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PUBLISHED BY AUTHORITY
24 AASHWIN 1947 (S)
No. 472
RANCHI WEDNESDAY 15TH October, 2025
NOTIFICATION
15th October, 2025
Notification No. 113 --In exercise of powers conferred by sub-section (1) of Section 181 and clauses (zd), (ze) and (zf) of sub-section (2) of Section 181, read with Sections 61, 62, and 86, of the Electricity Act, 2003 (36 of 2003) and all other powers enabling it in that behalf, the Jharkhand State Electricity Regulatory Commission, hereby makes the following Regulations. The Regulation is guided by the principles contained in Sections 61 and 62 of the Act to encourage competition, efficiency, economical use of resources, good performance and optimum investments by the Generating Company within the State of Jharkhand and for determination of Multi-Year Tariff to be recovered by the Generating Company for the prudent expenses incurred for generating electricity.
Provided that where a generating station or Unit thereof, has been declared under commercial operation before the date of commencement of these Regulations and whose tariff has not been finally determined by the Commission till that date, tariff in respect of such generating station or Unit thereof for the period ending March 31, 2026 shall be determined in accordance with the JSERC (Terms and Conditions for Determination of Generation Tariff) Regulations, 2020, JSERC (Terms and Conditions for Determination of Generation Tariff) Regulations, 2015, JSERC (Terms and Conditions for Determination of Generation Tariff) Regulations, 2010, JSERC (Terms and Conditions of Tariff determination, Multi-Year Tariff Framework) Regulations, 2007, and JSERC (Terms and Conditions for determination of Thermal Generation Tariff) Regulations, 2004, read with all the amendments thereto, as the case may be.
Explanation:-For all purposes including the review matters pertaining to the period till FY 2025-26, i.e., up to March 31, 2026, the issue related to determination shall be governed by JSERC (Terms and Conditions for Determination of Generation Tariff) Regulations, 2020, JSERC (Terms and Conditions for Determination of Generation Tariff) Regulations, 2015, JSERC (Terms and Conditions for Determination of Generation Tariff) Regulations, 2010, JSERC (Terms and Conditions of Tariff determination, Multi Year Tariff Framework) Regulations, 2007, JSERC (Terms and Conditions for determination of Thermal Generation Tariff) Regulations, 2004 including amendment thereto, as may be applicable.
In these Regulations, unless the context otherwise requires: -
(i) The Balance Sheet, prepared in accordance with the form contained in The Companies Act, 2013 and its predecessors, as applicable;
(ii) Cash Flow Statement, prepared in accordance with the applicable Accounting Standards of the Institute of Chartered Accountants of India;
(iii) Cost Accounting Records prescribed by the Central Government under Section 148 of the Companies Act, 2013 and its predecessors, as applicable.
(iv) Notes on accounts thereto, and such other supporting statements and information forming part of financial statements or as the Commission may direct from time to time.
(v) Profit and Loss Account, complying with the requirements contained in The Companies Act, 2013 and its predecessors, as applicable;
Provided that auxiliary energy consumption shall not include energy consumed for supply of power to housing colony and other facilities at the generating station and the power consumed for construction works at the generating station and integrated coal mine:
Provided further that auxiliary energy consumption for compliance of revised emission standards, sewage treatment plant and external coal handling plant (jetty and associated infrastructure shall be considered separately;
Provided that where the Distribution Licensee is procuring power through a Trading Licensee, the arrangement shall be secured by the Trading Licensee through back-to-back Power Purchase Agreement and Power Sale Agreement;
‘Block’ in relation to a combined cycle thermal generating station includes combustion turbine-generator, associated waste heat recovery boiler, connected steam turbine-generator and auxiliaries;
‘Capital cost’ means the capital cost as determined in accordance with Section A13 of these Regulations;
‘Carrying Cost’ means the interest amount on gap/ surplus and it will be SBI MCLR rate plus 200 basis points;
‘CERC’ or ‘Central Commission’ means the Central Electricity Regulatory Commission;
‘Change in Law’ means occurrence of any of the following events: -
Provided that the cut-off date may be extended by the Commission if it is proved on the basis of documentary evidence that the capitalization could not be made within the cut-off date for reasons beyond the control of the Generating Company;
of, and is not due to an act of omission or commission of that party and which, by the exercise of reasonable care and diligence, could not have been prevented; and, without limiting the generality of the foregoing, shall include the following events or circumstances:
'Fuel Supply Agreement' means the agreement executed between the generating company and the fuel supplier for the generation and supply of electricity to the beneficiaries;
'GCV as Received' means the GCV of coal as measured at the unloading point of the thermal generating station through collection, preparation and testing of samples from the loaded wagons, trucks, ropeways, Merry-Go-Round (MGR), belt conveyors and ships in accordance with the IS 436 (Part-1/ Section 1)- 1964;
Provided that the measurement of coal shall be carried out through sampling by third party to be appointed by the generating companies in accordance with the guidelines, if any, issued by Central/State Government:
Provided further that samples of coal shall be collected either manually or through hydraulic augur or through any other method considered suitable keeping in view the safety of personnel and equipment:
Provided also that the generating companies may adopt any advance technology for collection, preparation and testing of samples for measurement of GCV in a fair and transparent manner;
transportation cost (overseas or inland or both) and handling cost, charges for third party sampling and applicable statutory charges;
‘Licence’ means a Licence granted under Section 14 of the Act;
‘Maximum Continuous Rating’ or ‘MCR’ in relation to a Unit of the thermal generating station means the maximum continuous output at the generator terminals, guaranteed by the manufacturer at rated parameters, and in relation to a block of a combined cycle thermal generating station means the maximum continuous output at the generator terminals, guaranteed by the manufacturer with water/steam injection (if applicable) and corrected to 50 Hz grid frequency and specified site conditions;
‘Multi-year tariff (MYT)’ framework means a regulatory system where tariffs are set for a specific period, typically three to five years, instead of being determined year-to-year;
‘New Project’ shall mean the generating station or unit thereof achieving its commercial operation on or after April 01, 2026;
‘Non-Tariff Income’ means net income relating to the regulated business other than from Tariff, including but not limited to profit derived from sale of scrap, rent of land or buildings, income from investments, miscellaneous receipts, etc.;
‘Normative Annual Plant Availability Factor’ or ‘NAPAF’ in relation to a generating station means the availability factor specified in Clause 16.1 and Clause 16.3 of these Regulations for thermal generating station and in Clause 18.2 and Clause 18.7 of these Regulations for hydro generating station;
‘Normative Annual Plant Load Factor’ or ‘NAPLF’ in relation to a generating station means the Plant Load Factor specified in Clause 16.1 and Clause 16.3 of these Regulations for thermal generating station;
‘Operation and Maintenance Expenses’ or ‘O&M expenses’ means the expenditure incurred for operation and maintenance of the project, or part thereof, and includes the expenditure on manpower, repairs and maintenance, spares, consumables, insurance and overheads, and fuel other than used for generation of electricity;
‘Original Project Cost’ means the capital expenditure incurred by the Generating Company, within the original scope of the project up to the cut-off date as admitted by the Commission;
‘Plant Availability Factor’ or ‘(PAF)’ in relation to a generating station for any period means the average of the daily declared capacities (DCs) for all the days during that period expressed as a percentage of the installed capacity in MW reduced by the normative auxiliary energy consumption;
‘Plant Load Factor’ or ‘(PLF)’ in relation to thermal generating station or Unit for a given period means the total sent out energy corresponding to scheduled generation during the period, expressed as a percentage of sent out energy corresponding to installed capacity in that period and shall be computed in accordance with the following formula:
$$PLF (%) = 100 \times \frac{\sum_{i=1}^N SG_i}{{N \times IC \times (1 - Aux_n)}} %$$
Where,
IC=Installed Capacity of the generating station or Unit in MW;
SGi=Scheduled Generation in MW for the ith time block in such period;
N=Number of time blocks during the period;
Auxn=Normative Auxiliary Energy Consumption as a percentage of gross energy generation;
‘Prudence Check’ means scrutiny of reasonableness of any cost or expenditure incurred or proposed to be incurred in accordance with these Regulations by the Generating Company;
‘Pumped Storage Hydro Generating Station’ means a hydro generating station, which generates power through energy stored in the form of water energy, pumped from a lower elevation reservoir to a higher elevation reservoir;
‘Quarter’ shall mean the period of three months commencing on the first day of April, July, October and January of each financial year in case of existing project, and
in case of a new project, in respect of the first quarter, from the date of commercial operation to the last day of June, September, December or March, as the case may be;
‘Run-of-river generating station’ means a hydro generating station, which does not have upstream pondage;
‘Run-of-river generating station with pondage’ means a hydro generating station with sufficient pondage for meeting the diurnal variation of power demand;
‘Scheduled Commercial Operation Date or SCOD’ shall mean the date(s) of commercial operation of a generating station or generating Unit or block thereof or as indicated in the Investment Approval or as agreed in Power Purchase Agreement, whichever is earlier;
‘Scheduled Energy’ means the quantum of energy scheduled by the State Load Despatch Centre to be injected into the grid by a generating station over a day;
‘Scheduled Generation’ or ‘SG’ at any time or for any period or time-block means schedule of generation in MW or MWh ex-bus, given by the State Load Despatch Centre;
‘Small Gas Turbine Generating Station’ means and includes open cycle gas turbine or combined cycle generating stations with gas turbines in the capacity range of 50 MW or below;
‘State’ means the Jharkhand State;
‘State Load Despatch Centre’ or ‘SLDC’ means the centre established by the State Government for purposes of exercising the powers and discharging the functions under Section 31 of the Act;
‘Statutory Charges’ comprises taxes, cess, duties, royalties and other charges levied through Acts of the Parliament or State Legislatures or by Indian Government Instrumentality under relevant statutes;
‘Storage type generating station’ means a hydro generating station associated with large storage capacity to enable variation of generation of electricity according to demand;
‘Tariff’ shall mean the schedule of charges for generation and bulk supply of electricity together with terms and conditions applicable thereof;
‘Tariff Period’ shall mean the period from April 01, 2026 and up to March 31, 2031 for which Tariff is determined by the Commission under these Regulations;
‘Thermal Generating Station’ shall mean a generating station or a unit thereof that generates electricity using fossil fuels such as coal, lignite, gas, liquid fuel or combination of these as its primary source of energy or co-firing of biomass with coal;
‘Trial Run and Trial Operation’ Trial Run in relation to generating station or Unit thereof shall mean the successful running of the generating station or Unit thereof at maximum continuous rating or installed capacity for continuous period of 72 hours in case of Unit of a thermal generating station or Unit thereof and 12 hours in case of a Unit of a hydro generating station or Unit thereof:
Provided that where the beneficiaries have been tied up for purchasing power from the generating station, the trial run shall commence after seven days’ notice by the Generating Company to the beneficiaries and concerned RLDC or SLDC, as the case may be:
Provided further that the short interruptions, for a cumulative duration of 4 hours, shall be permissible, with corresponding increase in the duration of the test. Cumulative interruptions of more than 4 hours shall call for repeat of trial operations or trial run:
Provided also that the partial loading may be allowed with the condition that average load during the duration of the trial run shall not be less than Maximum Continuous Rating or the Installed Capacity or the Name Plate excluding period of interruption and partial loading but including the corresponding extended period:
Provided also that the Units of thermal and hydro Generating Stations shall also demonstrate capability to raise load up to 105% or 110% of its Maximum Continuous Rating or the Installed Capacity or the Name Plate as the case may be;
‘Unit’ in relation to a thermal generating station other than combined cycle thermal generating station means steam generator, turbine-generator and auxiliaries, or in relation to a combined cycle thermal generating station, means turbine-generator and auxiliaries; and in relation to a hydro generating station means turbine-generator and its auxiliaries;
‘Unloading Point’ shall mean the point within the premises of the coal or lignite based thermal generating station where the coal or lignite is unloaded from the rake or truck or any other mode of transport;
‘Useful life’ in relation to a Unit of a generating station from the date of commercial operation shall mean the following, namely: -
Provided that the extension of life of the projects beyond the completion of their useful life shall be decided by the Commission after prudence check based on the facts, details and justifications presented before the Commission by the Generating Company or suo-motu on case-to-case basis;
‘Year’ means Financial Year;
‘Zero Date’ means the date indicated in the Investment Approval for commencement of implementation of the project and where no such date has been indicated, the date of Investment Approval shall be deemed to be Zero Date;
Provided that if Power Purchase Agreement between Generating Company and the Beneficiary stipulates better norms of operation then such norms provided in the Power Purchase Agreement shall be considered for the determination of tariff.
existing loan agreements, risk associated in generating business and creditworthiness;
Business Plan shall also contain the requisite information for the preceding Control Period:
Provided that requisite information for the preceding Control Period shall include year-wise audited data on Scheme-wise capital investment, capacity enhancement plan, if any, proposed efficiency improvements and its cost benefit analysis, quality improvement measures undertaken, Employee Expenses, Repair & Maintenance Expenses and A&G Expenses along with detailed break up and any other information used for preparing projections of various performance parameters and other components during the Control Period. In case of a new generating plant, such information is required to be submitted for the period of operations up to the start of the Control Period.
6.7 The Generating Company shall file for the Commission's approval a Capital Investment Plan for the entire Control Period along with the Business Plan. The Capital Investment Plan shall be prepared scheme-wise and each scheme shall include: -
Provided that in case the capital expenditure is required for emergency work or unforeseen situation to mitigate threat to life and property and if prior intimation thereof to the Commission shall cause any irreparable loss or injury, the Generating Company may undertake such capital expenditure and submit the details for post-facto approval of the Commission along with next Tariff Petition with all relevant details.
6.11 The Commission has stipulated following performance parameters that are deemed to be controllable in nature: -
a) Normative Annual Plant Availability Factor (NAPAF);
6.12 The variation from performance targets set for the controllable parameters as specified in Clause 6.11 of these Regulations shall be subject to incentive and penalty framework, as detailed in Clause 6.13 to Clause 6.15 of these Regulations.
The financial gains by the Generating Company, on account of above controllable parameters shall be shared between the Generating Company and the beneficiaries on annual basis. The financial gains on account of parameters (a) to (c) shall be computed as per the following formula for a thermal generating station and shall be shared in the ratio of 50:50 between the generating stations and beneficiaries;
Provided that for generating stations that have signed coal linkage agreement through Shakti Scheme, sharing of gains in the ratio of 75:25 between the generating stations and beneficiaries shall be applicable due to variation in normative controllable operational parameters.
Net Gain = $(ECR_N - ECR_A) \times \text{Scheduled Generation}$ ;
Where,
ECRN: Normative Energy Charge Rate computed on the basis of norms specified for Station Heat Rate, Auxiliary Energy Consumption and Secondary Fuel Oil consumption.
ECRA: Actual Energy Charge Rate computed on the basis of actual Station Heat Rate, Auxiliary Energy Consumption and Secondary Fuel Oil Consumption for the month:
Provided that in case of hydro generating stations, the net gain on account of Actual Auxiliary Energy Consumption being less than the Normative Auxiliary Energy Consumption, shall be computed as per following formulae provided the saleable scheduled generation is more than the saleable design energy and shall be shared in the ratio of 50:50 between generating station and beneficiaries:
Net gain (Million Rupees) = [(Saleable Scheduled generation in MUs) - (Saleable Design energy on the basis of normative auxiliary energy consumption in MUs)] x [0.80 or ECR, whichever is lower]
Net gain (Million Rupees) = {Saleable Scheduled generation in MUs - [(Saleable Scheduled Generation in MUs x (100% - normative AEC in %) / (100% - actual AEC in %)]} x [0.80 or ECR, whichever is lower]
6.15 The financial gains on account of Operations and Maintenance Expenses for thermal and hydro stations shall be shared in the ratio of 50:50 between the generating stations and beneficiaries at the time of truing up. Further, the gain shall be calculated on consolidated basis for generating station having more than one unit provided the units concerned have the same beneficiary.
6.16 The Commission shall also permit pass-through of variations in performance parameters on account of Force Majeure events and due to Change in Law event(s) in the tariff, based on the submission of actual values by the Generating Company and subsequent validation and approval by the Commission.
7.1 The Generating Company shall submit the Petition for truing up for each year of the Control Period on the basis of annual Audited Accounts as per the timelines stipulated in Section A39.
Provided that no carrying cost on the duration of delay shall be allowed on unrecovered gap if the Generating Company fails to submit the Petition as per timelines stipulated in Section A39:
Provided further that any adverse financial impact on account of variation in uncontrollable items due to lapse on part of the Generating Company or its suppliers/contractors shall not be allowed in truing up.
8.1 The Generating Company shall file APR Petition, for Annual Performance Review along with details of capital expenditure, additional capitalization, sources of financing, operations and maintenance expenditure, actual loan portfolio with the interest paid, along with other components of ARR incurred/projected to be incurred for the year under review, as per timelines stipulated in Section A39 of these Regulations.
8.2 The Generating Company along with Annual Performance Review petition, shall also claim revised ARR for the following year based on the truing up and annual performance review of previous year/s.
8.3 The Scope of the Annual Performance Review shall be comparison of the approved expenses vis-à-vis revised estimates for the year/s and shall comprise the following:
a) Comparison of Performance Targets vis-a-vis revised estimates based on the latest actual data available;
8.4 The Generating Company may, as a result of additional information not previously known or available to them at the time the forecast was developed, apply for a modification in the approved forecast of ARR as part of the Annual Performance Review.
8.5 The Commission if, as a result of additional information not previously known or available to it at the time the forecast was developed, is of the view that the same may result in significant over/under recovery, either suo-motu or on an application made by any interested or affected party, modify the approved forecast of ARR for the remainder of the Control Period, as part of the Annual Performance Review.
8.6 Based on the analysis of Annual Performance Review and Truing up, the Commission may revise the ARR and Tariff for the ensuing year of the Control Period.
Provided that the common infrastructure of existing generating station shall be utilized for the expanded capacity and the benefit of new technology in the expanded capacity, as determined by the Commission, shall be extended to the existing capacity.
13.2 The capital cost for a new project shall include the following: -
a) The expenditure incurred or projected to be incurred up to the date of commercial operation of the project;
f) Adjustment of revenue due to sale of Infirm Power in excess of fuel cost prior to the date of commercial operation as specified under Clause 14.17 of these Regulations;
g) Capital expenditure on account of ash disposal and utilization including handling and transportation facility;
h) Capital expenditure incurred towards railway infrastructure and its augmentation for transportation of coal up to the receiving end of the generating station but does not include the transportation cost and any other appurtenant cost paid to the railways;
i) Capital expenditure on account of biomass handling equipment and facilities, for co-firing;
j) Capital expenditure on account of emission control system necessary to meet the revised emission standards and sewage treatment plant;
k) Expenditure on account of fulfilment of any conditions for obtaining environment clearance for the project;
l) Expenditure on account of Change in Law and Force Majeure Events; and
m) Capital cost incurred or projected to be incurred by a thermal generating station, on account of implementation of the norms under Perform, Achieve and Trade (PAT) scheme of Government of India shall be considered by the Commission subject to sharing of entire benefits accrued under the PAT scheme with the beneficiaries.
13.3 The capital cost of an existing project shall include the following: -
a) Capital cost admitted by the Commission prior to April 01, 2026 duly tried up excluding liability, if any, as on April 01, 2026;
b) Capital expenditure on account of renovation and modernisation as admitted by this Commission in accordance with these Regulations;
c) Capital expenditure on account of ash disposal and utilization including handling and transportation facility;
d) Capital expenditure incurred towards railway infrastructure and its augmentation for transportation of coal up to the receiving end of generating station but does not include the transportation cost and any other appurtenant cost paid to the railways;
e) Capital cost incurred or projected to be incurred by a thermal generating station, on account of implementation of the norms under Perform, Achieve and Trade (PAT) scheme of Government of India shall be considered by the Commission subject to sharing of entire benefits accrued under the PAT scheme with the beneficiaries.
13.4 The capital cost in case of existing or new hydro generating station shall also include:
a) Cost of approved rehabilitation and resettlement (R&R) plan of the project in conformity with National R&R Policy and R&R package as approved;
13.5 The following shall be excluded from the capital cost of the existing and new projects: -
a) The assets forming part of the project, but not in use;
b) De-capitalised assets after the date of commercial operation on account of replacement or removal on account of obsolescence or shifting from one project to another project.
13.6 The following principles shall be adopted for prudence check of capital cost of the existing or new projects:
a) In case of the thermal generating station, prudence check of capital cost shall include scrutiny of the capital expenditure, in the light of capital cost of similar projects based on past historical data, wherever available, reasonableness of financing plan, interest during construction, incidental expenditure during construction, use of efficient technology, cost over-run and time over-run, procurement of equipment and materials through competitive bidding and such other matters as may be considered appropriate by the Commission:
Provided that, while carrying out the prudence check, the Commission shall also examine whether the Generating Company, has been careful in its judgements and decisions in execution of the project;
Provided that any revenue earned during construction period up to SCOD on account of interest on deposits or advances, or any other receipts shall be taken into account for reduction in incidental expenditure during construction.
13.12 The following factors shall be considered as controllable and uncontrollable factors for deciding time over-run, cost escalation, IDC and IEDC of the project:
13.13 The “controllable factors” shall include but shall not be limited to the following: -
13.14 The “uncontrollable factors” shall include but shall not be limited to the following:
13.15 Initial spares shall be capitalised as a percentage of the Plant and Machinery cost, subject to following ceiling norms:
| a) Coal-based/lignite-fired thermal generating stations: | 4.0% |
| b) Gas Turbine/Combined Cycle thermal generating stations: | 4.0% |
| c) Hydro generating stations: | 4.0% |
Provided that:
under Jharkhand State Electricity Regulatory Commission (Terms and Conditions for Determination of Transmission Tariff) Regulations, 2025.
14.1 The additional capital expenditure in respect of a new project or an existing project incurred or projected to be incurred, on the following counts within the original Scope of Work, after the date of commercial operation and up to the cut-off date may be admitted by the Commission, subject to prudence check:
Provided that in case of any replacement/ upgradation of the assets, the additional capitalization shall be worked out after adjusting the gross fixed assets and cumulative depreciation of the assets replaced on account of de-capitalization;
Provided further that the details of work included in the original scope of work along with estimates of expenditure, undischarged liabilities and works deferred for execution shall be submitted along with the application for determination of tariff.
14.2 The additional capital expenditure incurred or projected to be incurred in respect of an existing project or a new project within the original scope of work and after the cut-off date may be admitted by the Commission, subject to prudence check on the following counts:
a) Liabilities to meet award of arbitration or for compliance of the directions or order of any statutory authority, or order or decree of any court of law;
b) Change in law or compliance of any existing law;
c) Deferred works relating to ash pond or ash handling system in the original scope of work;
d) Liability for works executed prior to the cut-off date;
e) Force Majeure events;
f) Liability for works admitted by the Commission after the cut-off date to the extent of discharge of such liabilities by actual payments; and
g) Raising of ash dyke as a part of ash disposal system.
14.3 In case of replacement/up gradation of assets deployed under the original scope of the existing project after cut-off date, the additional capitalization may be admitted by the Commission, after necessary adjustments in the gross fixed assets and the cumulative depreciation, subject to prudence check on the following grounds:
14.4 The capital expenditure, in respect of existing generating station incurred or projected to be incurred on the following counts beyond the original scope, may be admitted by the Commission, subject to prudence check:
Provided also that if any expenditure has been claimed under Renovation and Modernisation or repairs and maintenance under O&M expenses, the same shall not be claimed under this Regulation;
g) Usage of water from sewage treatment plant in thermal generating station.
14.5 In case there is additional capitalization proposed during the fag end of the project (at least 5 years before the Useful life or extended Useful life) of the plant, the Generating Company is required to submit the detail justification of its necessity during the fag year, Cost-Benefit analysis, DPR, if any and rate reasonability along with the residual life assessment report of the Project. The Commission may carry out prudence check based on the details submitted by the Generating Company, its necessity, its financial viability before approval of such additional capitalization.
14.6 In case of de-capitalisation of assets of a Generating Company, the original cost of such asset as on the date of decapitalization duly certified by its Statutory Auditor shall be deducted from the value of gross fixed asset and corresponding outstanding loan on such assets as well as equity shall be deducted from loan and the equity balances respectively. Such deductions shall be carried out in the year such de-capitalisation takes place with corresponding adjustments in cumulative depreciation and cumulative repayment of loan shall be carried out duly taking into consideration the year in which it was capitalised.
14.7 Impact of additional capitalisation within the approved scheme cost on tariff shall be considered by the Commission during the Annual Performance Review.
Provided that the Commission may consider any new scheme proposed on merits subject to prudence check as per this Tariff Regulation.
Provided that the Generating Company making the applications for renovation and modernization shall not be eligible for Special Allowance under these Regulations:
Provided further that the Generating Company intending to undertake renovation and modernization shall be required to obtain the consent of the beneficiaries for such renovation and modernization and submit the same along with the Petition.
Provided also that such option shall not be available for a generating station or Unit, which is in a depleted condition or operating under relaxed operational and performance norms.
Provided that if a Unit is in commercial operation for more than 25 years as on April 01, 2026, this allowance shall be admissible from FY 2026-27:
Provided further that if special allowance is granted by the Commission, the expenditure incurred or utilized from special allowance shall be maintained separately by the generating station and details of same shall be made available to the Commission immediately thereafter.
Provided that the Generating Company shall furnish all relevant details as sought by the Commission to carry out necessary due diligence for deciding the matter.
Provided that any revenue earned by the Generating Company from sale of infirm power after accounting for the fuel expenses shall be applied in adjusting the capital cost accordingly.
Provided that Special Allowance in lieu of Renovation & Modernization, where opted in accordance with Clause 14.11 and Clause 14.12 of these Regulations, shall be recovered separately and shall not be considered for computation of Working Capital.
15.4 Energy Charges: Energy Charges shall be derived on the basis of the landed fuel cost (LFC) of a generating station (excluding hydro) and shall consist of the following cost:
(a) Landed Fuel Cost of primary fuel;
(b) Cost of secondary fuel oil consumption; and
(c) Cost of limestone or any other reagent, as applicable:
Provided that any refund of taxes and duties along with any amount received on account of penalties from fuel supplier shall be adjusted in fuel cost:
Provided further that the supplementary energy charges, if any, on account of meeting the revised emission standards in case of a thermal generating station shall be determined separately by the Commission.
Debt-Equity ratio allowed by the Commission for determination of tariff for the period ending March 31, 2026 shall be considered;
In case of the generating station declared under commercial operation prior to April 01, 2026, but where debt-equity ratio has not been determined by the Commission for determination of tariff for the period ending March 31, 2026, the Commission shall approve the debt-equity ratio in accordance with Clause 15.7 of these Regulations.
Any expenditure incurred or projected to be incurred on or after April 01, 2026, as may be admitted by the Commission as additional capital expenditure for determination of tariff and renovation and modernisation expenditure for life extension shall be serviced in the manner as specified in Clause 15.7 of these Regulations.
Normative debt-equity ratio of 70:30 shall be considered for the purpose of determination of Tariff.
In case the actual equity employed is in excess of 30%, the amount of equity for the purpose of tariff determination shall be limited to 30%, and the balance amount shall be considered as normative loan;
In case the actual equity employed is less than 30%, the actual debt-equity ratio shall be considered;
The premium, if any raised by the Generating Company while issuing share capital and investment of internal accruals created out of free reserve, for the funding of the project, shall also be reckoned as paid-up capital for the purpose of computing return on equity, only if such premium amount and internal resources are actually utilized for meeting capital expenditure of the generating station;
The Equity invested in foreign currency shall be designated in Indian rupees on the date of each investment;
Any consumer contribution, work carried out under deposit and grant obtained for the execution of the project shall not be considered as part of the capital structure for the purpose of computation of normative debt-equity.
Note 1: Any expenditure admitted on account of committed liabilities within the original scope of work and the expenditure deferred on techno-economic grounds but falling within the original scope of work shall be serviced in the normative debt-equity ratio specified in these Regulations;
Note 2: Any expenditure on replacement of old assets or on renovation and modernization or life extension shall be considered on normative debt-equity ratio specified in these Regulations after writing off the entire book value of the original assets from the capital cost of the new asset;
Note 3: Any expenditure admitted by the Commission for determination of tariff on account of new works not in the original scope of work shall be serviced in the normative debt-equity ratio specified in these Regulations.
The return on equity shall be computed on post-tax basis at the base rate of 15.00% for thermal generating stations, and run of the river hydro generating station, and at the base rate of 16.00% for the storage type hydro generating stations including pumped storage hydro generating stations and run of river generating station with pondage for generating stations whose Date of Commercial Operation is before April 01, 2026:
Provided that the return on equity shall be allowed only on the equity employed on assets which are commissioned and are in use;
Provided further that the rate of return of a new project shall be reduced by 1.00% for such period as may be decided by the Commission, if the generating station is found to be declared under commercial operation without commissioning of any of Restricted Governor Mode Operation (RGMO)/Free Governor Mode Operation (FGMO), data telemetry, communication system up to load despatch centre or protection system;
Provided also as and when any of the above requirements are found lacking in a generating station based on the report submitted by the SLDC, return on equity shall be reduced by 1.00% for the period for which the deficiency continues.
15.11 Tax on income, if any, on the Generating business of the Generating Company shall be limited to tax on the allowed return on equity;
15.12 The income tax actually payable or paid limited to the tax on allowed return on equity shall be included in the ARR while truing up. The actual assessment of income tax should take into account benefits of tax holiday, and the credit for carry forward losses applicable as per the provisions of the Income Tax Act, 1961 and its amendments thereof shall be passed on to the Beneficiaries. Tax on the other income streams of the Generating Company shall not be recovered from the Beneficiaries.
Provided that if there is no actual loan for a particular year but normative loan is still outstanding, then the rate of interest shall be considered on normative basis and shall be equal to Bank Rate as on April 01 of the respective year of the Control Period plus 200 basis points;
Provided also that, in case of new Generating Company commencing its operation after the date of effectiveness of these Regulations, and which does not have actual loan portfolio, the rate of interest shall be considered on normative basis and shall be equal to Bank Rate as on April 01 of the respective year of the Control Period plus 200 basis points.
Provided that the cost of primary fuel shall be based on the landed cost incurred (taking into account normative transit and handling losses) by the generating station and gross calorific value of the fuel on ‘as received basis’ less 85 kCal/kg on account of variation during storage at generating station as per actual weighted average for three months preceding the first month for which tariff is to be determined:
Provided further that in case of new generating station, the cost of fuel for the first financial year shall be considered based on landed fuel cost (taking into account normative transit and handling losses) and gross calorific value of the fuel as per actual weighted average for three months, as used for infirm power, preceding date of commercial operation for which tariff is to be determined.
15.24 The working capital for Open-cycle Gas Turbine/Combined Cycle thermal based Generating Stations shall comprise the following components:
Provided that the cost of primary fuel shall be based on the landed cost incurred as per actual weighted average for three months preceding the first month for which tariff is to be determined:
Provided further that in case of new generating station, the cost of fuel for the first financial year shall be considered based on landed fuel and gross calorific value of the fuel as per actual weighted average for three months, as used for infirm power, preceding date of commercial operation for which tariff is to be determined.
Provided that the rate of interest on working capital shall be trued up on the basis of Bank Rate plus 350 basis points as applicable on April 01, of the respective financial year at the time of true up.
Provided that depreciation shall not be allowed on assets funded by Consumer Contribution and Capital Subsidies/Grants. Provision for replacement of such assets shall be made in the Capital Investment Plan.
Provided that the Generating Company shall ensure that once the individual asset is depreciated to the extent of seventy (70) percent of the Book Value of that asset, remaining depreciable value as on March 31 of the year closing shall be spread over the balance useful life of the asset;
Provided that in case the tenure of PPA executed between the Generating plant and Beneficiaries is more than that of the Useful life of the plant, the Commission after prudence check may consider the PPA life for spreading the remaining depreciable value as on March 31 of the year instead of useful life;
Provided that in case after carrying out the residual life assessment, it is found that the residual life of the generating station or unit as the case may be is beyond the useful life specified in these regulations the Commission after prudence check, may spread the remaining depreciable value to be recovered over the extended life of the plant.
Provided that any depreciation disallowed on account of lower availability of the generating station shall not be allowed to be recovered at a later stage during the useful life and the extended life.
Provided that the salvage value for IT equipment and software shall be considered as NIL and 100% value of the assets shall be considered depreciable:
Provided further that in case of hydro generating stations, the salvage value shall be as provided in the agreement signed by the developers with the State Government for creation of the site:
Provided also that the capital cost of the assets of the hydro generating station for the purpose of computation of depreciable value shall correspond to the percentage of sale of electricity under long-term Power Purchase Agreement at regulated tariff.
| Year | 200/210/250 MW Sets |
300/330/350 MW Sets |
500 MW Sets | 600 MW and above Sets |
|---|---|---|---|---|
| FY 2026-27 | 40.92 | 34.04 | 27.17 | 25.78 |
| FY 2027-28 | 43.07 | 35.83 | 28.60 | 27.13 |
| FY 2028-29 | 45.33 | 37.71 | 30.10 | 28.56 |
| FY 2029-30 | 47.71 | 39.69 | 31.68 | 30.06 |
| FY 2030-31 | 50.21 | 41.78 | 33.34 | 31.64 |
Note: all the values are in Rs. Lakh/MW
Provided that where the date of Commercial Operation of any additional Unit(s) of a Generating Station after first four Units occurs on or after April 01, 2026, the Operation & Maintenance Expenses of such additional Unit(s) shall be admissible at 90% of the Operation & Maintenance Expenses as specified above:
Provided further that the O&M Expenses for the existing Stations will be approved by the Commission in their respective MYT Orders based on the actual value of O&M expenses of the past Control Period and after carrying out due prudence check.
| Year | Gas Turbine/Combined Cycle Generating Stations | Small Turbine Power Generating Stations |
|---|---|---|
| FY 2026-27 | 18.18 | 47.86 |
| FY 2027-28 | 19.14 | 50.37 |
| FY 2028-29 | 20.14 | 53.02 |
| FY 2029-30 | 21.20 | 55.80 |
| FY 2030-31 | 22.32 | 58.73 |
Note: all the values are in Rs. Lakh/MW
| Year | 125 MW Sets |
|---|---|
| FY 2026-27 | 38.81 |
| FY 2027-28 | 40.85 |
| FY 2028-29 | 42.99 |
| FY 2029-30 | 45.25 |
| FY 2030-31 | 47.62 |
Note: all the values are in Rs. Lakh/MW
| Year | O&M Expenses |
|---|---|
| FY 2026-27 | 38.81 |
| FY 2027-28 | 40.85 |
| FY 2028-29 | 42.99 |
| FY 2029-30 | 45.25 |
| FY 2030-31 | 47.62 |
Note: all the values are in Rs. Lakh/MW
$$\mathbf{O&M_n = (R&M_n + EMP_n + A&G_n) + Terminal Liabilities}$$
Where,
R&Mn – Repair and Maintenance Costs of the Generating Company for the nth year;
EMPn – Employee Costs of the Generating Company for the nth year excluding terminal liabilities;
A&Gn – Administrative and General Costs of the Generating Company for the nth year.
a) $(\text{Repair & Maintenance})_n = K * GFA * (INDX_n / INDX_o)$
Where,
‘K’ is a constant (expressed in %) governing the relationship between Repair & Maintenance costs and Gross Fixed Assets (GFA) and shall be calculated based on the % of Repair & Maintenance to GFA of the preceding years of the Base Year in the MYT Order after normalising any abnormal expenses;
‘GFA’ is the opening value of the gross fixed asset of the nth year;
INDXn is the indexation for nth year of control period;
INDXo is the indexation for the base year of the control period;
b) $EMP_n + A&G_n = [(EMP_{n-1}) * (1 + G_n) + (A&G_{n-1})] * (INDX_n / INDX_{n-1})$
Where,
EMPn-1 – Employee Costs of the Generating Company for the (n-1)th year excluding terminal liabilities;
A&Gn-1 – Administrative and General Costs of the Generating Company for the (n-1)th year excluding legal/litigation expenses;
INDXn – Inflation factor to be used for indexing the employee cost and A&G cost. This will be a combination of the Consumer Price Index (CPI) and the Wholesale Price Index (WPI) for immediately preceding year before the base year;
Gn – is a growth factor for the nth year and it can be greater than or lesser than zero based on the actual performance. Value of Gn shall be determined by the Commission in the MYT Order for meeting the additional manpower requirement based on the Generating Company Filing, benchmarking and any other factor that the Commission feels appropriate;
Note-1: For the purpose of estimation, the same INDXn/INDXn-1 value shall be used for all years of the Control Period. However, the Commission will consider the actual values in the INDXn/INDXn-1 at the end of each year during the Annual Performance Review exercise and true up the employee cost and A&G expenses on account of this variation, for the Control Period;
Note-2: Any variation due to changes recommended by the Pay Commission or wage revision agreement, etc., will be considered separately by the Commission.
Note-3: Terminal Liabilities will be approved as per actual submitted by the Generating Company along with documentary evidence such as actuarial studies.
15.43 The Generating Company, in addition to the above details shall also submit the detailed break-up of the Legal/Litigation Expenses for the previous Years (FY 2020-21 to FY 2024-25) along with the details and documentary evidence of incurring such expenses. The Commission shall approve the legal expenses as per the relevant provisions of the Jharkhand State Litigation Policy based on the necessary documentary evidence submitted for the Control Period and shall carry out due prudence check of legal expenses at the time of truing up.
15.44 The additional Operation and Maintenance expenses on account of implementation of revised emission standards shall be approved on case-to-case basis.
15.45 In case of the hydro generating stations declared under commercial operation on or after April 01, 2026, operation and maintenance expenses of first year shall be fixed at 3.5% and 5.0% of the original project cost (excluding cost of rehabilitation & resettlement works, IDC and IEDC) for stations with installed capacity exceeding 200 MW and for stations with installed capacity less than 200 MW respectively, with annual escalation ( $INDX_n / INDX_{n-1}$ ) as determined annually.
Provided that Water Charges shall be allowed based on water consumption, depending upon type of plant, type of cooling water system, subject to prudent check. The details regarding the same shall be furnished along with the Petition.
Provided that the generating station shall submit the details of year wise actual capital spares consumed at the time of truing up with appropriate justification for incurring the same and substantiating that the same is not funded through special allowance as per Clause 14.11 and 14.12 of the Regulation or claimed as a part of additional capitalisation or consumption of stores and spares and renovation and modernization
Provided that the generating station shall submit the assessment of the security requirement and estimated expenses, and the details of year-wise actual capital spares consumed at the time of truing up with appropriate justification.
Provided that the Generating Company shall submit full details of its forecast of Non-Tariff Income to the Commission in such form as may be stipulated by the Commission.
a) Income from rent of land or buildings;
Provided that the interest earned from investments made out of return on equity corresponding to the Generating Business of the Generating Company shall not be included in Non-Tariff Income.
Provided that the onus to substantiate, to the satisfaction of the Commission, that such investments have been out of Return on Equity shall be on the Generating Company.
15.50 Where the Generating Company is engaged in any Other Business utilising infrastructure and/or manpower of regulated business by any means, the income from such business will be calculated considering the following conditions:
The Generating Company shall not in any manner utilize the assets and facilities of the Generating Business or otherwise directly or indirectly allow the activities to be undertaken in a manner that it results in the Generating Business subsidising the Other Business in any manner;
The Generating Company shall not in any manner, directly or indirectly encumber the assets and facilities of the Generating Business for the Other Business or for any activities other than the Generating Business;
The Generating Company shall duly pay for all costs accounted for in the Generating Business, which have been incurred for Other Business and in the event of such cost being incurred commonly for both the Generating Business and Other Business, apportion such cost and ensure due payment of apportioned costs to the Generating Business from the Other Business;
The revenue derived from the Other Business shall be commensurate with prevailing market condition for such similar business activities;
In addition to the sharing of costs under sub-clause 3 above, the Generating Company shall account for and ensure due payment to the Generating Business a certain proportion of revenues from the Other Business. The Generating Company shall retain 50% of the revenues arising on account of Other Business and pass on the remaining 50% of the revenues to the Beneficiaries.
Provided that the Generating Company shall follow a reasonable basis for allocation of all joint and common costs between the Generating Business and the Other Business and shall submit the Allocation Statement as approved by the Board of Directors to the Commission along with his application for determination of tariff:
Provided further that where the sum total of the direct and indirect costs of such Other Business exceeds the revenues from such Other Business, no amount shall be allowed to be added to the ARR of the Generating Company on account of such Other Business.
| Parameters | UoM | FY26-27 | FY27-28 | FY28-29 | FY29-30 | FY30-31 |
|---|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Normative Annual Plant Load Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Gross Station Heat Rate | kCal/kWh | 2567.00 | 2567.00 | 2567.00 | 2567.00 | 2567.00 |
| Auxiliary Consumption | % | 10.00 | 10.00 | 10.00 | 10.00 | 10.00 |
| Secondary Fuel Oil Consumption | ml/kWh | 0.5 | 0.5 | 0.5 | 0.5 | 0.5 |
| Parameters | UoM | FY26-27 | FY27-28 | FY28-29 | FY29-30 | FY30-31 |
|---|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Normative Annual Plant Load Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Gross Station Heat Rate | kCal/kWh | 2577.00 | 2577.00 | 2577.00 | 2577.00 | 2577.00 |
| Auxiliary Consumption | % | 10.00 | 10.00 | 10.00 | 10.00 | 10.00 |
| Secondary Fuel Oil Consumption | ml/kWh | 0.5 | 0.5 | 0.5 | 0.5 | 0.5 |
| Parameters | UoM | FY26-27 | FY27-28 | FY28-29 | FY29-30 | FY30-31 |
|---|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Normative Annual Plant Load Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Gross Station Heat Rate | kCal/kWh | 2387.00 | 2387.00 | 2387.00 | 2387.00 | 2387.00 |
| Auxiliary Consumption | % | 9.00 | 9.00 | 9.00 | 9.00 | 9.00 |
| Secondary Fuel Oil Consumption | ml/kWh | 0.50 | 0.50 | 0.50 | 0.50 | 0.50 |
| Parameters | UoM | FY26-27 | FY27-28 | FY28-29 | FY29-30 | FY30-31 |
|---|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Normative Annual Plant Load Factor | % | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Gross Station Heat Rate | kCal/kWh | 2387.00 | 2387.00 | 2387.00 | 2387.00 | 2387.00 |
| Auxiliary Consumption | % | 9.00 | 9.00 | 9.00 | 9.00 | 9.00 |
| Secondary Fuel Oil Consumption | ml/kWh | 0.50 | 0.50 | 0.50 | 0.50 | 0.50 |
| Parameters | FY 2026-27 | FY 2027-28 | FY 2028-29 | FY 2029-30 | FY 2030-31 |
|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor (%) | 82.50 | 82.50 | 82.50 | 82.50 | 82.50 |
| Normative Annual Plant Load Factor (%) | 82.50 | 82.50 | 82.50 | 82.50 | 82.50 |
| Gross Station Heat Rate (kcal/kWh) | 2902.00 | 2902.00 | 2902.00 | 2902.00 | 2902.00 |
| Auxiliary Consumption (%) | 10.50 | 10.50 | 10.50 | 10.50 | 10.50 |
| Secondary Fuel Oil Consumption (ml/kWh) | 1.00 | 1.00 | 1.00 | 1.00 | 1.00 |
| Parameters | FY 2026-27 | FY 2027-28 | FY 2028-29 | FY 2029-30 | FY 2030-31 |
|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor (%) | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Normative Annual Plant Load Factor (%) | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Gross Station Heat Rate (kcal/kWh) | 2547.00 | 2547.00 | 2547.00 | 2547.00 | 2547.00 |
| Auxiliary Consumption (%) | 9.50 | 9.50 | 9.50 | 9.50 | 9.50 |
| Secondary Fuel Oil Consumption (ml/kWh) | 1.00 | 1.00 | 1.00 | 1.00 | 1.00 |
| Parameters | FY 2026-27 | FY 2027-28 | FY 2028-29 | FY 2029-30 | FY 2030-31 |
|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor (%) | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Normative Annual Plant Load Factor (%) | 85.00 | 85.00 | 85.00 | 85.00 | 85.00 |
| Gross Station Heat Rate (kcal/kWh) | 2547.00 | 2547.00 | 2547.00 | 2547.00 | 2547.00 |
| Auxiliary Consumption (%) | 9.50 | 9.50 | 9.50 | 9.50 | 9.50 |
| Secondary Fuel Oil Consumption (ml/kWh) | 1.00 | 1.00 | 1.00 | 1.00 | 1.00 |
Provided that for any existing generating station whose norms are not specified above and whose determination of tariff falls under the jurisdiction of this Commission, the Commission shall determine the norms for such generating station on case-to-case basis taking into consideration actuals and the norms specified in the previous Control Period after carrying out due prudence check based on the petition submitted by the Generating Company.
SHR=1.05 x Design Heat Rate (kcal/kWh);
Where, the Design Heat Rate of the generating Unit means the Unit heat rate guaranteed by the supplier at conditions of 100% MCR, zero percent make up, design coal and design cooling water temperature/back pressure:
Provided that the design heat rate shall not exceed the following maximum design Unit heat rates depending upon the pressure and temperature ratings of the Units:
| Particulars | Values | ||||||
|---|---|---|---|---|---|---|---|
| Pressure Rating (kg/cm 2 ) | 150 | 170 | 170 | 247 | 247 | 270 | 270 |
| SHT/RHT (°C) | 535/535 | 537/537 | 537/565 | 537/565 | 565/593 | 593/593 | 600/600 |
| Type of BFP | Electrical Driven | Turbine driven | Turbine driven | Turbine driven | Turbine driven | Turbine driven | Turbine driven |
| Particulars | Values | ||||||
|---|---|---|---|---|---|---|---|
| Max Turbine Cycle Heat rate (kcal/kWh) | 1955 | 1950 | 1935 | 1900 | 1850 | 1810 | 1800 |
| Minimum Boiler Efficiency | |||||||
| Sub-Bituminous Indian Coal | 0.86 | 0.86 | 0.86 | 0.86 | 0.86 | 0.865 | 0.865 |
| Bituminous Imported Coal | 0.89 | 0.89 | 0.89 | 0.89 | 0.89 | 0.895 | 0.895 |
| Maximum Design Heat rate (kcal/kWh) | |||||||
| Sub-Bituminous Indian Coal | 2273 | 2267 | 2250 | 2222 | 2151 | 2105 | 2081 |
| Bituminous Imported Coal | 2197 | 2191 | 2174 | 2135 | 2078 | 2034 | 2022 |
Provided further that in case pressure and temperature parameters of a Unit are different from above ratings, the maximum design unit heat rate of the nearest class shall be taken:
Provided also that where unit heat rate has not been guaranteed but turbine cycle heat rate and boiler efficiency are guaranteed separately by the same supplier or different suppliers, the unit design heat rate shall be arrived at by using guaranteed turbine cycle heat rate and boiler efficiency:
Provided also that where the boiler efficiency is lower than 86% for Subbituminous Indian coal and 89% for bituminous imported coal, the same shall be considered as 86% and 89% for Sub-bituminous Indian coal and bituminous imported coal respectively, for computation of station heat rate:
Provided also that maximum turbine cycle heat rate shall be adjusted for type of dry cooling system:
Provided also that if one or more Units were declared under commercial operation prior to April 01, 2026, the heat rate norms for those Units as well as Units declared under commercial operation on or after April 01, 2026, shall be lowest of the heat rate norms arrived at by above methodology and the norms specified in Clause 16.1 of these Regulations:
Provided also that for Generating stations based on coal rejects, the Commission shall approve the Station Heat Rate on case-to-case basis.
Note: In respect of Units where the boiler feed pumps are electrically operated, the maximum design unit heat rate shall be 40 kcal/kWh lower than the maximum design unit heat rate specified above with turbine driven BFP.
For Natural Gas = $1.05 \times \text{Design Heat Rate of the Unit/block (kcal/kWh)}$
For RLNG = $1.071 \times \text{Design Heat Rate of the Unit/block for Liquid Fuel (kcal/kWh)}$ ;
Where, the Design Heat Rate of a Unit shall mean the guaranteed heat rate for a Unit at 100% MCR and at site ambient conditions; and the Design Heat Rate of a block shall mean the guaranteed heat rate for a block at 100% MCR, site ambient conditions, zero percent make up, design cooling water temperature/back pressure.
For Coal-based generating stations with Natural Draft cooling tower or without cooling tower:
| Sr.no. | Generating Station | Auxiliary Energy Consumption |
|---|---|---|
| 1. | 200 MW Series | 8.50% |
| 2. | 300 MW and above Series with Steam driven Boiler Feed Pumps | 5.75% |
| 3. | 300/330/350/500 MW Series with Electrically driven Boiler Feed Pumps | 8.00% |
Provided that for thermal generating stations with induced draft cooling towers, the norms shall be further increased by 0.5%:
Provided further that additional auxiliary energy consumption as follows shall be allowed for plants with Dry Cooling Systems:
| Sr.no. | Type of Dry Cooling System | Type of Dry Cooling System |
|---|---|---|
| 1. | Direct cooling air cooled condensers with mechanical draft fans | 1.0% |
| 2. | Indirect cooling system employing jet condensers with pressure recovery turbine and natural draft tower | 0.5% |
Note: The auxiliary energy consumption for the Unit capacity of less than 200 MW sets shall be dealt on case-to-case basis.
| Sr.no. | Generating Station | Auxiliary Energy Consumption |
|---|---|---|
| 1. | Combined Cycle | 2.5% |
| 2. | Open Cycle | 1.0% |
Wherever the station is designed for combined cycle operation, the approval of SLDC shall be required for operation of the station in the open cycle mode.
For Coal-based generating stations: 0.50 ml/kWh;
For Lignite-fired generating stations: 1.00 ml/kWh
16.4 Operational norms specified in these Regulations are the ceiling norms and shall not preclude the Generating Company and the beneficiaries from agreeing to the improved norms and in case the improved norms are agreed to, such improved norms shall be applicable for determination of tariff. The Generating Company and the beneficiaries are required to provide the detail of such improved norms before the Commission.
16.5 In case of renovation and modernisation, derating and rerating of the generating station, norms of operation may be reviewed and modified accordingly by the Commission.
16.6 The generating station whose tariff is determined by the commission under section 62 of the Act shall be compensated for degradation of station heat rate and auxiliary energy compensation, consumption of additional secondary fuel oil due to loading below normative plant availability factor specified in Section A 16 of these Regulation.
16.7 The compensation of degradation under clause 16.6 of the regulation shall be borne by the entity / beneficiary that has caused the plant to be operated at a schedule lower than the corresponding Normative Plant Availability Factor.
16.8 The compensation for the station heat rate and auxiliary energy consumption shall be worked out in terms of energy charge rate.
16.9 For the purpose of compensation under clause 16.6 of this regulation, the degradation of gross station heat rate (SHR) over and above the norms specified under clause 16.1 of the regulation shall be considered as under: -
| Sl No | Unit loading as a % of Installed Capacity of the Unit | Increase in SHR (for subcritical units) % | Increase in SHR (for supercritical units) % |
|---|---|---|---|
| 1. | 85-100 | Nil | Nil |
| 2. | 80-<85 | 2.1 | 1.8 |
| 3. | 75-<80 | 3.0 | 2.5 |
| 4. | 70-<75 | 4.0 | 3.3 |
| 5. | 65-<70 | 5.1 | 4.1 |
| 6. | 60-<65 | 6.1 | 4.9 |
| 7. | 55-<60 | 7.6 | 6.0 |
| 8. | 50-<55 | 9.2 | 7.1 |
| 9. | 45-<50 | 11.3 | 8.3 |
| 10. | 40-<45 | 13.8 | 9.9 |
| Sl No | Unit loading as a % of Installed Capacity of the Unit | % degradation in AEC admissible |
|---|---|---|
| 1. | 85-100 | Nil |
| 2. | 80-<85 | 0.5 |
| 4. | 70-<80 | 1.1 |
| 6. | 60-<70 | 1.8 |
| 8. | 50-<60 | 2.5 |
| 10. | 40-<50 | 3.2 |
| Unit Size (MW) | Secondary fuel oil consumption per start up (KL) |
|---|---|
| ---------------- | -------------------------------------------------- |
| 200/210/250 MW | 20 | 40 | 60 |
| 500 MW | 30 | 60 | 100 |
| 660 MW | 45 | 75 | 130 |
| 800 MW | 60 | 80 | 150 |
$CC1 = (AFC/12)(PAF1/NAPAF)$ subject to ceiling of $(AFC/12)$ ;
$CC2 = ((AFC/6)(PAF2/NAPAF))$ subject to ceiling of $(AFC/6)$ )-CC1;
$CC3 = ((AFC/4)(PAF3/NAPAF))$ subject to ceiling of $(AFC/4)$ )-(CC1+CC2);
$CC4 = ((AFC/3)(PAF4/NAPAF))$ subject to ceiling of $(AFC/3)$ )-(CC1+CC2+CC3);
$CC5 = ((AFC \times 5/12)(PAF5/NAPAF))$ subject to ceiling of $(AFC \times 5/12)$ )-(CC1+CC2+CC3+CC4);
$CC6 = ((AFC/2)(PAF6/NAPAF))$ subject to ceiling of $(AFC/2)$ )-(CC1+CC2+CC3+CC4 + CC5)
$CC7 = ((AFC \times 7/12)(PAF7/NAPAF))$ subject to ceiling of $(AFC \times 7/12)$ )-(CC1+CC2+CC3+CC4+CC5+CC6);
$CC8 = ((AFC \times 2/3)(PAF8/NAPAF))$ subject to ceiling of $(AFC \times 2/3)$ )-(CC1+CC2 +CC3 +CC4+CC5+CC6+CC7);
$CC9 = ((AFC \times 3/4)(PAF9/NAPAF))$ subject to ceiling of $(AFC \times 3/4)$ )-(CC1+CC2 +CC3+CC4+CC5+CC6+CC7+CC8);
$CC10 = ((AFC \times 5/6)(PAF10/NAPAF))$ subject to ceiling of $(AFC \times 5/6)$ )-(CC1+CC2+CC3+CC4+CC5+CC6+CC7+CC8+CC9);
$CC11 = ((AFC \times 11/12)(PAF11/NAPAF))$ subject to ceiling of $(AFC \times 11/12)$ )-(CC1+CC2+CC3+CC4+CC5+CC6+CC7+CC8+CC9+CC10);
$CC12 = ((AFC)(PAFY/NAPAF))$ subject to ceiling of $(AFC)$ )-(CC1+CC2+CC3+CC4+CC5+CC6+CC7+CC8+CC9+CC10+CC11);
Provided that in case of generating station or Unit thereof under shutdown due to Renovation and Modernisation, the Generating Company shall be allowed to recover Operation and Maintenance expenses and interest on loan only;
Where,
AFC = Annual Fixed Cost, specified for the year (in Rupees);
NAPAF = Normative Annual Plant Availability Factor (%);
PAFM = Plant Availability Factor achieved up to the end of nth month (%);
PAFY = Plant Availability Factor achieved during the Year (%).
CC1, CC2, .....CC12 are the Capacity Charges of 1st, 2nd ..... and 12th months, respectively.
$$PAFM = 100 \times \sum_{i=1}^N DC_i / {N \times IC \times (1 - Aux)} %$$
Where,
Aux: Normative Auxiliary Energy Consumption (%);
DCi: Average Declared Capacity (in ex-bus MW), for the ith time block in such period;
IC: Installed Capacity (in MW) of the generating station;
N: Number of time blocks in the given period.
Energy Charges = Energy Charge Rate (in Rs./kWh) x Scheduled Energy (Ex-Bus) for the Month (in kWh)
For coal-based stations and lignite fired stations:
Energy Charge Rate (ECR) = {(SHR - SFC x CVSF) x LPPF / CVPF + SFC x LPSFi + LC x LPL} / (1 - Aux)
For gas and liquid fuel-based stations:
ECR = SHR x LPPF / {CVPF x (1 - Aux)}
Where,
Aux: Normative auxiliary energy consumption (%);
CVPF: (a) Weighted Average Gross calorific value of coal as received, in kcal per kg for coal-based stations less 85 Kcal/Kg on account of variation during storage at generating station;
(b) Weighted Average Gross calorific value of primary fuel as received in kcal per kg, per litre or per standard cubic meter, as applicable for lignite, gas and liquid fuel-based stations;
(c) In case of blending of fuel from different sources, the weighted average Gross calorific value of primary fuel shall be arrived in proportion to blending ratio.
CVSF: Calorific value of secondary fuel (kcal/ml);
ECR - Energy Charge Rate (Rs./kWh);
SHR - Gross Station Heat Rate (kcal/kWh);
LC = Normative limestone consumption (kg/kWh);
LPPF - Weighted average landed price of primary fuel, in Rupees per kg, per litre or per standard cubic metre, as applicable, during the month. (In case of blending of fuel from different sources, the weighted average landed price of primary fuel shall be arrived in proportion to blending ratio);
LPSFi=Weighted Average Landed Price of Secondary Fuel in Rs./ml during the month;
LPL = Weighted average landed price of limestone in Rupees per kg;
SFC - Specific fuel oil consumption, in ml per kWh.
Provided that the energy charge rate for a gas or liquid fuel-based station shall be adjusted for open cycle operation based on certification of SLDC for the open cycle operation during the month.
Provided that the details of blending ratio of the imported coal with domestic coal, proportion of e-auction coal and the weighted average GCV of the fuels as received shall also be provided separately, along with the bills of the respective month:
Provided further that copies of the bills and details of parameters of GCV and price of fuel, i.e., domestic coal, imported coal, e-auction coal, lignite, natural gas, RLNG, liquid fuel, etc., and details of blending ratio of the imported coal with domestic coal, proportion of e-auction coal shall also be displayed on the website of the Generating Company. The details should be available on its website on monthly basis for a period of three months.
17.10 The landed fuel cost of primary fuel and secondary fuel for tariff determination shall be based on actual weighted average cost of primary fuel and secondary fuel of the three preceding months, and in the absence of landed costs for the three preceding months, latest procurement price of primary fuel and secondary fuel for the generating station, before the start of the Control period for existing stations and immediately preceding three months in case of new generating stations shall be taken into account.
17.11 The landed cost of fuel for the month shall include price of fuel corresponding to the grade and quality of fuel inclusive of royalty, taxes and duties as applicable, transportation cost by rail/road or any other means, and, for the purpose of computation of energy charge, and in case of coal/lignite shall be arrived at after considering normative transit and handling losses as percentage of the quantity of coal or lignite dispatched by the coal or lignite supply company during the month as given below:
Pithead generating stations: 0.2%
Non-pithead generating stations: 0.8%
Provided that in case of pithead stations if coal or lignite is procured from sources other than the pithead mines, which is transported to the station through rail, transit loss of 0.8% shall be applicable:
Provided further that in case of imported coal, the transit and handling losses shall be 0.2%.
17.12 The Fuel Price Adjustment (FPA) applicable for calculation of Energy Charges is as follows:
a) For coal-based generating stations, $FPA = A + B$
Where,
FPA – Fuel price Adjustment for a month in Paise/kWh sent out;
A – Fuel price adjustment for Secondary Fuel oil in Paise/kWh sent out;
B – Fuel price adjustment for Coal in Paise/kWh sent out;
$$A = {10 / (100 - AC_n)} * SFC_n * (P_{om} - P_{os})$$
$$B = {10 / (100 - AC_n)} * [SHR_n * {(P_{cm}/K_{cm}) - (P_{cs}/K_{cs})} - SFC_n * {(K_{om} * P_{cm}/K_{cm}) - (K_{oms} * P_{cs}/K_{cs})}]$$
Where,
$SFC_n$ = Normative Specific Fuel Oil consumption in L/kWh;
$SHR_n$ = Normative Gross Station Heat Rate in kcal/kWh;
$AC_n$ = Normative Auxiliary consumption, in absolute term (if normative aux is 10%, then absolute value i.e. 10, to be considered;
$P_{om}$ = Weighted average price of fuel oil on as consumed basis during the month in Rs. /kL;
$K_{om}$ = Weighted average Gross Calorific Value of fuel oils fired for the month in kcal/Litre;
$P_{os}$ = Base value of price of fuel oils as taken for determination of base energy charge in the Tariff Order in Rs./kL;
$K_{os}$ = Base value of Gross Calorific Value of fuel oils as taken for determination of base energy charge in the Tariff Order in kcal/Litre;
$P_{cm}$ = Weighted average price of coal procured and burnt during the month at the power station in Rs. / MT;
$K_{cm}$ = Weighted average Gross Calorific Value of coal fired at boiler front for the month in kcal/kg;
$P_{cs}$ = Base value of price of coal as taken for determination of base energy charge in the Tariff Order in Rs. /MT;
$K_{cs}$ = Base value of gross calorific value of coal as taken for determination of base energy charge in the Tariff Order in kcal/kg.
$$FPA = \frac{10 * SHR_n * [(P_m/K_m) - (P_s/K_s)]}{(100 - AC_n)}$$
Where:
FPA = Fuel Price Adjustment for a month in Paise/kWh sent out;
$SHR_n$ = Normative Gross Station Heat Rate expressed in kcal/kWh;
$AC_n$ = Normative Auxiliary Consumption, in absolute term (if normative aux is 10%, then absolute value i.e. 10, to be considered;
$P_m$ = Weighted average price of Gas or Liquid fuel as per PSL for the month in Rs. / 1000 SCM of Rs./ KL or Rs./MT;
$K_m$ = Weighted average Gross Calorific Value of Gas or Liquid fuel for the month in Kcal/ SCM or kcal/ Litre or kcal/kg;
$P_s$ = Base price of Gas or Liquid fuel as taken for determination of base energy charge in tariff order in Rs. / 1000 SCM of Rs./kL or Rs./MT;
$K_s$ = Base value of Gross Calorific Value of Gas or Liquid fuel as taken for determination of base energy charge in tariff order in kcal/ SCM or kcal/Litre or kcal/ Kg.
18.1 The norms of operation for hydro power station shall be as under:
18.2 Normative Annual Plant Availability Factor (NAPAF): The Normative Annual Plant Availability Factor for hydro generating stations shall be determined by the Commission as per the following criteria:
$$= (\text{Average head}/\text{Rated head}) + 0.02$$
Alternatively, in case of a difficulty in making such projection, the multiplying factor may be determined as:
$$= (\text{Head at MDDL}/\text{Rated head}) \times 0.5 + 0.52$$
18.3 A further allowance may be made by the Commission in NAPAF determination under special circumstances, e.g., abnormal silt problem or other operating conditions, and known plant limitations.
18.4 In case of a new hydroelectric project, the developer shall have the option of approaching the Commission in advance for fixation of NAPAF based on the principles enumerated in Clause 18.2 and Clause 18.3 of these Regulations.
Provided that in the event of the beneficiaries failing to supply the desired level of energy during off-peak hours, there will be pro-rata reduction in their energy entitlement from the station during peak hours:
| Sr.no. | Type of Station | Auxiliary Energy Consumption | |
|---|---|---|---|
| Installed Capacity above 200 MW |
Installed Capacity upto 200 MW |
||
| 1. | Surface | ||
| Rotating Excitation | 0.7% | 0.7% | |
| Static | 1.0% | 1.2% | |
| 2. | Underground | ||
| Rotating Excitation | 0.9% | 0.9% | |
| Static | 1.2% | 1.3% |
| Parameters | FY 2026-27 | FY 2027-28 | FY 2028-29 | FY 2029-30 | FY 2030-31 |
|---|---|---|---|---|---|
| Normative Annual Plant Availability Factor (%) | 75% | 75% | 75% | 75% | 75% |
| Auxiliary Consumption (%) | 0.70% | 0.70% | 0.70% | 0.70% | 0.70% |
Provided that during the period between the date of Commercial Operation of the first Unit of the generating station and the Date of Commercial Operation of the generating station, the Annual Fixed Cost shall provisionally be worked out based on the latest estimate of the completion cost for the generating station, for the purpose of determining the Capacity Charge and Energy Charge payable during such period.
Capacity Charge (inclusive of incentive) = $AFC \times 0.5 \times NDM / NDY \times (PAFM / NAPAF)$ (in Rupees)
Where,
AFC: Annual Fixed Cost specified for the Year, in Rupees;
NAPAF: Normative Plant Availability Factor in percentage;
NDM: Number of Days in the month;
NDY: Number of Days in the Year;
PAFM: Plant Availability Factor achieved during the month, in Percentage;
Provided that the revenue recovered through capacity charges shall not exceed 50% of the Annual Fixed Charges determined.
$$PAFM = 100 \times \sum_{i=1}^N DC_i / {N \times IC \times (1 - Aux)} %$$
Where,
Aux: Normative auxiliary energy consumption in percentage;
DCi: Declared Capacity (in ex-bus MW) for the ith Day of the month, which the station can deliver for at least three (3) hours, as certified by the State Load Despatch Centre after the Day is over;
IC: Installed Capacity (in MW) of the complete generating station;
N: Number of Days in the month.
Energy Charges= (Energy Charge Rate in Rs. / kWh) x {Scheduled Energy (ex-bus) for the month in kWh} x (100 - FEHS) / 100.
ECR = AFC x 0.5 x 10 / {DE x (100 - AUX) x (100 - FEHS)}
Where,
DE: Annual Design Energy specified for the Hydro generating station, in MWh, subject to the provision in Clause 19.6 of these Regulations;
FEHS: Free Energy for home State, as defined in Clause 22.2 of these Regulations.
Provided that in case actual generation from a hydro generating station is less than the design energy for a continuous period of four years on account of hydrology factor, the generating station shall approach the Central Electricity Authority with relevant hydrology data for revision of design energy of the station.
$(AFC \times NDM / NDY)$ (in Rupees), if actual Generation during the month is $\geq 75%$ of the Pumping Energy consumed by the station during the month and ${(AFC \times NDM / NDY) \times (\text{Actual Generation during the month during peak hours} / 75% \text{ of the Pumping Energy consumed by the station during the month})}$ (in Rupees), if actual Generation during the month is $< 75%$ of the Pumping Energy consumed by the station during the month;
Where,
AFC: Annual Fixed Cost specified for the year, in Rupees;
NDM: Number of days in the month;
NDY: Number of days in the year:
Provided that there would be adjustment at the end of the year based on actual generation and actual pumping energy consumed by the station during the year.
19.12 The energy charge shall be payable by every beneficiary for the total energy scheduled to be supplied to the beneficiary in excess of the design energy plus 75% of the energy utilized in pumping the water from the lower elevation reservoir to the higher elevation reservoir, at a flat rate equal to the average energy charge rate of 20 paise per kWh, excluding free energy, if any, during the calendar month, on ex-power plant basis.
19.13 Energy charge payable to the Generating Company for a month shall be:
$$= 0.20 \times { \text{Scheduled energy (ex-bus) for the month in kWh} - (\text{Design Energy for the month (DE}_m) + 75% \text{ of the energy utilized in pumping the water from the lower elevation reservoir to the higher elevation reservoir of the month}) } \times (1 - \text{FEHS});$$
Where,
DEm: Design energy for the month specified for the hydro generating station in MWh
FEHS: Free energy for home State, in percentage:
Provided that in case the Scheduled energy in a month is less than the Design Energy for the month plus 75% of the energy utilized in pumping the water from the lower elevation reservoir to the higher elevation reservoir of the month, then the energy charges payable by the beneficiaries shall be zero.
19.14 The Generating Company shall maintain the record of daily inflows of natural water into the upper elevation reservoir and the reservoir levels of upper elevation reservoir and lower elevation reservoir on hourly basis. The generator shall be required to maximize the peak hour supplies with the available water including the natural flow of water. In case it is established that generator is deliberately or otherwise without any valid reason, not pumping water from lower elevation reservoir to the higher elevation during off-peak period or not generating power to its potential or wasting natural flow of water, the capacity charges of the day shall not be payable by the beneficiary. For this purpose, outages of the Unit(s)/station including planned outages and the forced outages up to 15% in a year shall be construed as the valid reason for not pumping water from lower elevation reservoir to the higher elevation during off-peak period or not generating power using energy of pumped water or natural flow of water:
Provided that the total capacity charges recovered during the year shall be adjusted on pro-rata basis in the following manner in the event total machine outages in a year exceeds 15%:
$$(ACC)_{adj} = (ACC) R \times (1 - ATO)/0.85$$
Where,
(ACC)adj – Adjusted Annual Capacity Charges
(ACC) R – Annual Capacity Charges recovered
ATO - Total Outages in percentage for the year including forced and planned outages:
Provided further that the generating station shall be required to declare its machine availability daily on day ahead basis for all the time blocks of the day in line with the scheduling procedure of Grid Code.
22.1 Bills shall be raised for Capacity Charge and Energy Charge on monthly basis by the Generating Company in accordance with these Regulations, and payments shall be made by the Beneficiaries directly to the Generating Company.
22.2 Payment of the Capacity Charge for a thermal generating station shall be shared by the Beneficiaries of the Generating Station as per their percentage shares for the month in the installed capacity of the generating station. Payment of capacity charge and energy charge for a hydro generating station shall be shared by the Beneficiaries of the generating station in proportion to their shares in the saleable capacity (to be determined after deducting the capacity corresponding to free energy to home State as per Note 1 herein).
FEHS - Free Energy for Home State, in per cent shall be taken as 13% (not applicable for generating stations of the State):
Provided that in cases where the site of a Hydro Project is awarded to a developer (not being a State controlled or owned Company), by a State Government by following a two-stage transparent process of bidding, the "Free Energy" shall be taken as 13%, which shall also include energy corresponding to 100 Units of electricity to be provided free of cost every month to every Project affected family for a period of 10 Years from the Date of Commercial Operation of the generating station.
Provided that the rate of Late Payment Surcharge shall not exceed the rate specified in the Power Purchase Agreement entered between the Generating Company and Distribution Licensee.
Note 1: In case of computation of 5 days, the number of days shall be counted consecutively without considering any holiday. However, in case the last day or 5th day is official holiday, the 5th day for the purpose of Rebate shall be construed as the immediate succeeding working day (as per the official State Government's calendar, where the Office of the Authorized Signatory or Representative of the Beneficiary, for the purpose of receipt or acknowledgement of Bill is situated).
Note 2: As per example if a bill is issued on the 1st day of any month, the 5 days will be counted from the 2nd day of the month, i.e. the 6th day of the month will be the end date for availing the rebate.
27.1 The Generating Company may hedge foreign exchange exposure in respect of the interest and repayment of foreign currency loan taken for the generating station, in part or full at their discretion.
27.2 If the Generating Company enters into hedging arrangement(s) based on its approved hedging policy, the Generating Company shall communicate to the beneficiaries concerned, of entering into such arrangement(s) within thirty days.
27.3 Every Generating Company shall recover the cost of hedging of Foreign Exchange Rate Variation corresponding to the normative foreign debt, in the relevant Year on Year-to-Year basis as expense in the period in which it arises and extra rupee liability corresponding to such foreign exchange rate variation shall not be allowed against the hedged foreign debt.
27.4 To the extent the Generating Company is not able to hedge the foreign exchange exposure, the extra rupee liability towards interest payment and loan repayment corresponding to the normative foreign currency loan in the relevant Year shall be permissible, provided it is not attributable to the Generating Company or its suppliers or contractors.
27.5 The Generating Company shall recover the cost of hedging and Foreign Exchange Rate variation on Year-to-Year basis as income or expense in the period in which it arises.
| Sl. No. | Description | Filing of the Petition by the Generating Company | Furnishing additional information as sought by the Commission | Disposal of the Petition by the Commission |
|---|---|---|---|---|
| 1. | Business Plan for the Control Period and MYT Petition for the Control Period for FY 2026-27 to FY 2030-31 including Tariff for each year of the Control Period | November 30, 2025 | Within 15 days of issuance of letter regarding the information required | Within 120 days of acceptance of the filing |
| 2. | True-Up for the previous year, Annual Performance Review for the current year and ARR & Tariff Determination for the next year of the Control Period | November 30, of the financial year for which APR has been sought | Within 15 days of issuance of letter regarding the information required. | Within 120 days of acceptance of the filing |
| Asset Description | Straight Line Depreciation (%) |
|---|---|
| Land owned under full ownership | 0.00 |
| Land held under lease: | |
| For investment in the land | 2.67 |
| For cost of clearing the site | 2.67 |
| Land for reservoir in case of hydro generating station | 2.67 |
| Assets Purchased New: | |
| Plant & Machinery in generating stations | |
| Hydro electric | 4.22 |
| Steam electric NHRB & waste heat recovery boilers | 4.22 |
| Diesel electric and gas plant | 4.22 |
| Cooling towers & circulating water systems | 4.22 |
| Hydraulic works forming part of the Hydro-generating stations | |
| Dams, Spillways, Weirs, Canals, Reinforced concrete flumes and siphons | 4.22 |
| Reinforced concrete pipelines and surge tanks, steel pipelines, sluice gates, steel surge tanks, hydraulic control valves and hydraulic works | 4.22 |
| Building & Civil Engineering works | |
| Offices and showrooms | 2.67 |
| Containing thermo-electric generating plant | 2.67 |
| Asset Description | Straight Line Depreciation (%) |
|---|---|
| Containing hydro-electric generating plant | 2.67 |
| Temporary erections such as wooden structures | 100 |
| Roads other than Kutcha roads | 2.67 |
| Others | 2.67 |
| Transformers, Kiosk, sub-station equipment & other fixed apparatus (including plant foundations) | |
| Transformers including foundations having rating of 100 kVA and over | 4.22 |
| Others | 4.22 |
| Switchgear including cable connections | 4.22 |
| Lightning arrestor | |
| Station type | 4.22 |
| Pole type | 4.22 |
| Synchronous condenser | 4.22 |
| Batteries | 12.77 |
| Underground cable including joint boxes and disconnected boxes | 4.22 |
| Cable duct system | 4.22 |
| Overhead lines including cable support | |
| Lines on fabricated steel operating at terminal voltages higher than 66 kV | 4.22 |
| Lines on steel supports operating at terminal voltages higher than 13.2 kV but not exceeding 66 kV | 4.22 |
| Lines on steel on reinforced concrete support | 4.22 |
| Lines on treated wood support | 4.22 |
| Meters | 12.77 |
| Self-propelled vehicles | 12.77 |
| Air Conditioning Plants | |
| Static | 4.22 |
| Portable | 7.60 |
| Furniture and Furnishing | |
| Office furniture and furnishing | 6.33 |
| Office equipment | 6.33 |
| Internal wiring including fittings and apparatus | 6.33 |
| Street Light fittings | 6.33 |
| Apparatus let on hire | |
| Other than motors | 7.60 |
| Motors | 4.22 |
| Asset Description | Straight Line Depreciation (%) |
|---|---|
| Communication equipment | |
| Radio and high frequency carrier system | 6.33 |
| Telephone lines and telephones | 6.33 |
| Fibre Optic | 6.33 |
| I.T Equipment and software | 15.00 |
| Any other assets not covered above | 4.22 (or as approved by the Commission considering asset life and residual value) |
By Order of the Commission,
R.P.Nayak,
Secretary
Jharkhand State Electricity Regulatory Commission