transmission Charges and Losses) (Fourth Amendment) Regulations, 2015.
Effective Control period
These regulations shall come into force with effect from 1st June, 2015.
Processes of sharing transmission charges and losses
Amendment to Regulation 7 of the Principal Regulations
1. After, sub-clause 1 (v) following subclause are added:
(w) No transmission charges for the use of ISTS network shall be charged to incremental gas based generation from e-bid RLNG for the years 2015-16 and 2016-17.
(x) No transmission losses for the use of ISTS network shall be attributed to incremental gas based generation from e-bid RLNG for the year 2015-16 and 2016-17.
1. After, sub-clause 1 (v) following subclause are added:
(w) No transmission charges for the use of ISTS network shall be charged to incremental gas based generation from e-bid RLNG for the years 2015-16 and 2016-17.
(x) No transmission losses for the use of ISTS network shall be attributed to incremental gas based generation from e-bid RLNG for the year 2015-16 and 2016-17.
CERC ISTS Regulations, 2010 (6th Amendment)
Resolution By
CERC
Notification No. and date
L-1/44/2010-CERC Dated 27nd March, 2019
Regulations called as
The Central Electricity Regulatory Commission (Sharing of inter-State Transmission Charges and Losses) (Sixth Amendment),Regulations, 2019
Effective Control period
These Regulations shall come into effect from 13.2.2018.
Processes of sharing transmission charges and losses
Amendment to Regulation 7 of the Principal Regulations:
1. In sub-clause 1(y), the date “31.12.2019” shall be substituted with the date “12.2.2018”
2. In sub-clause 1(z) , the date “31.12.2019” shall be substituted with the date “12.2.2018”
3. A new sub-clause 1(aa) shall be added, saying that no transmission charges and losses for the use of ISTS network shall be payable for the generation based on solar and wind power resources for a period of 25 years from the date of commercial operation of such generation projects with conditions applied.
1. In sub-clause 1(y), the date “31.12.2019” shall be substituted with the date “12.2.2018”
2. In sub-clause 1(z) , the date “31.12.2019” shall be substituted with the date “12.2.2018”
3. A new sub-clause 1(aa) shall be added, saying that no transmission charges and losses for the use of ISTS network shall be payable for the generation based on solar and wind power resources for a period of 25 years from the date of commercial operation of such generation projects with conditions applied.
CERC ISTS Regulations, 2010 (5th Amendment)
Resolution By
CERC
Notification No. and date
L-1/44/2010-CERC Dated 14th December, 2017
Regulations called as
The Central Electricity Regulatory Commission (Sharing of Inter State Transmission Charges and Losses) (Fifth Amendment) Regulations, 2017.
Effective Control period
These regulations shall come into force from the date of publication of notification in the Gazette of India except in case of sub-clauses (y) and (z) of Clause (1) of Regulation 7 which shall come into effect from 1.7.2017 and 30.9.2016 respectively.
Billing
Amendment to Regulation 11 of the Principal Regulations:
1. In Clause 6, the third part of the bill shall be used to adjust any variations in interest rates, FERV, rescheduling of commissioning of transmission assets, etc. Further, deviations shall be billed separately by the CTU and this part of the bill shall be raised on first working day of September, December, March and June for the previous PoC pplication period.
2. Addition of new clause 10 in place of clause 9, which defines now provisions under the offset for Short term open access for a DIC paying charges under long term access.
1. In Clause 6, the third part of the bill shall be used to adjust any variations in interest rates, FERV, rescheduling of commissioning of transmission assets, etc. Further, deviations shall be billed separately by the CTU and this part of the bill shall be raised on first working day of September, December, March and June for the previous PoC pplication period.
2. Addition of new clause 10 in place of clause 9, which defines now provisions under the offset for Short term open access for a DIC paying charges under long term access.
Processes of sharing transmission charges and losses
Amendment to Regulation 7 of the Principal Regulations:
1. After, sub-clause 1 (v) following subclause are added:
1.1. Subclause (y), No transmission charges and losses for the use of ISTS network shall be payable for the capacity of the generation projects based on solar resources for a period of 25 years from the date of commercial operation with applied conditions.
1.2 Subclause (z), No transmission charges and losses for the use of ISTS network shall be payable for the generation based on wind power resources for a period of 25 years from the date of commercial operation with applied conditions.
1. After, sub-clause 1 (v) following subclause are added:
1.1. Subclause (y), No transmission charges and losses for the use of ISTS network shall be payable for the capacity of the generation projects based on solar resources for a period of 25 years from the date of commercial operation with applied conditions.
1.2 Subclause (z), No transmission charges and losses for the use of ISTS network shall be payable for the generation based on wind power resources for a period of 25 years from the date of commercial operation with applied conditions.
Specific transmission charges applicable for a Designated ISTS Customer
Amendment to Regulation 8 of the Principal Regulations:
1. A new Clause (7) shall be added after Clause (6), DIC with LTA to target region whose POC rate has not been determined for the quarter, shall be billed at Average PoC rate of the target region.
1. A new Clause (7) shall be added after Clause (6), DIC with LTA to target region whose POC rate has not been determined for the quarter, shall be billed at Average PoC rate of the target region.
CERC ISTS Regulations, 2010 (3rd Amendment)
Resolution By
CERC
Notification No. and date
1/44/2010-CERC Dated 1st of April, 2015
Regulations called as
The Central Electricity Regulatory Commission (Sharing of Inter State Transmission Charges and Losses) (Third Amendment) Regulations, 2015
Effective Control period
These regulations shall come into force with effect from 1st of May, 2015.
Applicability
Amendment to Regulation 3 of the Principal Regulations
1. In Sub clause (a), ISTS regulation are now applied to Generating Stations
1.1. which are regional entities as defined in the Indian Electricity Grid Code (IEGC)
1.2. are having LTA or MTOA to ISTS and are connected either to STU or ISTS or both
1. In Sub clause (a), ISTS regulation are now applied to Generating Stations
1.1. which are regional entities as defined in the Indian Electricity Grid Code (IEGC)
1.2. are having LTA or MTOA to ISTS and are connected either to STU or ISTS or both
Processes of sharing transmission charges and losses
Amendments to Regulation 7 of the Principal Regulations:
1. In Sub-clause 1(d), Nodal generation information shall be based on the forecast data provided by the DICs. Such forecast data shall incorporate estimate of total maximum injection into the grid, considering the injection under long term access, LTOA, STOA during an Application Period.
2. In sub-clause 1 (i), There shall be nine slab rates for PoC charges. The slab rates shall be computed by the Implementing Agency based on the methodology provided in the regulation. The slab rates shall be approved by the Commission for each Application Period. The number of slabs shall be reviewed by the Commission after two years."
3. In sub-clause 1(n), for the computation of transmission charges at each node as per Hybrid Methodology, commission's approved tariff for inter-State lines are considered for computation of PoC chages and for non-ISTS lines the asset-wise tariff as approved by the respective State Commission are considered.
4. In sub-clause 1(o), the participation factors, and the Point of Connection nodal and zonal rates thus determined, shall be computed for each Application Period.
5. In sub-clause 1(q), the recovery of the YTC of the ISTS network shall be based on the PoC charge, Reliability Support Charge and HVDC Charge. Further, 10% of the YTCs shall be recovered through Reliability Support Charge methodology which can be ammended.
6. In sub-clause 1(s), the losses shall be apportioned to the DICs by suitably adjusting their scheduled MWs. There shall be 9 slabs for calculation of transmission losses which shall be expressed in terms of percentage.
7. In Para (iv) of sub-clause 1(t), any inter-State Generating Station connected to the 400 kV inter-State Transmission System shall be treated as a separate zone and shall not be clubbed with other generator nodes in the area, for the purpose of calculation of PoC injection rate.
8. In sub-clause 1(u), no transmission charges for the use of ISTS network shall be charged to solar based generation and the useful life of the projects commissioned during the period 1.7.2014 to 30.6.2017.
9. In sub-clause 1(v), no transmission losses for the use of ISTS network shall be attributed to solar based generation and the useful life of the projects commissioned during the period 1.7.2014 to 30.6.2017.
1. In Sub-clause 1(d), Nodal generation information shall be based on the forecast data provided by the DICs. Such forecast data shall incorporate estimate of total maximum injection into the grid, considering the injection under long term access, LTOA, STOA during an Application Period.
2. In sub-clause 1 (i), There shall be nine slab rates for PoC charges. The slab rates shall be computed by the Implementing Agency based on the methodology provided in the regulation. The slab rates shall be approved by the Commission for each Application Period. The number of slabs shall be reviewed by the Commission after two years."
3. In sub-clause 1(n), for the computation of transmission charges at each node as per Hybrid Methodology, commission's approved tariff for inter-State lines are considered for computation of PoC chages and for non-ISTS lines the asset-wise tariff as approved by the respective State Commission are considered.
4. In sub-clause 1(o), the participation factors, and the Point of Connection nodal and zonal rates thus determined, shall be computed for each Application Period.
5. In sub-clause 1(q), the recovery of the YTC of the ISTS network shall be based on the PoC charge, Reliability Support Charge and HVDC Charge. Further, 10% of the YTCs shall be recovered through Reliability Support Charge methodology which can be ammended.
6. In sub-clause 1(s), the losses shall be apportioned to the DICs by suitably adjusting their scheduled MWs. There shall be 9 slabs for calculation of transmission losses which shall be expressed in terms of percentage.
7. In Para (iv) of sub-clause 1(t), any inter-State Generating Station connected to the 400 kV inter-State Transmission System shall be treated as a separate zone and shall not be clubbed with other generator nodes in the area, for the purpose of calculation of PoC injection rate.
8. In sub-clause 1(u), no transmission charges for the use of ISTS network shall be charged to solar based generation and the useful life of the projects commissioned during the period 1.7.2014 to 30.6.2017.
9. In sub-clause 1(v), no transmission losses for the use of ISTS network shall be attributed to solar based generation and the useful life of the projects commissioned during the period 1.7.2014 to 30.6.2017.
Specific transmission charges applicable for a Designated ISTS Customer
Amendment to Regulation 8 of the Principal Regulations
1. In clause 5 , the Designated ISTS Customer shall be obliged to pay the transmission charges allocated:
1.1. In case the commissioning of a generating station or unit is delayed
1.2. In case the operationalization of LTA is contingent and only some of the transmission lines have been declared commercial.
1.3. In case the construction of dedicated transmission line has been taken up by the CTU or the transmission licensee for generator.
1.4 In case a generating station draws start-up power or injects infirm power before commencement of LTA.
2. In Clause 6, for Long Term Transmission Customers availing power supply from inter-State generating stations, the charges attributable to such generation for long term supply shall be calculated directly at drawal nodes.
1. In clause 5 , the Designated ISTS Customer shall be obliged to pay the transmission charges allocated:
1.1. In case the commissioning of a generating station or unit is delayed
1.2. In case the operationalization of LTA is contingent and only some of the transmission lines have been declared commercial.
1.3. In case the construction of dedicated transmission line has been taken up by the CTU or the transmission licensee for generator.
1.4 In case a generating station draws start-up power or injects infirm power before commencement of LTA.
2. In Clause 6, for Long Term Transmission Customers availing power supply from inter-State generating stations, the charges attributable to such generation for long term supply shall be calculated directly at drawal nodes.
Billing
Amendment to Regulation 11 of the Principal Regulations:
1. In clause 4, the first part of the bill shall recover charges based on the POC methodology which is computed as POC transmission charge towards LTA/MTOA, Reliability Support Charge and HVDC charge.
2. In clause 9, A generator, who has been granted Long-term Access to a target region, shall be required to pay PoC injection charge for the approved injection for the remaining quantum after offsetting the charges for Medium-term Open Access, and Short-term open access.
1. In clause 4, the first part of the bill shall recover charges based on the POC methodology which is computed as POC transmission charge towards LTA/MTOA, Reliability Support Charge and HVDC charge.
2. In clause 9, A generator, who has been granted Long-term Access to a target region, shall be required to pay PoC injection charge for the approved injection for the remaining quantum after offsetting the charges for Medium-term Open Access, and Short-term open access.