Logo of the Uttarakhand Electricity Regulatory Commission (UERC) featuring a stylized mountain peak with a sun and a river flowing at its base.
रुड़की, शनिवार, दिनांक 22 सितम्बर, 2018 ई० (भाद्रपद 31, 1940 शक सम्वत्)
नियम, कार्य-विधियां, आज्ञाएं, विज्ञप्तियां इत्यादि जिनको उत्तराखण्ड के राज्यपाल महोदय, विभिन्न विभागों के अध्यक्ष तथा राजस्व परिषद् ने जारी किया
September 06, 2018
No. F-9 (28)/RG/UERC/2018/815 – In exercise of the powers conferred under section 61(h), 86(1)(e) read with section 181 (zd) & (zp) of the Electricity Act, 2003, and all other powers enabling it in this behalf, and after previous publication, the Uttarakhand Electricity Regulatory Commission hereby makes the following regulations, namely:
Provided that in cases of Wind, Small Hydro projects, Biomass power based on Rankine cycle, Non-Fossil Fuel based cogeneration projects, Solar PV, Canal Bank & Canal Top solar PV, Solar Thermal power projects, Grid Interactive Roof Top and Small Solar PV plants, Biomass gasifier and Biogas, Municipal Solid Waste and Refuse Derived Fuel based power project these Regulations shall apply subject to the fulfillment of eligibility criteria specified in Regulation 4 of these Regulations;
Provided further that Regulations in Chapter 4 & 5 (except clause (B) & (C) of sub-Regulation (1) of Regulation 26) of these Regulations shall not be applicable for generating stations commissioned prior to coming into effect of these Regulations and their existing tariffs shall continue to be applicable;
Provided also that clause (d) of sub-Regulation (3) of Regulation 10, 2nd & 3rd proviso of sub-Regulation 7 of Regulation 14 shall be applicable to such stations commissioned prior to coming into effect of these Regulations;
Provided that the tariff computation norms shall be in accordance with the Regulations prevalent during the year of commissioning of those stations;
Provided also that normative levelised tariff of 12 paise/unit, over and above the generic tariff, for solar thermal/PV generating stations as specified in Regulation 15(1)(c) shall also be applicable to such stations commissioned prior to coming into effect of these Regulations;
Provided also that the Regulations other than those in Chapter 4 and 5 shall apply to other generating stations located in the State of Uttarakhand, which are based on Renewable Sources of Energy including non-fossil fuel based Co-generation and which transmit and/or supply electricity to any person other than the distribution licensee of the State utilizing State Transmission and/or Distribution System.
Provided that implementation of Canal Bank and Canal Top Solar PV Plants by the eligible government organization (as specified by MNRE) and implementation of solar PV plants by eligible government organization shall be done through tariff based competitive bidding process. In such cases PPA for sale of power from these plants shall be signed with distribution licensee at a tariff which shall be 10% higher than the tariff quoted by L-1 bidder;
Provided further that in no case PPA for purchase of power by the distribution licensee shall be executed at a tariff exceeding the ceiling tariff as specified by the Commission in accordance with the regulations.
(1) Unless the context otherwise requires, the words used in these Regulations shall have the following meaning:
(a) "Act" means the Electricity Act, 2003 (36 of 2003);
(g) "Biogas" means a gas created when organic matter like crop residues, sewage and manure breaks down in an oxygen-free environment (ferments);
(h) "Capacity Utilisation Factor (CUF)" shall mean the total energy sent out during the period expressed as a percentage of installed capacity reduced by the normative auxiliary consumption in that period.
$$CUF = \frac{ESO \times 10^7}{IC \times (100 - AUX) \times H} %$$
Where,
ESO-Energy Sent Out Ex-bus, i.e. at interconnection point, in MU during the period,
IC- Installed capacity in MW,
AUX - % Normative Auxiliary Consumption
H - Number of hours in the period
generator on achieving maximum continuous rating through a successful trial run and in relation to the generating station, the date of commercial operation means the date of commercial operation of the last unit or block of generating station and expression 'commissioning' shall be construed accordingly.
Provided that in case of Small Hydro Plants the date of commissioning shall not be linked to achieving maximum continuous rating, nevertheless the generator will have to demonstrate the same within three years of commissioning.
Provided further that in case of Solar PV plant, date of commercial operation or Commissioning (CoD) shall be considered as the date of first injection of power into the licensee's grid after completion of project in all respect subsequent to compliance of all the following pre-requisites:
by the exercise of reasonable care and due diligence, that party is not able to prevent, including, without limiting the generality of the foregoing:
i. Acts of God like lightning, landslide, storm, action of the elements, earthquakes, flood, drought and natural disaster or exceptionally adverse weather conditions;
(t) "Grid interactive roof top and small solar PV plants" means Solar PV plants installed on the roof of buildings or premises thereof and connected to the grid.
(u) "Gross Calorific Value" or "GCV" in relation to a fuel used in generating station means the heat produced in kCal by complete combustion of one kilogram of solid fuel or one litre of liquid fuel or one standard cubic meter of gaseous fuel, as the case may be;
(v) "Gross Station Heat Rate" or "GSHR" means the heat energy input in kCal required to generate one kWh of electrical energy at generator terminals of a thermal generating station;
(w) "Hybrid Solar Thermal Power Plant" means the solar thermal power plant that uses other forms of energy input sources alongwith solar thermal energy for electricity generation, and wherein not less than 75% of electricity is generated from solar energy component.
(x) "Hybrid Wind Solar Power Plant" means the hybrid plant where Solar photovoltaic (PV) array coupled with a wind turbine and configured to operate at the same point of grid connection.
(y) "Indian Electricity Grid Code (IEGC)" means the Grid Code specified by the Central Electricity Regulatory Commission under clause (h) of sub-section (1) of section 79 of the Act;
(z) "Infirm Power" means electricity generated during trial runs prior to commercial operation of a unit of a generating station;
(aa) "Installed Capacity" or "IC" means the summation of the name plate capacities of the units in the generating station or the capacity of the generating station (reckoned at the generator terminals);
(bb) "Inter-connection Point" in respect of all the RE based generating stations, except Grid interactive Roof Top & Small Solar PV Power Projects, shall mean interface point of line isolator on outgoing feeder on HV side of generator transformer in the switching year of renewable energy generating facility with the transmission system or distribution system.
Provided that in respect of Grid interactive rooftop & Small Solar PV projects, Inter-connection Point shall mean the interface of solar power generation facility under net metering arrangement with the network of licensee and shall normally be the point where export/import meter is installed to measure the energy transfer between the licensee and the eligible consumer.
(cc) "MNRE" means the Ministry of New and Renewable Energy of the Government of India;
(dd) "Municipal solid waste" means and includes commercial and residential wastes generated in a municipal or notified areas in either solid or semi-solid form excluding industrial hazardous wastes but including treated bio-medical wastes;
(ee) "Non-fossil Fuel Based Co-generation" means the process in which more than one form of energy (such as steam and electricity) are produced in a sequential manner by use of biomass provided the project may qualify to be a co-generation project if it fulfills the eligibility criteria as specified in Regulation 4(2)(e).
(ff) "Open Access" means the non-discriminatory provision for the use of transmission lines or distribution system or associated facilities with such lines or system by any licensee or consumer or a person engaged in generation in accordance with the regulations specified by the Appropriate Commission;
(gg) "Open Access Regulations" means the Uttarakhand Electricity Regulatory Commission (Terms and Conditions of Intra-State Open Access) Regulations, 2015 as amended from time to time;
(hh) "Operation and Maintenance Expenses" or "O&M Expenses" means the expenditure incurred in operation and maintenance of the generating station or part thereof, including the expenditure on manpower, repairs, spares, consumables, insurance and overheads;
(ii) "Peak Hours/Off Peak Hours" means particular hours of the day as may be decided by the Commission from time to time;
(jj) "Performance Ratio" (PR) means the ratio of plant output versus installed plant capacity at any instance with respect to the radiation measured.
$$PR = \frac{\text{Measure output in kW}}{\text{Installed Plant capacity in kW}} \times \frac{1000 \text{ W/m}^2}{\text{Measured radiation intensity in W/m}^2}$$
(kk) "Power Purchase Agreement" or "PPA" means a long term agreement between a generating company and a distribution licensee for supply of power on the terms and conditions specified therein and with the provision that the tariff for sale of power shall be as determined by the Commission from time to time;
(ll) "Premises" means the land, building or infrastructure or part or combination thereof including the rooftops or/and elevated areas owned by the Eligible Consumer;
(mm) "Project/Plant" means a generating station and the evacuation system upto inter-connection point, as the case may be, and in case of a small hydro generating station includes all components of generating facility such as dam, intake water conductor system, power generating station and generating units of the scheme, as apportioned to power generation;
(nn) "Refuse Derived Fuel" or RDF means segregated combustible fraction of solid waste other than chlorinated plastics in the form of pellets or fluff produced by drying, de-stoning, shredding, dehydrating, and compacting combustible components of solid waste that can be used as fuel;
(oo) "Renewable Energy" means grid quality electricity generated from renewable energy sources.
(pp) "Renewable Energy Based Generating Stations and Non-fossil Fuel Based Co-generating Stations" means the power plants other than the conventional generating stations generating grid quality electricity from Renewable Energy Sources.
(qq) "Renewable Energy Sources" means renewable sources such as small hydro, wind, solar including integration with combined cycle biomass, bio fuel co-generation, urban or municipal waste and other such sources as approved by MNRE.
(rr) "Small Hydro Plant" means Hydro Power projects with station capacity/installed capacity upto and including 25 MW.
(ss) "Solar Photo Voltaic (PV) Power Project" means the project that uses sunlight for direct conversion into electricity through photovoltaic (PV) technology.
(tt) "Solar PV power plants on Canal Bank" means the Solar PV power plants installed on the banks of the canals.
(uu) "Solar PV Power Plants on Canal Top" means the Solar PV power plants installed on the top of the canals.
(vv) "Solar Thermal Power Project" means the project that uses sunlight for conversion into electricity through concentrated Solar Power Technology based on either line focus or point focus principle.
(ww) "Saleable Energy" means the quantum of energy available for sale (ex-bus) after allowing for free energy, if any, to the home State;
(xx) "State Grid Code" means the Uttarakhand Electricity Regulatory Commission (State Grid Code) Regulations, 2016 specified by Uttarakhand Electricity Regulatory Commission under clause (h) of sub-section (1) of section 86 of the Act;
(yy) "Tariff period" means the period for which tariff is to be determined by the Commission on the basis of norms specified under these Regulations;
(zz) "Third party owner" means a developer who generates solar energy from its plant established in the Premises of Eligible Consumer and who has entered into a lease/commercial agreement with such Eligible Consumer;
(aaa) "Useful Life" in relation to a unit of a generating station including evacuation system shall mean the following duration from the date of commercial operation (CoD) of such generation facility, namely:-
| (i) Wind energy power project | 25 years |
| (ii) Biomass power project including Municipal Solid Waste (MSW) and Refuse Derived Fuel (RDF) based power projects With rankine cycle technology. |
20 years |
| (iii) Non-fossil fuel cogeneration project | 20 years |
| (iv) Small Hydro Plant | 35 years |
| (v) Solar PV/Solar thermal/Grid interactive Rooftop and small Solar PV plants/ Solar PV power plants on Canal bank/Canal top. |
25 years |
| (vi) Biomass Gasifier based power project | 20 years |
| (vii) Biogas based power project | 20 years |
(bbb) "Year" means a financial year.
Topping cycle mode of co-generation - Any facility that uses non-fossil fuel input for the power generation and also utilizes the thermal energy generated for useful heat applications in other industrial activities simultaneously.
Provided that for the co-generation facility to qualify under topping cycle mode, the sum of useful power output and one half the useful thermal output be greater than 45% of the facility's energy consumption, during season.
Explanation- For the purposes of this clause,
(i) 'Useful power output' is the gross electrical output from the generator. There will be an auxiliary consumption in the cogeneration plant itself (e.g. the boiler feed pump and the FD/ID fans). In order to compute the net power output it would be necessary to subtract the auxiliary consumption from the gross output. For simplicity of calculation, the useful power output is defined as the gross electricity (kWh) output from the generator.
(ii) 'Useful Thermal Output' is the useful heat (steam) that is provided to the process by the cogeneration facility.
(iii) 'Energy Consumption' of the facility is the useful energy input that is supplied by the fuel (normally bagasse or other such biomass fuel).
(iv) 'Topping cycle' means a cogeneration process in which thermal energy produces electricity followed by useful heat application in industrial activities.
(f) Biomass Gasifier based Power Project - The project shall qualify to be termed as a biomass gasifier based power project, if it is using new plant and machinery and having a Grid connected system that uses 100% producer gas engine, coupled with gasifier technologies approved by MNRE.
(g) Biogas based Power Project - The project shall qualify to be termed as a biogas based power project, if it is using new plant and machinery and having grid connected system that uses 100% Biogas fired engine, coupled with Biogas technology for co-digesting agriculture residues, manure and other bio waste as may be approved by MNRE.
(h) Municipal solid waste based power projects - The project shall qualify to be termed as a Municipal solid waste based power project, if it is using new plant and machinery based on Rankine cycle technology and using Municipal solid waste as fuel sources.
(i) Refuse derived fuel based power projects - The project shall qualify to be termed as a Refuse derived fuel based power project, if it is using new plant and machinery based on Rankine cycle technology and using Refuse derived fuel as fuel sources.
(j) Hybrid Wind-Solar power Plant- The project shall qualify to be termed as a hybrid Wind-Solar power plant, if Solar photovoltaic (PV) array coupled with a wind turbine and configured to operate at the same point of grid connection.
(3) Any new source or technology would qualify as 'renewable energy', only after such source/ technology is based on scientifically proven technology approved by MNRE or any competent authorities under the central ministry. Further, the Commission shall determine tariffs separately for each technology after the approval of such scientifically proven technology by competent authority under the central ministry.
Provided that in case the generator is having more than one generating station in operation, it shall maintain and submit plant wise details of O&M expenses alongwith the audited accounts on yearly basis to the Commission.
(e) Shall establish a communication and data transfer system with State Load Dispatch Centre and Co-ordinate with State Load Dispatch Centre and the Regional Load Dispatch Center in respect to:
(3) The RE Based Generating Stations and Co-generating Stations shall abide by the grid discipline and install adequate protection equipment for safety of its system and human life. It shall not be entitled for any compensation in the event of grid failure or any interruptions or damage to the plant or its associated sub-station and transmission line on account of any occurrence in the grid.
(4) The RE Based Generating Stations and Co-generating Stations shall establish, operate and maintain generating station, the associated substation and dedicated transmission lines, if it exercises the option to establish the line. These shall be in accordance with:
(5) The RE Based Generating Stations and Co-generating Stations shall ensure the compliance of the 'IEGC', the State Grid Code and the Distribution Code as amended from time to time.
(6) The RE Based Generating Stations and Co-generating Stations shall ensure compliance of any general or specific direction issued and regulations made by the Commission for the generating companies.
(7) All Power Purchase Agreements (PPAs) signed by the generating stations existing on the date of notification of these regulations shall be amended in accordance with these regulations, if inconsistent with these Regulations, and such amended PPAs shall be valid for entire life of the RE Based Generating Stations and Co-generating Stations.
(8) The RE Based Generating Stations and Co-generating Stations shall coordinate with State Transmission Utility/Distribution Licensee for the purpose of planning and coordination relating to intra-state transmission/distribution system as provided under the Act.
(9) The RE Based Generating Stations and Co-generating Stations shall be under obligation to comply with the directions issued to it by the State Load Dispatch Centre failing which the plant shall be liable for appropriate action under the Act.
(10) The RE Based Generating Stations and Co-generating Stations shall pay fee and charges to the State Load Dispatch Centre as may be specified or directed by the Commission from time to time.
(11) In case of dispute with reference to quality of electricity or safe, secure and integrated operation of the grid or in relation to any direction issued by the State Load Dispatch Centre, the matter shall be referred to the Commission for adjudication.
distribution licensee is not willing to purchase power from such generator it shall intimate the same to the generating company within one month of offer made by it.
Provided that where a grid interactive roof top and small Solar PV plant, is installed in the Premises, by a third party who intends to sell net energy (i.e. after adjustment of entire consumption of owner of the premise) to the distribution licensee, a tripartite agreement will have to be entered into amongst the third Party, the Eligible Consumer and such Distribution Licensee.
Provided that the 'open access' shall be allowed subject to the availability of surplus capacity in the State Transmission/Distribution System.
| Year | Renewable Purchase Obligation -Non-Solar | Renewable Purchase Obligation-Solar |
|---|---|---|
| 2018-19 | 10.25% | 6.75% |
| 2019-20 | 10.25% | 7.25% |
| 2020-21 | 10.25% | 8.75% |
| 2021-22 | 10.50% | 10.50% |
| 2022-23 | 11.00% | 11.00% |
Percentage RPO as stipulated above denotes Minimum Quantum of purchase from non-fossil fuel based co-generation and generation of electricity from renewable energy sources' as a percentage of total energy purchased from all sources/generated by the Obligated Entity during the year for own consumption.
Where, total energy purchased for different obligated entities shall be as under:
Provided further that Non-Solar & Solar RPO shall be applicable on total energy purchased/generated of electricity by an obligated entity excluding energy purchased/generated from hydro sources of power;
Provided that on achievement of Solar RPO compliance to the extent of 85% and above, remaining shortfall if any, can be met by excess Non-Solar energy purchased beyond specified Non-Solar RPO for that particular year;
Provided further that on achievement of Non-Solar RPO compliance to the extent of 85% and above, remaining shortfall if any, can be met by excess Solar energy purchased beyond specified Solar RPO for that particular year.
Provided that the option of seeking projects specific tariff shall not be available to Grid interactive roof top and small solar PV plants, Solar PV Power Plants, Canal Top & Canal Bank based Solar PV Power Plants, Solar Thermal Plants, Wind Energy Power Plants and other RE based power projects having installed capacity upto 1 MW.
Provided that if generating company does not give its option to the distribution licensee within above stipulated time, generic tariff shall be applicable based on the date of commissioning of the project or commissioning of the first unit, in case of multiple units.
(3) Project Specific Tariff, on case to case basis, shall be determined by the Commission in the following cases:
(c) Projects having old plant and machinery or equipment;
(d) The RE generating company for meeting the expenditure on Renovation, Modernisation and Up-gradation (RMU) for the purpose of extension of life beyond the useful life of its RE based power plant shall make an application before the Commission for in-principle approval of the proposal alongwith a DPR giving complete scope, cost-benefit analysis, estimated life extension from a reference date, financial package, phasing of expenditure, schedule of completion and other details as required by the Commission and the Commission while fixing their tariffs, shall be guided by the tariff norms specified in the Regulations based on actual capital cost subsequent to the completion of the RMU activities and such other factors considered relevant by the Commission;
(e) Any other new renewable energy technologies approved by MNRE.
Provided that the Commission while determining the Project Specific Tariff shall be guided by the provisions of Chapter 4 & 5 of these Regulations for technologies specifies therein.
Provided that the benchmark capital cost of Solar PV, Canal Bank & Canal Top Solar PV, Solar Thermal, Municipal Solid Waste based power projects, Refuse Derived Fuel based power projects and Grid interactive Roof Top and Small Solar PV projects may be reviewed annually by the Commission.
Provided further that the tariff determined as per these Regulations for the RE projects commissioned during the Control Period, shall continue to be applicable for the entire Tariff Period.
Provided that for Project Specific Tariff determination, the RE Based Generating Stations and Co-generating Stations shall submit the DPR and the break-up of Capital Cost items along with its petition.
Provided that the RE Based Generating Stations and Co-generating Stations shall be required to make a fresh application for determination of final tariff based on actual capital expenditure incurred up to the date of commercial operation or commissioning of the generating station within 18 months from the actual CoD.
(3) A petition for determination of project specific tariff shall be accompanied by such fee as specified in the UERC (Fee and Fines) Regulations, 2002, as amended from time to time, and shall be accompanied by:
(a) Information in forms 1.1, 1.2, 2.1 and 2.2 as the case may be, and as appended in these regulations;
(e) Auditor's certificate indicating year wise and component/asset wise expenditure incurred towards project cost and IDC & IEDC alongwith duly audited and certified copies of annual accounts by the statutory auditors.; and
(4) The proceedings for determination of tariff shall be in accordance with the UERC (Conduct of Business Regulations), 2014.
Provided that for renewable energy technologies having fuel cost component, like biomass/biogas/biomass gasifier power projects, Refuse derived fuel and non-fossil fuel based cogeneration, tariff with two components, namely fixed cost component and fuel cost component, shall be determined.
Provided that the generic tariff for supply of electricity from the plant, having more than one unit commissioned during currency of different control period, shall be based on weighted average of the tariffs specified under different Regulations for the total capacity of the plant.
Provided that for renewable energy technologies having tariff (in Rs./kWh) with two components, for fixed cost component tariff may be determined on levelised basis considering the year of commissioning of the project while the fuel cost component shall be specified on year of operation basis.
Provided that where project specific tariff is being determined the revenue generated from infirm power shall be used to reduce the capital cost of the project after giving credit for cost of fuel consumed, wherever applicable;
Provided that any additional expenditure of capital nature which becomes necessary for restoration works only on account of damages caused by natural calamities (but not due to flooding of power house attributable to the negligence of the generating company), after prudence check by the Commission, shall be allowed as additional
capitalisation after duly adjusting the proceeds from any insurance scheme for all the generating stations covered under these Regulations. For additional capital expenditure admitted, as above, appropriate adjustment in tariff shall be allowed for balance life of that project based on the norms given in Chapters 4 & 5 of the Regulations;
Provided that additional capitalisation on this account would only be allowed if appropriate and adequate insurance cover was available for the generating station at the time of occurrence of natural calamities referred to above. The generating company shall intimate the Commission and Distribution Licensee within seven days from the occurrence of any such force majeure event resulting into shut down of plant. The Commission may in such case direct the distribution licensee and State nodal agency to visit the damaged plant and assess the nature & type of damages and restoration works required in coordination with the generator/developer.
Provided that if the delay is not attributable to the generating company and is due to uncontrollable factors, such expenditures may be allowed after due prudence check;
Provided further that where the delay is attributable to an agency or contractor or supplier engaged by the generating company, the liquidated damages recovered from such agency or contractor or supplier shall be kept in view while computing the capital cost.
The said normative tariff for evacuation infrastructure has been arrived at considering the cost of normative line length of 10 kms. (including cost of terminal equipments) for different capacities of generating stations as per normative cost given below:
| (i) Upto 3MW, 11 kV S/C | - Rs. 44 lakh |
| (ii) Above 3MW and upto 13 MW, 33 kV S/C | - Rs. 85 lakh |
| (iii) Above 13 MW and upto 25 MW, 33 kV 2 x S/C or DC | - Rs. 170 lakh |
Provided that in case more than one generating stations construct, at its own cost, a common evacuation infrastructure including pooling switching station, in accordance with Regulation 41 of these Regulations, for evacuation of power of their generation, then the above normative levelised tariff shall be apportioned among all such generating stations on the basis of their installed capacity.
Provided that the distribution licensee will be required to exercise the option within one year from the date of commissioning of the generating station(s).
The debt-equity ratio for generic and project specific tariff shall be as follows:
If the equity actually deployed is more than 30% of the capital cost, equity in excess of 30% shall be treated as normative loan:
Provided that where equity actually deployed is less than 30% of the capital cost, the actual equity shall be considered for determination of tariff;
Provided further that the equity invested in foreign currency shall be designated in Indian rupees on the date of each investment;
Provided further that it shall be assumed that the original repayments shall not be affected by this prepayment.
For the purpose of computation of project specific tariff, interest rate shall be considered as lower of the actual interest payable to the financial institutions or the average State Bank of India (SBI) Marginal Cost of Funds based Lending Rate (MCLR) (one year tenor) prevalent during the last available six months plus 300 basis points.
While calculating project specific tariff, notwithstanding any moratorium period availed by the generating company, the repayment of loan shall be considered from the first year of commercial operation of the project and shall be equal to the annual depreciation allowed or actual repayment made, whichever is higher.
(1) The Working Capital requirement in respect of Wind energy projects, Small hydro power, Solar PV, Canal Bank and Canal Top Solar PV, Solar thermal and Grid interactive Roof Top and Small solar PV power projects shall be computed in accordance with the following:
(a) Operation & Maintenance expenses for one month;
(b) Receivables equivalent to 2 (Two) months of energy charges for sale of electricity calculated on the normative CUF:
Provided that for determination of project specific tariff, sale of electricity will be calculated based on the CUF envisaged in the approved DPR or the normative CUF specified for the relevant technology under Chapter 5, whichever is higher.
(c) Maintenance spare @ 15% of operation and maintenance expenses.
(2) The Working Capital requirement in respect of biomass power projects, municipal solid waste based power projects, refused derived fuel based power projects and non-fossil fuel based co-generation projects shall be computed in accordance with the following:
(a) Fuel costs for four months equivalent to normative CUF;
(b) Operation & Maintenance expense for one month;
(c) Receivables equivalent to 2 (Two) months of fixed and variable charges for sale of electricity calculated on the normative CUF:
Provided that for determination of project specific tariff, CUF will be taken as the CUF envisaged in the approved DPR or the normative CUF specified for the relevant technology under Chapter 5, whichever is higher.
(1) Operation and maintenance expenses for the year of commissioning shall be determined based on normative O&M expenses specified by the Commission under Chapter 5 for different technologies for the first Year of Control Period, i.e. for FY 2018-19. These expenses shall be escalated @ 5.72% p.a. to arrive at O&M expenses for the ensuing years.
(2) Normative O&M expenses allowed for the year of commissioning shall be escalated at the rate of 5.72% p.a. to determine the O&M expenses for the different years of the Tariff Period.
In case the payment of bills is delayed beyond a period of 60 days from the date of billing, a late payment surcharge at the rate of 1.25% per month or part thereof shall be levied by the generating company.
The Commission shall take into consideration any incentive or subsidy offered by the Central or State Government, including accelerated depreciation benefit if availed by the generating
company, for the renewable energy power plants while determining the tariff under these Regulations.
Provided that only 75% of the capital subsidy for the financial year of commissioning as per applicable scheme of MNRE shall be considered for tariff determination.
Provided that the following principles shall be considered for ascertaining income tax benefit on account of accelerated depreciation, if availed, for the purpose of tariff determination:
Provided further that where Central Government or the State Government has notified any Generation Based Incentive Scheme for a particular kind of renewable technology such technology based generating stations shall be assumed to have availed the benefit of such a scheme and their tariffs shall automatically be treated as reduced by the amount of GBI per unit.
Tariff determined under these regulations shall be including direct taxes on income but exclusive of other taxes and duties as may be levied by the appropriate Government.
Provided that the taxes, duties and cess levied by the appropriate Government other than direct taxes shall be allowed as pass through on actual incurred basis.
A. For generators opting generic tariff:
(a) Till the actual CUF is less than or equal to annual CUF of 40%, tariffs would be payable at the levelised generic rates specified in the Regulations arrived at based on the normative CUF of 40%.
(b) For generation beyond annual CUF of 40%, following will apply:
(i) For generation beyond annual CUF of 40% but upto annual CUF of 45%, tariff shall be Rs. 1.50/kWh.
B. For generators opting for project specific tariffs, the tariff for generation beyond the applicable CUF (i.e. the CUF envisaged in the approved DPR or the normative CUF specified for the relevant technology under Chapter 5, whichever is higher), shall be allowed to be recovered at the project specific tariff approved by the Commission.
C. For additional capitalization as allowed by the Commission for restoration work, the tariff for generation beyond the applicable CUF to the generating station shall be allowed to be recovered at the project specific tariff approved by the Commission for such restoration work.
The annual CUF shall be calculated in accordance with the principles specified in Regulation 3(1)(h) of the Regulations.
Since RE Sources are dependent on vagaries of nature and are of small capacities, the principle of merit order dispatch/purchase shall not be applicable to supply of power from such sources to the distribution licensee or local rural grids within the State, i.e. they shall be treated as must run stations.
The technology specific parameters for determination of generic tariffs for Small Hydro Generating Stations commissioned or to be commissioned on or after 01.04.2018 shall be as follows:
| Project Size | Capital Cost | O&M Expenses for year of commissioning | Capacity Utilization Factor* | Auxiliary Consumption |
|---|---|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | (%) | (%) | |
| Upto 5 MW | 1000 | 45.00 | Generic Tariff- 40% Project Specific- 45% |
1% |
| > 5 MW & upto 15 MW | 950 | 40.38 | ||
| > 15 MW & upto 25 MW | 900 | 36.00 |
* for the recovery of Annual Fixed Charges.
NOTE: For the purpose of this Regulation, normative CUF is based on Energy Sent Out at interconnection point and for tariff purposes energy net of free power to the home State, if any, committed by the developer shall be factored. For generic tariff determination, home State share has been taken as 18% from 16th year onwards.
| Biomass Rankine Cycle Projects | Capital Cost for the year of commissioning of project (Rs. Lakh/MW) |
|---|---|
| Projects [other than rice straw and juliflora (plantation) based projects] with water cooled condenser | 559.03 |
| Projects [other than rice straw and juliflora (plantation) based projects] with air cooled condenser | 600.44 |
| For rice straw and juliflora (plantation) based projects with water cooled condenser | 610.80 |
| For rice straw and juliflora (plantation) based projects with air cooled condenser | 652.20 |
Normative O&M expenses for the first year of the Control period shall be Rs. 42.29 Lakh/MW. The Normative O&M expenses allowed for the year of commissioning shall be escalated at the rate of 5.72% per annum for subsequent years.
The Station Heat Rate of biomass power projects shall be
(1) Threshold CUF for determining fixed charge component of Tariff shall be:
(i) During Stabilisation: 60%,
(ii) During the remaining period of the first year (after stabilization): 70%
(iii) From 2nd year onwards: 80%
(2) The stabilization period shall not be more than 6 months from the date of commissioning of the project.
(1) For the projects using water cooled condenser:
(i) During first year of operation: 11%
(ii) From 2nd year onwards: 10%
(2) For the project using air cooled condenser:
(i) During first year of operation: 13%
(ii) From 2nd year onwards: 12%
Provided that for the biomass power projects commissioned on or before 31.03.2018, the use of fossil fuels to the extent of 15% in terms of calorific value on annual basis shall be allowed for the tariff period from the date of commissioning.
(2) The Project developer shall furnish a monthly fuel usage statement and monthly fuel procurement statement duly certified by Chartered Accountant to the beneficiary (with a copy to appropriate agency appointed by the Commission for the purpose of monitoring the fossil and non-fossil fuel consumption) for each month, alongwith the monthly energy bill.
(3) Non-compliance with the conditions of fossil fuel usage by the project developer, during any financial year, shall result in withdrawal of applicability of tariff as per these Regulations for such biomass based power project. However, such defaulting biomass power project shall continue to sell power to the distribution licensee and the rate during the financial year in which default occurred shall be the rate lower by Rs. 1/kWh of the applicable variable tariff specified by the Commission.
The Calorific Value of the biomass fuel used for the purpose of determination of tariff shall be at 3100 kCal/kg.
Biomass Fuel Price for the first year of the Control Period, i.e FY 2018-19 shall be taken as Rs. 2355/MT, unless specifically reviewed by the Commission. For each subsequent year of the Tariff Period, the normative escalation factor of 5% on previous year's fuel cost shall be applicable to determine the fuel cost for different years of the Tariff Period.
| Capital Cost | O&M Expenses for year of commissioning | Station Heat Rate | Calorific value of fuel | Auxiliary Consumption | Capacity Utilization Factor |
|---|---|---|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | (kCal / kWh) | (kCal/kg) | ||
| 492.50 | 22.35 | 3600 | 2250 | 8.5% | 45% |
(3) Fuel Cost (P) for the first year of the Control Period, i.e. FY 2018-19 shall be taken as Rs. 1954/MT, unless specifically reviewed by the Commission. For each subsequent year of Tariff Period, the normative escalation factor of 5% on previous year's fuel shall be applicable to determine the fuel cost for different year of Tariff Period.
(4) For use of biomass other than bagasse in co-generation projects, the biomass prices as specified under Regulation 29(1)(h) shall be applicable.
| Type of Project | Capital Cost (Rs. Lakh/MW) |
O&M Expenses for year of commissioning (Rs. Lakh/MW) |
Specific Fuel Consumption Kg/kWh |
Auxiliary Consumption |
Capacity Utilization Factor |
|---|---|---|---|---|---|
| Pine leaves based Biomass Gasifier projects |
625.00 | 100.00 | 1.50 | 10% | 85% |
| Other Biomass Gasifier Projects |
592.88 | 55.85 | 1.25 |
(2) Fuel Price (P) for the first year of the Control Period, i.e. FY 2018-19 shall be taken as Rs. 2355/MT for all type of Biomass Gasifier based power projects, unless specifically reviewed by the Commission. For each subsequent year of the Tariff Period, the normative escalation factor of 5% on previous year's fuel cost shall be applicable to determine the fuel cost for different years of the Tariff Period.
(3) Fuel Mix
(a) The Biomass Gasifier based Power Plant shall be designed in such a way that it uses different types of non-fossil fuels available within the vicinity of Biomass Power Project such as crop residues, agro-industrial residues, forest residues etc. and other biomass fuels as may be approved by MNRE.
(b) The Biomass Gasifier based Power Generating Companies shall ensure fuel management plan to ensure adequate availability of fuel to meet the respective project requirements.
| Capital Cost (Rs. Lakh/MW) |
O&M Expenses for year of commissioning (Rs. Lakh/MW) |
Specific Fuel Consumption (kg/kWh) |
Auxiliary Consumption |
Capacity Utilization Factor |
|---|---|---|---|---|
| 1185 | 55.85 | 3.00 | 12% | 90% |
Norms for Solar Photovoltaic (PV) power project under these Regulations shall be applicable for grid connected PV systems that directly convert solar energy into electricity and are based on the technologies such as crystalline silicon or thin film etc. as may be approved by MNRE. The technology specific parameters for determination of generic tariffs for Solar PV Power Projects commissioned or to be commissioned on or after 01.04.2018 shall be as follows:
| Capital Cost | O&M Expenses for year of commissioning | Capacity Utilization |
|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | Factor |
| 388.19 | 12.30 | 19 % |
Norms for canal bank Solar PV Power Plants and canal top Solar PV Power Plants under these Regulations shall be applicable for grid connected PV systems that directly convert solar energy into electricity and are based on the technology specific parameters for determination of generic tariffs for such power projects commissioned or to be commissioned on or after 01.04.2018 shall be as follows:
| Type Solar PV Plant | Capital Cost | O&M Expenses for year of commissioning | Capacity utilization Factor |
|---|---|---|---|
| (Rs. Lakh/ MW) | (Rs. Lakh/MW) | ||
| Canal Bank Solar PV Plant | 600.00 | 12.30 | 19% |
| Canal Top Solar PV Plant | 625.00 |
Norms for Solar thermal power under these Regulations shall be applicable for Concentrated solar power (CSP) technologies viz. line focusing or point focusing, as may be approved by MNRE, and uses direct sunlight, concentrating it several times to reach higher energy densities and thus higher temperatures whereby the heat generated is used to operate a conventional power cycle to generate electricity. The technology specific parameters for determination of generic tariffs for Solar Thermal Power Projects commissioned or to be commissioned on or after 01.04.2018 shall be as below:
| Capital Cost | O&M Expenses for year of commissioning | Capacity Utilization | Auxiliary |
|---|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | Factor | Consumption |
| 1200 | 16.77 | 23% | 10% |
| Project Size | Capital Cost | O&M Expenses for year of commissioning | Capacity Utilization Factor |
|---|---|---|---|
| (Rs./kW) | (Rs./kW) | ||
| Upto 10 kW | 47153 | 1627 | 19 % |
| >10 kW & upto 100 kW | 43224 | 1448 | |
| >100 kW & upto 500 kW | 40612 | 1320 | |
| >500 kW and upto 1 MW | 39135 | 1230 |
Provided that the maximum Rooftop Solar PV and Small Solar PV plants installed capacity at any Eligible Consumer's premises shall be upto a maximum of 80% of consumer's sanctioned load/contract demand;
Provided that in case of Domestic Consumer, such installed capacity of Roof Top and Small Solar PV Plants shall be irrespective of consumer's sanctioned load/contract demand;
Provided, the maximum installed capacity of rooftop PV solar power plant & small solar PV plant at the premises of eligible consumer shall not be more than 1 MW.
Provided that such eligible consumer shall be exempted from payment of monthly minimum charges/monthly minimum consumption guarantee charges, if any, equivalent to the capacity of Roof Top Solar PV plant installed at the premises;
Provided further that no open access charges including surcharges shall be leviable on such eligible consumers for the captive use of power.
| Capital Cost | O&M Expenses | Annual Mean Wind Power Density | Capacity Utilization |
|---|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | (W/m 2 ) | Factor |
| 515 | 9.51 | Upto 220 | 22% |
| 221-275 | 24% | ||
| 276-330 | 28% | ||
| 331-440 | 33% | ||
| >440 | 35% |
NOTE:
| Project | Capital Cost | O&M Expenses for year of commissioning | Plant Load Factor | Auxiliary Consumption | Station Heat Rate | Calorific value |
|---|---|---|---|---|---|---|
| (Rs. Lakh/MW) | (Rs Lakh/MW) | kcal/kWh | kcal/kg | |||
| MSW | 1500 | 6% of the project cost for 1 st year and shall be escalated @ 5.72% per annum | 65% during stabilization & first year. 75% from second year onwards. |
15% | 4200 | - |
| RDF | 900 | 6% of the project cost for 1 st year and shall be escalated @ 5.72% per annum | 65% during stabilization & first year. 80% from second year onwards. |
15% | 4200 | 2500 |
NOTE:
The generic tariffs for the above-mentioned technologies are given in Annexure 1.
Provided that no Transmission and Wheeling Charges are payable for sale of electricity to distribution licensee or to local rural grid within the State;
Provided further that where a generating company proposes to supply electricity outside the State, such generating company, in addition to transmission/wheeling charges specified above, shall have to bear the transmission/wheeling charges determined by the Commission on case to case basis for the dedicated lines and substation of the transmission/distribution licensee used only for evacuation of such power;
Provided further that where more than one generating company proposes to supply electricity outside the State over common dedicated transmission/distribution system of transmission/distribution licensee for evacuation of their power, such generating companies, in addition to transmission/wheeling charges specified above, shall have to bear the full transmission/wheeling charges determined by the Commission on case to case basis for such dedicated lines and substation of the transmission/distribution licensee used only for evacuation of such power on pro-rata basis of installed capacity.
Provided further that no losses shall be adjusted in kind for sale of electricity to distribution licensees within the State or to local rural grid.
Provided that any RE based Generating Station having capacity upto 25 MW is willing to connect and evacuate power through 132 kV & above transmission system, it may do so subject to consent of the Transmission Licensee.
Provided further that where more than one RE based Generating Stations having cumulative installed capacity more than 25 MW are located in a cluster/area and for the purpose of evacuation, these generating stations agree to pool their generation at a common pooling switching station to be constructed by them at their own cost and further beyond such pooling switching station, the Transmission Licensee shall provide connectivity at its nearest sub-station. They may further mutually agree to provide connectivity at appropriate voltage level subject to technical feasibility and technical standards for construction of electricity lines and connectivity with the grid as may be specified by CEA.
Provided that such Generating Stations may also get the work of construction of the power evacuation system carried out by State transmission/distribution licensee;
Provided further that the land for extending the bay shall be provided by the owner of the transmission or distribution sub-station, as the case may be, free of cost.
For sale to person other than the Distribution Licensees or to Local Rural Grid principles of optimum scheduling and dispatch as per IEGC and State Grid Code scheme shall apply and for this purpose RE based Generating Stations shall be required to pay such fee to the SLDC as specified under UERC (Terms and Conditions of Intra-State Open Access) Regulations, 2015.
either by two separate meters, the readings of which shall be used in each billing period for settlement on Net basis or alternatively by an export-import type meter suitable for directly measuring the Net exchange.
Provided that Check Meter and related equipments can be procured by such plant owner. However, the cost of Check Meter shall be refunded by the licensee to such plant owner. The cost of the check meter to be refunded would be, lower of the following:
Generating Station shall provide ABT compatible Special Energy Meters at the point of interconnection complying with the Regulation on installation of meters specified by CEA.
The State Load Dispatch Centre shall carry out scheduling and accounting of energy sent out by the generators and the same shall be communicated to the utilities interacting with the grid as per the scheme framed by SLDC in pursuance of the provisions of IEGC, State Grid Code and Open Access Regulations. Billing for open access transactions shall be done in accordance with the Open Access Regulations.
Provided that in case of sale to the distribution licensee of the area, the power purchase agreement may provide for joint meter reading and in such cases, energy accounting and billing shall be done by the generating station in coordination with the concerned distribution licensee.
Provided that in case electricity generated from the plant is being exclusively sold to the State Distribution Licensee, the electricity (in kWh) procured by the Generating Station from the State Distribution Licensee to meet its requirement of his own use or for startup power, will be adjusted from the electricity sold to the Distribution Licensee on month to month basis. The Distribution Licensee shall make the payment for net energy sold to it by the Generating Company, i.e. difference of the total energy injected into the grid and energy drawn from the grid by the Generating Company. In case the energy supplied by the distribution licensee is more than the energy injected by the generating company, the net energy (in kWh) thereof shall be billed by the distribution licensee in accordance with 2nd proviso below;
Provided further that in case electricity generated from the plant is sold to third party other than the Distribution Licensee, then such purchase of electricity by the generating company from the distribution licensee, shall be charged as per the tariff determined by the Commission for temporary supply under appropriate "Rate Schedule of tariff" for Industrial Consumers considering maximum demand during the month as
the contracted demand for that month. The Fixed/Demand charges for that month shall be payable for the number of days during which such supply is drawn. Such Generating Company shall, however, be exempted from payment of monthly minimum charges or monthly minimum consumption guarantee charges or any other charges.
(1) The Generating Stations shall be allowed to bank power within a period of one calendar month, for the purpose of withdrawal of the banked power in the event of emergency or shut down or maintenance of the plant, subject to following conditions:
(j) In case of a Non-fossil fuel based Co-generating Stations, which is not a captive generating plant, the facility of banking shall apply only if it has a PPA with the distribution licensee in the State.
(Applicable only in case of Small Hydro Generating Plants & Solar PV & Solar Thermal Projects)
Provided that the following shall not count towards Deemed Generation:
Any loss in generation due to variations in the voltage beyond the limits specified above shall be reckoned as deemed generation provided such loss of generation results in reduction of more than 25% of capacity output.
(3) The period of outage/interruption on account of such factor(s) specified in sub-Regulation 1 and 2 above, shall be reconciled on monthly basis and the loss of generation at the station towards Deemed Generation after accounting for the events specified under sub-Regulation 1 (i) & (ii) above, shall be computed on following considerations:
(i) The recovery on the above account shall be admissible if the actual energy generated during the year is less than the normative CUF specified in the Regulation for small hydro projects and Solar PV and solar thermal projects (in case of project opting for generic tariff) or the CUF considered for recovery of fixed charges (in case of project specific tariff is applicable) for small hydro projects and solar PV and solar thermal projects. In case the sum of actual energy generated and the deemed generation during the year exceeds the CUF at which the recovery of fixed charges has been envisaged, then the deemed generation alongwith the actual energy generated will be allowed only upto the CUF considered.
(ii) The generation loss towards the Deemed Generation in accordance with sub-Regulation (1) above, if any, during the month shall be considered on the pro-rata basis on the number of hours lost based on the actual average generation achieved during that month divided by the total number of hours available during the month reduced by the number of hours outage/interruption occurred in the system.
(iii) The generation loss towards the Deemed Generation (in MWh) in accordance with sub-Regulation (2) above, if any, during the month shall be considered as the summation of the product of number of hours the variations in voltage beyond the specified limit existed and the Generation lost (in MW) due to the variation in the voltage beyond the specified limit. The Generation lost (in MW) would be the difference between the following:
(a) Minimum of the generation (in MW) before the variation in voltage occurred and the generation (in MW) achieved after 90 minutes immediately after variation in voltage was restored within the specified limit would be treated as the "Actual Generation" during the period when voltage variations occurred; and
Provided that if such variation in voltage continues for the entire month, generation (in MW) before such variation in voltage occurrence would be treated as the "Actual Generation".
(b) The generation achieved during the period when variation in voltages took place.
Provided that any charges paid by the distribution licensee towards deemed generation shall not be allowed as an expense to be pass through in tariffs. The distribution licensee will have to bear such charges;
Provided further that the deemed generation conditions stipulated above shall be applicable only on those Small Hydro projects and Solar PV and Solar Thermal projects who have signed a long term PPA with the distribution licensee;
Provided also that the deemed generation conditions shall be applicable only on the Small Hydro projects and Solar PV and Solar Thermal projects where the evacuation line is connected to 11 kV or higher voltage Grid Sub-station.
Nothing in these regulations shall, expressly or impliedly, bar the Commission dealing with any matter or exercising any power under the Act for which no regulations have been framed, and the Commission may deal with such matters, powers and functions in a manner, as it considers just and appropriate.
If any difficulty arises in giving effect to these regulations, the Commission may, of its own motion or otherwise, by an order and after giving a reasonable opportunity to those likely to be affected by such order, make such provisions, not inconsistent with these regulations, as may appear to be necessary for removing the difficulty.
The Commission, for reasons to be recorded in writing, may vary any of the provisions of these regulations on its own motion or on an application made before it by an interested person.
| Particulars | Upto 5 MW | Above 5 MW & upto 15 MW | Above 15 MW & upto 25 MW |
|---|---|---|---|
| Gross Tariff (CUF@ 40%) | 6.33 | 6.08 | 5.70 |
| Gross Tariff (CUF @ 45%) | 5.63 | 5.40 | 5.07 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 6.89 |
| Less: Acc. Dep. Benefit | 0.30 |
| Net Tariff | 6.59 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 4.44 |
| Less: Acc. Dep. Benefit | 0.17 |
| Net Tariff | 4.27 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.56 | 3.74 | 3.92 | 4.12 | 4.32 | 4.54 | 4.77 | 5.01 | 5.26 | 5.52 | 5.80 | 6.08 | 6.39 | 6.71 | 7.04 | 7.40 | 7.77 | 8.15 | 8.56 | 8.99 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.67 |
| Less: Acc. Dep. Benefit | 0.15 |
| Net Tariff | 3.52 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.42 | 3.59 | 3.77 | 3.96 | 4.15 | 4.36 | 4.58 | 4.81 | 5.05 | 5.30 | 5.57 | 5.84 | 6.14 | 6.44 | 6.77 | 7.10 | 7.46 | 7.83 | 8.22 | 8.63 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 4.27 |
| Less: Acc. Dep. Benefit | 0.11 |
| Net Tariff | 4.16 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.27 | 3.43 | 3.61 | 3.79 | 3.98 | 4.17 | 4.38 | 4.60 | 4.83 | 5.07 | 5.33 | 5.59 | 5.87 | 6.17 | 6.48 | 6.80 | 7.14 | 7.50 | 7.87 | 8.27 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 2.93 |
| Less: Acc. Dep. Benefit | 0.10 |
| Net Tariff | 2.82 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.27 | 3.43 | 3.61 | 3.79 | 3.98 | 4.17 | 4.38 | 4.60 | 4.83 | 5.07 | 5.33 | 5.59 | 5.87 | 6.17 | 6.48 | 6.80 | 7.14 | 7.50 | 7.87 | 8.27 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 4.30 |
| Less: Acc. Dep. Benefit | 0.21 |
| Net Tariff | 4.09 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 4.52 | 4.75 | 4.99 | 5.24 | 5.50 | 5.77 | 6.06 | 6.37 | 6.68 | 7.02 | 7.37 | 7.74 | 8.12 | 8.53 | 8.96 | 9.40 | 9.88 | 10.37 | 10.89 | 11.43 |
| Particular | Canal bank Solar PV Power Plants |
Canal top Solar PV Power Plants |
|---|---|---|
| (Rs./kWh) | ||
| Gross Tariff | 6.69 | 6.92 |
| Less: Acc. Dep. Benefit | 0.39 | 0.41 |
| Net Tariff | 6.29 | 6.51 |
| Particular | Solar PV Projects | Solar Thermal Projects |
|---|---|---|
| (Rs./kWh) | ||
| Gross Tariff | 4.73 | 14.04 |
| Less: Acc. Dep. Benefit | 0.25 | 0.79 |
| Net Tariff | 4.48 | 13.26 |
| Level of Subsidy | 0% | 30% | 70% | 90% |
|---|---|---|---|---|
| Particulars | Rate of Fixed Charges (Rs./kWh) | |||
| Gross Tariff | 5.93 | 5.18 | 4.18 | 3.76 |
| Less: Acc. Dep. Benefit | 0.31 | 0.26 | 0.18 | 0.13 |
| Net Tariff | 5.62 | 4.92 | 4.00 | 3.63 |
| Level of Subsidy | 0% | 30% | 70% | 90% |
|---|---|---|---|---|
| Particulars | Rate of Fixed Charges (Rs./kWh) | |||
| Gross Tariff | 5.37 | 4.62 | 3.64 | 3.29 |
| Less: Acc. Dep. Benefit | 0.28 | 0.23 | 0.16 | 0.10 |
| Net Tariff | 5.09 | 4.39 | 3.48 | 3.19 |
| Level of Subsidy | 0% | 30% | 70% | 90% |
|---|---|---|---|---|
| Particulars | Rate of Fixed Charges (Rs./kWh) | |||
| Gross Tariff | 4.99 | 4.35 | 3.49 | 3.13 |
| Less: Acc. Dep. Benefit | 0.27 | 0.22 | 0.16 | 0.11 |
| Net Tariff | 4.72 | 4.12 | 3.33 | 3.01 |
| Level of Subsidy | 0% | 30% | 70% | 90% |
|---|---|---|---|---|
| Particulars | Rate of Fixed Charges (Rs./kWh) | |||
| Gross Tariff | 4.77 | 4.15 | 3.32 | 2.97 |
| Less: Acc. Dep. Benefit | 0.26 | 0.22 | 0.15 | 0.11 |
| Net Tariff | 4.51 | 3.93 | 3.17 | 2.86 |
| Particular | Rate of Fixed Charges (Rs./kWh) | ||||
|---|---|---|---|---|---|
| Zone 1 | Zone 2 | Zone 3 | Zone 4 | Zone 5 | |
| Gross Tariff | 4.85 | 4.44 | 3.81 | 3.23 | 3.05 |
| Less: Acc. Dep. Benefit | 0.47 | 0.43 | 0.37 | 0.31 | 0.29 |
| Net Tariff | 4.38 | 4.02 | 3.44 | 2.92 | 2.75 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.05 |
| Less: Acc. Dep. Benefit | 0.10 |
| Net Tariff | 2.95 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.58 | 3.76 | 3.95 | 4.15 | 4.36 | 4.58 | 4.80 | 5.04 | 5.30 | 5.56 | 5.84 | 6.13 | 6.44 | 6.76 | 7.10 | 7.45 | 7.83 | 8.22 | 8.63 | 9.06 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.04 |
| Less: Acc. Dep. Benefit | 0.10 |
| Net Tariff | 2.94 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.52 | 3.70 | 3.88 | 4.08 | 4.28 | 4.49 | 4.72 | 4.95 | 5.20 | 5.46 | 5.74 | 6.02 | 6.32 | 6.64 | 6.97 | 7.32 | 7.69 | 8.07 | 8.47 | 8.90 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.23 |
| Less: Acc. Dep. Benefit | 0.11 |
| Net Tariff | 3.12 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.67 | 3.85 | 4.04 | 4.25 | 4.46 | 4.68 | 4.91 | 5.16 | 5.42 | 5.69 | 5.97 | 6.27 | 6.59 | 6.92 | 7.26 | 7.62 | 8.01 | 8.41 | 8.83 | 9.27 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.23 |
| Less: Acc. Dep. Benefit | 0.11 |
| Net Tariff | 3.11 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.60 | 3.78 | 3.97 | 4.17 | 4.38 | 4.60 | 4.83 | 5.07 | 5.32 | 5.59 | 5.87 | 6.16 | 6.47 | 6.79 | 7.13 | 7.49 | 7.86 | 8.26 | 8.67 | 9.10 |
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.19 |
| Less: Acc. Dep. Benefit | 0.11 |
| Net Tariff | 3.08 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.58 | 3.76 | 3.95 | 4.15 | 4.36 | 4.58 | 4.80 | 5.04 | 5.30 | 5.56 | 5.84 | 6.13 | 6.44 | 6.76 | 7.10 | 7.45 | 7.83 | 8.22 | 8.63 | 9.06 |
F. For rice straw and juliflora (plantation) based projects with water cooled condenser based on AFBC Boilers.
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.18 |
| Less: Acc. Dep. Benefit | 0.11 |
| Net Tariff | 3.07 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.52 | 3.70 | 3.88 | 4.08 | 4.28 | 4.49 | 4.72 | 4.95 | 5.20 | 5.46 | 5.74 | 6.02 | 6.32 | 6.64 | 6.97 | 7.32 | 7.69 | 8.07 | 8.47 | 8.90 |
G. For rice straw and juliflora (plantation) based projects with air cooled condenser based on Travelling grate boilers.
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.38 |
| Less: Acc. Dep. Benefit | 0.12 |
| Net Tariff | 3.25 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.67 | 3.85 | 4.04 | 4.25 | 4.46 | 4.68 | 4.91 | 5.16 | 5.42 | 5.69 | 5.97 | 6.27 | 6.59 | 6.92 | 7.26 | 7.62 | 8.01 | 8.41 | 8.83 | 9.27 |
H. For rice straw and juliflora (plantation) based projects with air cooled condenser based on AFBC Boilers.
| Particular | Rate of Fixed Charges (Rs./kWh) |
|---|---|
| Gross Tariff | 3.37 |
| Less: Acc. Dep. Benefit | 0.12 |
| Net Tariff | 3.25 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Variable Charges where 1 st year is year of commissioning (Rs./kWh) | 3.60 | 3.78 | 3.97 | 4.17 | 4.38 | 4.60 | 4.83 | 5.07 | 5.32 | 5.59 | 5.87 | 6.16 | 6.47 | 6.79 | 7.13 | 7.49 | 7.86 | 8.26 | 8.67 | 9.10 |
| Sl.No. | Assumption Head | Sub-Head | Sub-Head (2) | Unit | Values |
|---|---|---|---|---|---|
| 1 | Power Generation | Capacity | Installed Power Generation Capacity Auxiliary Consumption factor PLF (during stabilization upto 6 months) PLF (during 1 st year after stabilization) PLF (2 nd yr onwards) Commercial Operation Date Useful Life |
MW % % % % mm/yyyy Years |
|
| 2 | Project Cost | Capital Cost/MW | Normative Capital Cost Capital Cost Capital subsidy, if any Net Capital Cost |
Rs. Lakh/MW Rs. Lakh Rs. Lakh Rs. Lakh |
|
| 3 | Financial Assumptions | Debt/Equity | Tariff Period Debt Equity Total Debt Amount Total Equity Amount |
Years % % Rs. Lakh Rs. Lakh |
|
| Debt Component | Loan Amount Moratorium Period Repayment Period (incl'd Moratorium) Interest Rate |
Rs. Lakh Year Year % |
|||
| Equity Component | Equity Amount Return on Equity for first 10 years Return on Equity 11 th year onwards Discount Rate |
Rs. Lakh % p.a. % p.a. % |
|||
| Depreciation | Depreciation Rate for first 12 years Depreciation Rate 13 years onwards Generation Based incentives, if any |
% % Rs. L p.a. |
|||
| Incentives | Period for GBI | years | |||
| 4 | Operation & Maintenance | Normative O&M expense O&M expense per annum Escalation factor for O&M expense |
Rs. Lakh/MW Rs. Lakh % |
||
| 5 | Working Capital | O&M expense Maintenance Spare Receivables Biomass stock Interest on working capital |
(% of O&M expenses) | Months % Months Months % p.a. |
|
| 6 | Fuel related assumptions | Station Heat Rate Fuel types & mix |
During stabilization Post stabilization Biomass fuel type-1 Biomass fuel type-2 Municipal Solid Waste fuel Refuse Derived Fuel Fossil fuel (coal) GCV of Biomass fuel type-1 GCV of Biomass fuel type-2 GCV of fossil fuel (coal) Biomass Price (fuel type-1):yr-1 Biomass Price (fuel type-2):yr-1 Fossil fuel price (coal) : yr-1 Fuel price escalation factor |
Kcal/kWh Kcal/kWh % % % % % kCal/kg kCal/kg kCal/kg Rs./MT Rs./MT Rs./MT % p.a. |
| Unit Generation | Year | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | |
| Installed Capacity | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 |
| Net Generation | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 |
| 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 |
| Unit Generation | Year | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | |
| O&M Expenses | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 |
| Depreciation | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 |
| Interest on term loan | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | |
| Interest on working Capital | ||||||||||||
| Return on Equity | ||||||||||||
| Total Fixed Cost |
| Per Unit Tariff Components | Year | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | |
| PU O&M Expenses | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 |
| PU Depreciation | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 |
| PU Interest on term loan | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | |
| PU Interest on working Capital | ||||||||||||
| PU Return on Equity | ||||||||||||
| Total Fixed PU Components |
| Levelised Tariff | Year | |||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | |
| Discount Factor | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 |
| Discount Tariff Components | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 |
| Levelised Tariff | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 |
| Year | ||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | ||
| Unit Generation | Unit | |||||||||||||||||||||||||||||||||||
| Installed Capacity | MW | |||||||||||||||||||||||||||||||||||
| Net Generation | MU |
| Year | ||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | ||
| Tariff Components (Fixed charge) | Unit | |||||||||||||||||||||||||||||||||||
| O&M Expenses | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Depreciation | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Interest on term loan | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Interest on working Capital | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Return on Equity | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Total Fixed Cost | Rs. Lakh |
| Year | ||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | ||
| Tariff Components (Variable charge) | Unit | |||||||||||||||||||||||||||||||||||
| Biomass fuel type-1 | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Biomass fuel type-2 | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Municipal Solid Waste | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Refuse Derived Fuel | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Fossil fuel (coal) | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Sub-total (fuel Costs) | Rs. Lakh | |||||||||||||||||||||||||||||||||||
| Fuel cost allocable to power | % | |||||||||||||||||||||||||||||||||||
| Total Fuel Cost | Rs. Lakh |
| Year | ||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | ||
| Per Unit Tariff (Components) | Unit | |||||||||||||||||||||||||||||||||||
| PU & O&M Expenses | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Depreciation | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Interest on term loan | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Interest on working Capital | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Return on Equity | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Total Fixed Components (Fixed) | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Total Fixed Components (Variable) | Rs./kWh | |||||||||||||||||||||||||||||||||||
| PU Total Fixed Components (Total) | Rs./kWh |
| Levelised Tariff | Year | Unit | ||||||||||||||||||||||||||||||||||||
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 | 21 | 22 | 23 | 24 | 25 | 26 | 27 | 28 | 29 | 30 | 31 | 32 | 33 | 34 | 35 | ||||
| Discount Factors | ||||||||||||||||||||||||||||||||||||||
| Discount Tariff Components (fixed) | ||||||||||||||||||||||||||||||||||||||
| Discount Tariff Components (variable) | ||||||||||||||||||||||||||||||||||||||
| Discount Tariff Components (total) | ||||||||||||||||||||||||||||||||||||||
| Levelised Tariff (fixed) | ||||||||||||||||||||||||||||||||||||||
| Levelised Tariff (variable) | ||||||||||||||||||||||||||||||||||||||
| Levelised Tariff (total) |