Logo of the Government of Uttarakhand, featuring a stylized mountain peak and a sun/moon symbol.
उत्तराखण्ड सरकार द्वारा प्रकाशित
रुड़की, शनिवार, दिनांक २० अप्रैल, २०१३ ई० (चैत्र ३०, १९३५ शक सम्वत्)
भाग १-क
नियम, कार्य-विधियां, आझाएं, विज्ञप्तियां इत्यादि जिनको उत्तराखण्ड के राज्यपाल महोदय, विभिन्न विभागों के अध्यक्ष तथा राजस्व परिषद ने जारी किया
Institution of Engineers (I) Building, 1st Floor, Near ISBT, Majra, Dehradun
Notification
15.04.2013
No. F-9(21)/RG/UERC/2013/102: In exercise of the powers conferred under section 61(h), 86(1)(e) read with section 181(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:
(1) These regulations may be called the Uttarakhand Electricity Regulatory Commission (Tariff and Other Terms for Supply of Electricity from Renewable Energy Sources and non-fossil fuel based Co-generating Stations) Regulations, 2013.
(2) These regulations shall come into force with effect from the date of notification, and unless reviewed earlier or extended by the Commission, shall remain in force for a period of 5 years from the date of commencement.
(3) With the coming into force of these Regulations, UERC (Tariff and Other Terms for Supply of Electricity from Non-conventional and Renewable Energy Sources) Regulations, 2010, shall stand repealed.
Provided that in cases of wind, Small Hydro projects, Biomass power based on Rankine cycle, non-fossil fuel based cogeneration projects, Solar PV, Solar Thermal power projects, grid interactive roof top and small solar PV plants, Biomass gasifier and Biogas 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, shall not be applicable for generating stations commissioned prior to coming into effect of these Regulations and their present tariffs shall continue to be applicable. However, provision of 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)(b) shall also be applicable to such stations commissioned prior to coming into effect of these Regulations. Provisions 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.
(2) The existing projects, who are at present supplying power to third party shall have the option to switch over to supply to the distribution licensee or the local rural grid at generic tariffs as was applicable at the time of commissioning of their project or seek determination of project specific tariff from the Commission. The option shall be for the balance life of the project and shall not be allowed to be changed once it is exercised.
(3) The generic tariff specified for Solar PV and Solar Thermal power projects under these Regulations shall be the maximum tariff and the distribution licensee shall invite bids from generators/developers for procurement of power from these generators/developers. The distribution licensee shall enter into a PPA with the generators/developers bidding lower tariff.
(4) The generating stations covered under these Regulations shall be deemed to be the generating station of a generating company and all functions, obligations & duties assigned to such generating company under the Electricity Act, 2003 shall apply to these generating stations.
$$CUF = \frac{ESO \times 10^7}{IC \times (100 - AUX) \times H} %$$
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 (viz. 8.5 for Co-generation).
H - Number of hours in the period
(g) "Capital Cost" means capital cost as defined under Regulation 15(1) of these Regulations.
(h) "Captive Generating Plant" means a power plant set up by any person to generate electricity primarily for his own use and includes a power plant set up by any cooperative society or association of persons for generating electricity primarily for use of members of such cooperative society or association where not less than twenty six percent of the ownership is held by the captive user(s), and not less than fifty one percent of the aggregate electricity generated in such plant, determined on an annual basis, is consumed for the captive use.
(i) "Captive User" means the end user of the electricity generated in a Captive Generating Plant primarily for his own use and the term "captive use" shall be construed accordingly.
(j) "Commission" means the Uttarakhand Electricity Regulatory Commission;
(k) "Control Period or Review Period" means the period during which the norms for determination of tariff specified in these Regulations shall remain valid;
(l) "Date of commercial operation or Commissioning (CoD)" in relation to a unit means the date declared by the 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. In case of Small Hydro Plants the date of commissioning shall, however, not be linked to achieving maximum continuous rating, but the generator will have to demonstrate the same within three years of commissioning.
(m) "Distribution Code" means the UERC (Distribution Code) Regulations, 2007 specified under Section 14 of the Electricity Act 2003, read with Section 181 of the said Act and clause 18 of Distribution and Retail Supply Licence.
(n) "Expenditure incurred" means the fund, whether the equity or debt or both, actually deployed and paid in cash or cash equivalent, for creation or acquisition of a useful asset and does not include commitments or liabilities for which no payment has been released.
(o) "Force Majeure Event" means, with respect to any party, any event or circumstance which is not within the reasonable control of, or due to an act or omission of, that party and which, by the exercise of reasonable care and diligence, that party is not able to prevent, including, without limiting the generality of the foregoing:
i. Lightning, storm, earthquakes, flood, natural disaster and action of the natural elements;
(p) "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;
(q) "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;
(r) "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.
(s) "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;
(t) "Infirm Power" means electricity generated during trial runs prior to commercial operation of a unit of a generating station;
(u) "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);
(v) "Inter-connection Point" shall mean interface point of renewable energy generating facility with the transmission system or distribution system which shall be line isolator on outgoing feeder on HV side of generator transformer;
(w) "MNRE" means the Ministry of New and Renewable Energy of the Government of India.
(x) "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 of Regulation 4(2)(e).
(y) "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;
(z) "Open Access Regulations" means the Uttarakhand Electricity Regulatory Commission (Terms and Conditions of Intra-State Open Access) Regulations, 2010 as amended from time to time;
(aa) "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;
(bb) "Peak Hours/Off Peak Hours" means particular hours of the day as may be decided by the Commission from time to time;
(cc) "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;
(dd) "Project" 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;
(ee) "Renewable Energy" means grid quality electricity generated from renewable sources.
(ff) "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.
(gg) "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.
(hh) "Small Hydro Plant" means Hydro Power projects with installed capacity upto and including 25 MW.
(ii) "Solar Photo Voltaic Power Project" means the project that uses sunlight for direct conversion into electricity through photovoltaic technology.
(jj) "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.
(kk) "Saleable Energy" means the quantum of energy available for sale (ex-bus) after allowing for free energy, if any, to the home State;
(ll) "State Grid Code" means the Uttarakhand Electricity Regulatory Commission (State Grid Code) Regulations, 2007 specified under clause (h) of sub-section (1) of section 86 of the Act by Uttarakhand Electricity Regulatory Commission;
(mm) 'Tariff period' means the period for which tariff is to be determined by the Commission on the basis of norms specified under these Regulations;
(nn) "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 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 roof top and small solar PV plants | 25 years |
| (vi) Biomass Gasifier based power project | 20 years |
| (vii) Biogas based power project | 20 years |
(oo) "Year" means a financial year.
(1) For the purposes of these Regulations, generation from all types of Renewable Energy Sources and non-fossil fuel based Co-generating Plants, as approved by Ministry of New and Renewable Energy (MNRE), Government of India shall be considered and such generating stations shall be collectively referred to as RE Based Generating Stations and Co-generating Stations.
(2) At present, generation from following sources and technologies shall qualify to be covered under these Regulations:
(e) Non-fossil fuel based Co-generating Stations - The project shall qualify to be termed as a non-fossil fuel based co-generation project, if it is using new plant and machinery and is in accordance with the definition and also meets the qualifying requirement outlined below:
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.
(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
(3) Any new source or technology would qualify as 'renewable energy', only after the technology for the same has been approved by MNRE approval. Further, the Commission shall determine tariffs separately for each technology after the approval of the technology by MNRE.
(1) RE Based Generating Stations and Co-generating Stations shall indicate the capacity of its generating plant in the 'Detailed Project Report' (DPR) keeping in view the potential of electricity generation available from such source and its optimal utilization. It shall further be obliged to submit the DPR, progress of construction and details regarding commissioning of the generating plant or any other related information to the Commission in such form and manner as may be required by the Commission.
(2) The RE Based Generating Stations and Co-generating Stations shall:
(ii) Exchange of data of quantity of electricity transmitted through the grid.
(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 and the associated substation. The dedicated transmission lines, if constructed by the generator, shall also be operated and maintained by it (without the requirement of a license). These shall be in accordance with:
(a) The technical standards for construction of electrical plants, electric lines and connectivity with the grid as specified by the Authority (section 73 (b) of the EA 2003).
(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) Except as provided in the Second Proviso to sub-Regulation (1) of Regulation 2 above, all Power Purchase Agreements 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.
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 |
|---|---|---|
| 2013-14 | 6.00% | 0.050% |
| 2014-15 | 7.00% | 0.075% |
| 2015-16 | 8.00% | 0.100% |
| 2016-17 | 9.00% | 0.300% |
| 2017-18 | 11.00% | 0.500% |
* 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
Provided that if energy from renewable and non-conventional sources of energy becomes available, over and above the specified RPO, the generator or the obligated entity shall approach the Commission.
(1) The tariff determined under these Regulations shall be applicable for sale of electricity to the distribution licensees and to local rural grids only. The Commission shall as far as possible be guided by the principles and methodologies, if any, specified by the CERC, National Electricity Policy and the Tariff policy.
(2) The RE Based Generating Stations and Co-generating Stations, except those mentioned under Proviso 2 to sub- Regulation (1) of Regulation 2, may opt for the generic tariff, as determined based on norms specified in these Regulations for different technologies, or may file a petition before the Commission for determination of "Project Specific Tariff". For this purpose RE Based Generating Stations and Co-generating Stations shall give its option to the distribution licensee at least 3 months in advance of date of commissioning of the project or commissioning of the 1st unit, in case of multiple units or one month after the date of issuance of these Regulations, whichever is later. This option once exercised shall not be allowed to be changed during the validity period of the PPA.
(3) Project Specific Tariff, on case to case basis, shall be determined by the Commission in the following cases:
(a) For projects opting to have their tariffs determined on the basis of actual capital cost instead of normative capital cost as specified for different technologies under Chapter 5, the CUF (generation) for recovery of fixed charges shall be taken as that envisaged in the approved DPR or the normative CUF specified under Chapter 5 for the relevant technology, whichever is higher;
(b) Other hybrid projects include renewable-renewable or renewable-conventional sources, for which renewable technology is approved by MNRE;
(c) Projects having old plant and machinery or equipment;
(d) 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 Chapters 4 & 5 of these Regulations for technologies specified therein.
Provided that the benchmark capital cost for Solar PV, Solar thermal 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 (Useful life of the plant) as specified under Regulation 3(1)(nn).
respect of the completed units of the RE Based Generating Stations and Co-generating Stations in such formats and along with such information as the Commission may require from time to time.
Provided that for Project Specific Tariff determination, the RE Based Generating Stations and Co-generating Stations shall submit 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, with duly audited and certified copies of accounts by the statutory auditors within 18 months from the CoD.
(3) The generating company shall file application for determination of tariff for as many years for which it wants the tariff to be fixed.
(4) A petition for determination of 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:
(d) A statement containing full details of calculation of any subsidy and incentive received, due or assumed to be due from the Central Government and/or State Government. This statement shall also separately include the proposed tariff calculated with and without consideration of the subsidy and incentive.
(e) Any other information that the Commission requires the Petitioner to submit.
(5) The proceedings for determination of tariff shall be in accordance with the UERC (Conduct of Business Regulations), 2004.
Provided that for renewable energy technologies having fuel cost component, like biomass power projects 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.
(6) For the purpose of levelised tariff computation, the discount factor equivalent to weighted average cost of capital shall be considered. For determination of weighted average cost of capital, the pre-tax return on equity would be adjusted for tax at the applicable rates.
(7) The generic tariff being normative, any shortfall or gain due to performance or other reasons is to be borne/retained by the RE Based Generating Stations and Co-generating Stations and no true up of any parameter, including additional capitalisation for whatsoever reasons, shall be taken up during the validity of the tariff. The tariff for supply of electricity between the period of synchronization and the commissioning of the unit (Infirm Power) shall be equal to 50% of fixed cost component of levelised generic tariff for the useful life of the project. However, renewable energy technologies having fuel cost component, like biomass power projects and non-fossil fuel based cogeneration, shall also be entitled to get the fuel cost component of tariff for that year in addition to 50% of the levelised generic tariff.
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..
commercial operation or commissioning of the project, as admitted by the Commission after prudence check. The capital cost shall also include the expenditure incurred or projected to be incurred towards the evacuation infrastructure upto point of interconnection (i.e. it does not include cost of dedicated line and associated equipment from point of interconnection up-to the nearest sub-station of transmission or distribution licensee to which generating station is connected). For calculation of project specific tariff the capital cost shall also include the expenditure incurred or projected to be incurred towards additional capitalization.
(b) In case, the generating company opts to construct the evacuation infrastructure from point of inter-connection to the nearest sub-station of transmission or distribution licensee to which the generating station is connected, it shall be allowed a normative levelised tariff of 5 paise/unit over and above the generic tariff determined at the point of inter-connection. However, in case of a solar generating company a normative levelised tariff of 12 paise/unit over and above the generic tariff determined at the point of inter-connection shall be allowed. 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 3 MW, 11 kV S/C | - Rs. 44 lakh |
| ii. Above 3 MW 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 |
(c) Where the dedicated line has been constructed by the generating company, the distribution licensee will have to pay the additional tariff specified above to the generating company provided ownership of such lines remains with the generating company. However the first option shall be given to the distribution licensee for either buying the evacuation line of the Generating Company at the depreciated cost indicated in the latest audited accounts of the generating company, or pay additional tariff as per regulations.
Provided that the distribution licensee will be required to exercise the option within one year from the date of commissioning or CoD of the project.
The debt-equity ratio for generic and project specific tariff shall be as follows:
(a) For generic tariff debt-equity ratio shall be 70:30.
(b) For project specific tariff, the following provisions shall apply:
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) Base Rate prevalent during the first six months of the previous year 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.
Provided that in case of commercial operation of the asset for part of the year, depreciation shall be charged on pro rata basis for computation of project specific tariff.
(1) The value base for the equity shall be as determined under Regulation 15(2).
(2) The Return on Equity shall be:
(b) Pre-tax 24% per annum 11th year onwards.
(1) The Working Capital requirement in respect of wind energy projects, small hydro power, 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 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.
Provided that for determining fuel/variable charges, the normative escalation factor of 5% shall be considered.
Provided further 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.
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. For generic tariff determination, the tax rate for first 10 years has been considered as 18.50% and 30% for balance period alongwith 5% surcharge and 3% education cess.
Provided that the taxes and duties levied by the appropriate Government other than direct taxes shall be allowed as pass through on actual incurred basis.
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 shall be as below:
| 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 | 785 | 26.43 | 45% | 1% |
| > 5 MW & upto 15 MW | 750 | 22.73 | ||
| > 15 MW & upto 25 MW | 715 | 19.03 |
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.
| 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) | ||
| 445 | 25.37 | 4000 | 3300 | 10% | i. During the first year- 65% |
| ii. From 2 nd Year onwards: 80 % |
(a) Biomass Fuel Price (P) for the first year of the Control Period, i.e. FY 2013-14 shall be taken as Rs. 1845/MT, which shall be indexed for different years of tariff period based on annual inflation rate for fuel handling (WPI), Indexed Energy Charge Component (IRC) and transportation cost (price for high speed diesel: Pd) with 20%, 60% and 20% respective weightages as per following formula:
(b) $P(n) = P(n-1) * {0.2 * (WPI(n)/WPI(n-1)) + 0.6 * (1+IRC)(n-1) + 0.2 * (Pd(n)/Pd(n-1))}$
(c) However, as the indices for nth year would be known only after close of nth year, the generating company shall be allowed to raise fuel cost bills for nth year based on normative escalation factor of 5% on previous year's fuel cost, which shall be adjusted based on actual index for the nth year
(d) Alternatively, for each subsequent year of the Tariff Period, the normative escalation factor of 5% per annum shall be applicable at the option of the biomass project developer.
Provided that the generating company has to give his option for normative or indexed fuel cost to the distribution licensee at least 3 months in advance of date of commissioning or one month after the date of issuance of these Regulations, whichever is later. The option once exercised shall not be allowed to be changed during the validity period of the PPA.
$$\text{Rate of Variable Charge (Rs./kWh)} VC_n = \frac{\text{Gross Station Heat Rate (GSHR)}}{\text{Gross Calorific Value (GCV)}} \times \frac{P_n}{(100 - \text{AUX})} \times 1$$
(3) Fuel Mix
(a) The biomass 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 Power Generating Companies shall ensure fuel management plan to ensure adequate availability of fuel to meet the respective project requirements.
(4) Use of Fossil Fuel
The use of fossil fuels shall be limited to the extent of 15% of total fuel consumption on annual basis.
(5) Monitoring Mechanism for the use of fossil fuel
(a) The Project developer shall furnish a monthly fuel usage statement and monthly fuel procurement statement duly certified by Chartered Accountant to the beneficiary for each month, along with the monthly energy bill. The statement shall cover details such as-
(i) Quantity of fuel (in tonnes) for each fuel type (biomass fuels and fossil fuels) consumed and procured during the month for power generation purposes,
(iv) Cumulative actual (gross and net) energy generation (denominated in units) until the end of that month during the year,
(b) Non-compliance with the condition of fossil fuel usage by the project developer, during any financial year, shall render power generated by such biomass power project ineligible as the generation from renewable source during such financial year. 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.
Projects Commissioned on or after 01.04.2013
| 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) | ||
| 420 | 16.92 | 3600 | 2250 | 8.5% | 45% |
$$P_{(n)} = P_{(n-1)} * [0.2 * (WPI_{(n)}/WPI_{(n-1)}) + 0.6 * (1+IRC){(n-1)} + 0.2 * (Pd{(n)}/Pd_{(n-1)})]$$
However, as the indices for nth year would be known only after close of nth year, the generating company shall be allowed to raise fuel cost bills for nth year based on normative escalation factor of 5% on previous year's fuel cost, which shall be adjusted based on actual index for the nth year
Alternatively, for each subsequent year of the Tariff Period, the normative escalation factor of 5% per annum shall be applicable at the option of the biomass project developer.
Provided that the generating company has to give his option for normative or indexed fuel cost to the distribution licensee at least 3 months in advance of date of commissioning or one month after the date of issuance of these Regulations, whichever is later. The option once exercised shall not be allowed to be changed during the validity period of the PPA.
$$\text{Rate of Variable Charge (Rs./kWh) } VC_n = \frac{\text{Gross Station Heat Rate (GSHR)}}{\text{Gross Calorific Value (GCV)}} \times \frac{P_n}{(100 - \text{AUX})} \times 10$$
| 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 |
|---|---|---|---|---|
| 550 | 42.29 | 1.25 | 10% | 85% |
$$(a) \quad P_{(n)} = P_{(n-1)} * {0.2 * (WPI_{(n)}/WPI_{(n-1)}) + 0.6 * (1+IRC){(n-1)} + 0.2 * (Pd{(n)}/Pd_{(n-1)})}$$
Provided that the generator has to give his option for normative or indexed fuel cost to the distribution licensee at least 3 months in advance of date of
commissioning or one month after the date of issuance of these Regulations, whichever is later. The option once exercised shall not be allowed to be changed during the validity period of the PPA.
$$\text{Rate of Variable Charge (Rs./kWh)} VC_n = \text{Specific Fuel Consumption} \times \frac{P_n}{(100 - \text{AUX})} \times 10$$
(4) 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 |
|---|---|---|---|---|
| 1100 | 42.29 | 3.00 | 12% | 90% |
on normative escalation factor of 5% on previous year's fuel cost, which shall be adjusted based on actual index for the nth year
Provided that the generating company has to give his option for normative or indexed fuel cost to the distribution licensee at least 3 months in advance of date of commissioning or one month after the date of issuance of these Regulations, whichever is later. The option once exercised shall not be allowed to be changed during the validity period of the PPA.
$$\left[ \text{Rate of Variable Charge (Rs./kWh)} \text{ VC}_n = \text{Specific Fuel Consumption} \times \frac{P_n}{(100 - \text{AUX})} \times 10 \right]$$
Norms for Solar Photovoltaic (PV) power 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 shall be as below:
| Capital Cost | O&M Expenses for year of commissioning |
Capacity Utilization Factor |
|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | |
| 1000 | 11.63 | 19 % |
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 shall be as below:
| Capital Cost | O&M Expenses for year of commissioning | Capacity Utilization Factor | Auxiliary Consumption |
|---|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | ||
| 1300 | 15.86 | 23% | 10% |
| Capital Cost | O&M Expenses for year of commissioning | Capacity Utilization Factor |
|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | |
| 1025 | 11.63 | 19 % |
The technology specific parameters for determination of generic tariffs for Wind Projects shall be as below:
| Capital Cost | O & M Expenses | Annual Mean Wind Power Density | Capacity Utilization Factor |
|---|---|---|---|
| (Rs. Lakh/MW) | (Rs. Lakh/MW) | (W/m 2 ) | |
| 515 | 9.51 | Upto 200 | 20% |
| 201-250 | 22% | ||
| 251-300 | 25% | ||
| 301-400 | 30% | ||
| >400 | 32% |
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 companys, 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.
The generating station 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 sub-station free of cost.
For sale to person other than the State 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 and Co-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, 2010.
(1) Roof-top Solar PV sources shall be allowed connectivity at the following voltage level in the distribution system of the licensee:
(2) If any dispute arises about connectivity of such sources with the grid, the matter shall be referred to the Commission whose decision in this regard shall be final.
(3) Supply of electricity to the consumer(s) from the licensee's sources and that to the licensee's distribution system from the roof-top Solar PV sources shall be measured 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.
(4) The cost of switch gear, metering and protection arrangement at generator end shall have to be borne by the owner of solar generators.
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 metering and in such cases, energy accounting and billing shall be done by the generating station in association with the concerned distribution licensee.
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 sub-Regulation (3) below.
(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:
(a) Banking of energy upto 100%, as agreed between the plant and the distribution licensee, shall be allowed during the period declared by the Commission as peak hours from time to time in its Tariff Orders.
(e) The power withdrawn by the plant as ascertained by SEM readings, which could not be considered as withdrawal from banked power, shall be considered as power purchased by the plant.
(f) The purchase of power by these plants under clause (e) or otherwise shall be charged as per the provisions of Regulation 45 above.
(g) A Generating Station shall be allowed to withdraw power that was banked during a particular financial year in the same year.
(h) The banked power remaining unutilized on the expiry of the financial year would be treated as sale and the financial settlement shall be made at the tariff determined by the Commission in its Tariff Order for the year during which the power was banked or at the generic tariff specified by the Commission in case of a Non-fossil fuel based Co-generating Stations. No banking charges shall be deducted from such unutilized banked energy.
(i) Banking charges shall be 12.5% of the energy banked.
(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:
(i) the loss of generation at the Station on account of aforesaid factor(s) but attributed to the Force Majeure event(s);
(ii) the loss of generation at the Station due to the interruptions/outages attributed to the aforesaid factor(s) during the period in which the total duration of such outages/interruptions, other than that excluded under above, is within the limit of
48 hours in a month in case of small hydro project, and
Provided further that for working out the ceiling of 60 Hrs. in a month, the interruptions/outages occurring during 18.00 hours in the evening to 6.00 hours in the morning shall not be counted.
(2) The distribution licensee shall be required to maintain the voltages at the point of interconnection with the project within the limits stipulated hereunder, with reference to declared voltage:
(i) In the case of High Voltage, +6% and -9%; and,
(ii) In the case of Extra High Voltage, +10% and -12.5%.
With effect from 01.04.2013, 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.
Further, 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 & upto 15 MW | Above 15 & upto 25 MW |
|---|---|---|---|
| Gross Tariff | 4.22 | 4.02 | 3.74 |
| Less: Accelerated Depreciation | 0.30 | 0.30 | 0.30 |
| Net Tariff | 3.92 | 3.72 | 3.44 |
| Particulars | Rate of Fixed Charges |
|---|---|
| Gross Tariff | 2.10 |
| Less: Accelerated Depreciation | 0.10 |
| Net Tariff | 2.00 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Rate of Variable Charges for Year 1 as FY 2013-14 with 5% normative escalation subsequently | 2.48 | 2.74 | 2.88 | 3.02 | 3.17 | 3.33 | 3.50 | 3.67 | 3.85 | 4.05 | 4.25 | 4.46 | 4.69 | 4.92 | 5.17 | 5.42 | 5.70 | 5.98 | 6.28 | 6.59 |
| Particulars | Rate of Fixed Charges |
|---|---|
| Gross Tariff | 2.85 |
| Less: Accelerated Depreciation | 0.15 |
| Net Tariff | 2.70 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Rate of Variable Charges for Year 1 as FY 2013-14 with 5% normative escalation subsequently | 2.45 | 2.57 | 2.70 | 2.84 | 2.98 | 3.13 | 3.28 | 3.45 | 3.62 | 3.80 | 3.99 | 4.19 | 4.40 | 4.62 | 4.85 | 5.09 | 5.35 | 5.61 | 5.90 | 6.19 |
| Particulars | Rate of Fixed Charges |
|---|---|
| Gross Tariff | 2.25 |
| Less: Accelerated Depreciation | 0.15 |
| Net Tariff | 2.10 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Rate of Variable Charges for Year 1 as FY 2013-14 with 5% normative escalation subsequently | 2.56 | 2.69 | 2.83 | 2.97 | 3.11 | 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 |
| Particulars | Rate of Fixed Charges |
|---|---|
| Gross Tariff | 3.75 |
| Less: Accelerated Depreciation | 0.25 |
| Net Tariff | 3.50 |
| Year | 1 | 2 | 3 | 4 | 5 | 6 | 7 | 8 | 9 | 10 | 11 | 12 | 13 | 14 | 15 | 16 | 17 | 18 | 19 | 20 |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| Rate of Variable Charges for Year 1 as FY 2013-14 with 5% normative escalation subsequently | 3.55 | 3.72 | 3.91 | 4.10 | 4.31 | 4.52 | 4.75 | 4.99 | 5.24 | 5.50 | 5.78 | 6.06 | 6.37 | 6.69 | 7.02 | 7.37 | 7.74 | 8.13 | 8.53 | 8.96 |
| Particulars | Levellised (Entire Life) (Rs./kWh) | ||
|---|---|---|---|
| Solar PV Projects | Solar Thermal Projects | Grid Interactive Rooftop and small solar PV Plants | |
| Gross Tariff | 11.10 | 13.30 | 9.20 |
| Less: Accelerated Depreciation | 0.95 | 1.15 | 1.05 |
| Net Tariff | 10.15 | 12.15 | 8.15 |
| Particulars | Levellised (Entire Life) (Rs./kWh) | ||||
|---|---|---|---|---|---|
| Zone1 | Zone2 | Zone3 | Zone4 | Zone5 | |
| Gross Tariff | 5.45 | 4.85 | 4.15 | 3.35 | 3.10 |
| Less: Accelerated Depreciation | 0.45 | 0.40 | 0.35 | 0.30 | 0.30 |
| Net Tariff | 5.00 | 4.45 | 3.80 | 3.05 | 2.80 |
Form-1.1: Form Template for (Wind Power or Small Hydro Project or Solar PV/Thermal)
| Sl. No. | Assumption Head | Sub-Head | Sub-Head(2) | Unit | Values |
|---|---|---|---|---|---|
| 1 | Power Generation | Capacity | Installed Power Generation Capacity Capacity utilization Factor 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 Debt Component Equity Component Depreciation Incentives |
Tariff Period Debt Equity Total Debt Amount Total Equity Amount Loan Amount Moratorium Period Repayment Period (inclcd Moratorium) Interest Rate Equity Amount Return on Equity for first 10 years Return on equity 11 th Year onwards Discount rate Depreciation Rate for first 12 years Depreciation Rate 13 years onwards Generation based incentives, if any Period for GBI |
Years % % Rs. Lakh Rs. Lakh Rs. Lakh Years Years % Rs. Lakh % p.a. % p.a. % % % RS L.p.a. years |
|
| 4 | Operation & Maintenance | Normative O&M Expenses O&M Expenses per annum Escalation factor for O&M expenses |
Rs. Lakh/MW Rs. Lakh % |
||
| 5 | Working Capital | O&M expenses Maintenance Spare Receivables Interest on working capital |
% of O&M expenses) | Months % Months %p.a. |
Form - 2.1: Form Template for (Biomass Power or Non-fossil fuel based Cogen): Parameter Assumptions
| 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 Debt Component Equity Component Depreciation incentives |
Tariff Period Debt Equity Total Debt Amount Total Equity Amount Loan Amount Moratorium Period Repayment Period (includ Moratorium) Interest Rate Equity Amount Return on Equity for first 10 years Return on Equity 11 th year onwards Discount Rate Depreciation Rate for first 12 years Depreciation Rate 13 years onwards Generation Based incentives, if any Period for GBI |
Years % % Rs. Lakh Rs. Lakh Rs. Lakh Year Year % Rs. Lakh % p.a. % p.a. % % % Rs. L p.a. 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 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. |
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 | Year | |
|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|---|
| ORM Expenses | R$ Lakh | ||||||||||||||||||||||||||||||
| Depreciation | R$ Lakh | ||||||||||||||||||||||||||||||
| Interest on term loan | R$ Lakh | ||||||||||||||||||||||||||||||
| Interest on working Capital | R$ Lakh | ||||||||||||||||||||||||||||||
| Return on Equity | R$ Lakh | ||||||||||||||||||||||||||||||
| Total Fixed Cost | R$ Lakh |
[illegible]
Form 2.2 Form Template for (Biomass Power or Non-fossil based Cogeneration): Determination of Tariff Components
| Year | Year | Year | Year | Year | Year |
|---|---|---|---|---|---|
| Installed Capacity | MW | ||||
| Net Generation | MU | ||||
| O&M Expenses | |||||
| 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 | ||||
| Biomass fuel type-1 | |||||
| Biomass fuel type-2 | Rs. Lakh | ||||
| Fossil fuel (coal) | Rs. Lakh | ||||
| Sub-total (Fuel Costs) | Rs. Lakh | ||||
| Fuel cost allowable to power | % | ||||
| Total Fuel Cost | Rs. Lakh | ||||
| PU & O&M Expenses | |||||
| 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 | ||||
| Discount Factors | |||||
| Discount Tariff Components (fixed) | Rs./kWh | ||||
| Discount Tariff Components (variable) | Rs./kWh | ||||
| Discount Tariff Components (total) | Rs./kWh | ||||
| Levelised Tariff (fixed) | Rs./kWh | ||||
| Levelised Tariff (variable) | Rs./kWh | ||||
| Levelised Tariff (total) | Rs./kWh |
NEERAJ SATI,
Secretary.पी०एस०यू० (आर०ई०) 16 हिन्दी गजट/278-भाग 1-क-2013 (कम्प्यूटर/रीजियो)।
मुद्रक एवम् प्रकाशक-अपर निदेशक, राजकीय मुद्रणालय, उत्तराखण्ड, रुड़की।