छत्तीसगढ़ विद्युत नियामक आयोग (नवीकरणीय ऊर्जा स्त्रोतों पर आधारित संयंत्रों द्वारा उत्पादित विद्युत हेतु उत्पादन टैरिफ के निर्धारण और संबंधित विषयवस्तु की निबंधन एवं शर्तें) विनियम, 2019 संबंधी

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Raipur, the 24thDecember 20 I 9

NOTIFICATION

Chhattisgarh State Electricity Regulatory Commission (Terms and conditions for determination of generation tariff and related matters for electricity generated by plants based on renewable energy sources) Regulations,2019

No. ⁸³/CSERC/²⁰¹⁹. - Govt. of India is giving thrust to develop renewable source of energy being environment friendly in nature. Also the Electricity Act 2003 provides for policy formulation by the Govemment of India and mandates State Electricity Regulatory Commissions (SERCs) to take steps to promote renewable sources of energy within their area ofjurisdiction.

The Central Commission (CERC) has notified the Central Electricity Regulatory Commission (Terms and Conditions for Tariff determination from Renewable Energy Sources), Regulations,20lT under which tariff determination aspects for various renewable energy technologies including municipal waste to energy (municipal solid waste and refused derived fuel), has been discussed. Although these Regulations are applicable for central sector and inter-State generation projects, under Section 61 of EA 2003, however these can be considered as guiding factor for SERCs while dealing with matters related to energy generation from RE sources.

Centre of Wind Energy Technology (CWETy National Institute of Wind Energy (NIWE) along with CREDA has identified few wind energy potential sites in the Chhattisgarh State, wherein wind energy potential can be harnessed for power generation, which needs suitable tariff to attract the investors in this sector.

Keeping the above in view and in exercise of powers vested under section 61, 86 read with Section 181 of the Electricity Act 2003 (36 of 2003) and all other powers enabling it in this behalf, the Chhattisgarh State Electricity Regulatory Commission (the Commission) hereby makes the following Regulations specifying the terms and conditions of tariff for renewable energy sources for the purpose of sale of power to distribution licensees.

However nothing in these regulations bar distribution licensees to procure power as per the provisions in the "Guidelines for tariff based competitive bidding process for grid connected power projects based on renewable energy sources" issued by Ministry of ,New aiid Renewable Energy in December 2012 or its subsequent amendments.

1. Short title and commencement 1.1 These Regulations may be called the Chhattisgarh State Electricity Regulatory Commission (Terms and conditions for determination of generation tariff and related matters for electicity generated by plants based renewable energy sources) Regulations, 2019.

1.2 These Regulations shall come into force from Apri101, 2019 and shall remain in force for a period of 3 years from the date of commencement.

1810 (32)

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1.3 These Regulations shall extend to the whole of the State of Chhattisgarh and shall be applicable to rbnewable energy based generating stations established in thestate.

2. Definitions and Interpretation

2.1 ln these Regulations, unless the context otherwise requires: '

a)

rrAct'r means the Electricity Act, 2003 (36of 2003), as amended from time to time;

b) "Auxiliary Enerry Consumption" or 'AUX' in relation to a period in case of a generating station means the quantum of energy consumed by auxiliary equipments of the generating station, and transformer losses within the generating station, expressed as a percentage of the sum of gross energy generated at the generator terminals of all the units, combined or separately of the generating station.

c) "Biomass" means wastes produced during agricultural and forestry operations (for example straws and stalks) or produced as a by-product of processing operations of agricultural produce (e.g., husks, shells, de-oiled cakes, etc); wood produced in dedicated energy plantations or recovered from wild bushes/weeds, and the wood waste produced in some industrial operations or as specified by Ministry of New and Renewable Energy from time to time.

d)

ttCapacity Utilization Factor" or "CUF" or "Plant Load Factor" or 6'PLF" for a given period, means the total electricity corresponding to actual generation (gross generation) during the reference period, expressed as a percentage of gross generation electricity corresponding to installed capacity in that reference period and shall be computed in accordance with the following formula;

CUtr': Gross generation over the reference period x 1007"

Installed capacity x total hours during the reference period (including outage hours)

e)

6'Capital Cost" means as defined in the regulation 12,25,28,34, 46, 54, 59 and 65 for the respective renewable energy source.

0

g)

I'CERC'! means the Central Electricity Regulatory Commission; "Commission" means the Chhattisgarh State Electricity Regulatory Commission;

h) "Commissioning" means testing and operation of systems and components of generating plant as may be required for successful synchronization of fthe generating plant. A commissioning process may be applied not only to new projects but also to existing units and systems subjected to expansion, renovation or revamping.

i) "Cutoff Date" means 31tt March of the year closing after one year of the year of commercial operation of the project, and in case the project is declared under commercial operation in the last quarter of a year, the cut-off date shall be 31't March of the year closing after one y"*r of the year of commercial operation;

Control Period or Review Period means the period during which the norms i)

1810 (33)

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for determination of tariff specified in these regulations shall remain valid;

k) "Date of Commercial Operation" or "COD" means ' (D in relation to a generating unit means the date declared by the generator after demonstrating the maximum continuou-s rating (MCR) or installed capacity (IC) at designed condition (after considering deviations in uncontrollable parameters) through a successful tri?il r[n, after notice to the beneficiary.

(iD in relation to the generating station means the date of commercial operation of the last unit or block of the generating station in accordance with the clause (i) above;

D "Financial Year" means a period commencing on ltt day of April of a calendar year and ending on 31't March of the subsequent calendar year;

m) "Firm Power" means any electricity supplied from and after the COD of project;

n) "Gross Calorific Yalue" 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 lit of liquid fuel or one standard cubic meter of gaseous fuel, as the case may be;

o) "Gross Station Heat Rate" or "GSHR" means the heat energy input in kCal required to generate one kWh of electrical energy at generator terminals;

p) Hybrid Solar Thermal Power Plants means the solar thermal power plant that uses other forms of renewable energy input sources along-with solar thermal energy for electricity generation, and wherein not less than 75Yo of electricity is generated from solar energy component.

q) "Infirm Power" means electricity generated prior to declaration of date of commercial operation of generating statiorV unit;

r) "Installed Capacity" or "IC" means the summation of the name plate capacities of all the units of the generating station or the capacity of the generating station (reckoned / tested at the generator terminals), as approved by the Commission from time to time;

s) Inter-connection Point

'Inter-connection Point' shall mean interface point of renewable energy generating facility with the transmission system or distribution system, as the case may be:

i. in relation to wind energy projects and solar photovoltaic Projects, interi connection point shall be line isolator on outgoing feeder on HV side of the pooling sub-station ;

ii. in relation to small hydro power, biomass power and non fossil fuel based cogeneration power projects and solar thermal Power Projects the, inter- connection point shall be line isolator on outgoing feeder on HV side of generator transformer;

0

u)

"Licensee" means a distribution licensee operating in the State; ⁶⁶MNRF," means the Ministry of New & Renewable Energy of Government of lndia;

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v) "Maximum Continuous Rating" or "MCR" in relation to a unit of the themal gen0rating station based on renewable energy source :means the maximum continuous output at the generator terminals, guaranteed by the manufacfurer at rated parameters;

- w) Municipal Solid Waste (MSIY) means and includes commercial and residential wastes generated in a municipal or notified-ardas in either solid or semi-solid form excluding industrial hazardous wastes but including treated bio-medical wastes."

x) 'Mini/lVlicro Hydro' means Hydro Power projects with a station capacity up to 100 kW for micro hydro power plants and from 101 kW & up to 2 MW for mini hydro;

y) ttNon-firm power" means the power generated from renewable sources, the hourly variation of which is dependent upon nature's phenomenon like sun, cloud, wind, etc., that cannot be accurately predicted

z) "Non fossil fuel based co-generation" means the process in which more than one form ofenergy (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 fulfiIs the eligibility criteria as specified in Regulation 4.4;

aa) "Project/Plant" means a generating station including the evacuation system upto inter-connection point, 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 the case may be, as apportioned to power generation;

bb) "Refuse Derived Fuel (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 fuels;

cc) ⁶'Renewable Enerry Power Plants" means the power plants other than the conventional power plants generating grid quality electricity from renewable energy sources as approved by MNRE;

dd) "Renewable Energ5r Sources" means renewable sources such as hydro, wind, solar including its integration with combined cycle, biomass, bio fuel cogeneration, urban or municipal waste and other such sources as approved by the MNRE;

ee) "Scheduled Generation" at any time or for any period or time block mehns schedule of generation in MW or MU at inter-connection point as agreed by the generator and licensee;

f0 "Solar PV power" means the Solar Photo Voltaic power project that uses sunlight for direct conversion into electricity through Photo Voltaic technology;

gg) o'Solar Thermal power" means the Solar Thermal power project that uses sunlight for direct conversion into electricity through Concentrated Solar Power technology based on either line focus or point focus principle;

hh) "State" means the State of Chhattisgarh;

l81o (3s) -

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ii) "Tariff period" means the period for which tariff is to be determined by the Commission on the basis of norms specified under these Regulations;

ji)

'Useful Life' in relation to a unit of a generating station including evacuation system shall mean the following duration from the date of commqrcial operation of such generation facility, namely;

'i5 years

I. Wind energy power project

35 years

20 years

20 years

25 years

20 years

JI. Small Hydro Plant ilI. Biomass power project [V. Non-fossil fuel cogeneration V. Solar PV/Solar thermal power plants VI. MSW and RDF based power project

kk) 'Year'means a financial year;

2.2 Words and expressions used in these Regulations and not defined shall have the same meaning as they have in the Act and in the other Regulations made by the Commission.

3. Scope and extent of application

3.1 New Projects:

I. These Regulations shall apply to the Renewable Energy projects, achieving COD from April 01, 2019 to March 31, 2022 (herein after referred to as "RE projects"), located in the State and supplying entire power to distribution licensee(s) of the State on long term basis.

II. These Regulations shall also apply to those RE projects which fulfil the eligibility criteria specified in regulation 4.

3.2 Existing Projects:

I. For existing biomass projects, which have achieved COD before Apil0l,2012 and have long term PPA with distribution licensee for 20 years or more, the applicable tariff i.e., fixed charges, shall be governed by the Commission's order in Petition No 22 of 2011(T) and energy charges will be determined as per provisions in these regulations.

[I. Existing RE projects having long term PPA with distribution licensee of 20 years or more, which have achieved COD between April0l, 2012 to March3l,2017,, applicable tariff (fixed charges) shall be govemed by respective Tariff Orders aS issued from time to time by the Commission for the duration of the Tariff Period whereas energy charges will be determined as per provisions in these regulations.

4. Eligibility Criteria

Following projects achieving COD after Apri101, 2019 shall be eligible under these regulations:

4.1 Wind power project - New wind power project(s) using new plant and machinery.

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4.2 Hydro project -

I. New Mini/Micro/small hydro project(s) located at the sites approved by State Nodal Agency/ State Government using new plant and machinery.

/ II. Large Hydro Projects (LHP) above 25 MW.

4.3 Biomass power project based on Rankine cycle technology - New biomass power project(s) using new plant and machinery based on Rankine cycle technology and using biomass fuel sources.

Provided, that use of fossil fuel shall be restricled to stipulation under Regulation 40 of these Regulations.

4.4 Non-fossil fuel based co-generation project - New non-fossil fuel based co- generation project(s) 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.

4.5 Solar PV, Solar Thermal Power Projects, Solar rooftop PV systems and small Solar power projects - Projects based on Technologies approved by MNRE. 4.6 Municipal solid waste (MSW) 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.

4.7 Refuse derived fuel (RDF) 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.

Chapter 1: General Principals

5. Control Period or review Period 5.1 The Control Period or Review Period under these Regulations shall be of three years.

First year of the Control Period shall commence from the April 01,2019.

Provided 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 duration of the Tariff Period as specified in Regulation 6 below. i Provided also that the Regulations for next Control Period shall be undertaken six months prior to the end of the first Control Period and in case Regulations for the npxt Control Period are not notified until commencement of next Control Period, the tariff norns as per these Regulations shall continue to remain in force until notification of therevisedRegulationssubjecttoadjustmentsasperrevisedRegulations'

6. TariffPeriod 6.1 The Tariff Period for new Renewable Energy power projects will be same as their Usetul Life as defined in Regulation ² (¹) fi).

6.2 Tariff Period under these Regulations shall be considered from the date of commercial operation of the renewable energy generating stations.

uffi€Ird ttqrd, frcis ro ftq|Tr zo r q 1El0 (37) 6.3 Tariff determined as per these Regulations shall be applicable for Renewable Energy power projects, for the duration of the Tariff Period as stipulated under Clause (6.1) and(6.2).

l:., #::t#ffin shau determine the seneric preferentiar tarln in case ", *r, Hydro, Solar PV and Co-generation power projects, at the beginning of each year of the Control period.

7.2 In case of delay in determination of generic tariff, the CERC tariff for the respective year shall be the piovisional tariff. The difference will be adjusted accordingly.

8. Project Specific Tariff 8.1 Project specific tariff, on case to case basis, shall be determined by the Commission for the following types of projects:

i. Wind energy ii. Hydro power plant of above25 MW capacity iii. Solar thermal iv. Municipal Solid Waste and Refuse Derived Fuel based projects with Rankine cycle technology

v. Any other new renewable energy technologies approved by MNRE apart from those identified in these Regulations

vi. Hybrid Solar Thermal Power plants

' vii. Biomass projects

viii. Any generating unit/ station, commissioned by using old plant and machinery.

ix. Any project, if the licensee/developer desires for the project specific tariff 8.2 Determination of Project specific tariff for generation of electricity from such renewable energy sources shall be in accordance with terms and conditions as stipulated under relevant provisions of the regulations/orders.

Provided that norms for project-specific tariff for Hydro power plants above 25 MW capacity, shall be in accordance with CSERC MYT Regulations.

8.3 Further, in case of projects which have been awarded provisional tariff before commencement of these regulations and who opt for generic tariff, payments already made to developers towards provisional tariff shall be adjusted in six equal monthly instalments after deducting the statutory charges paid to State Government.

If such project opts for project specific tariff then such revenue eamed shall be set off against the capital cost incurred on the project.

8.4 The norms as specified under Chapter2 of these Regulations, except for capital cost for the respective year of project commissioning, shall be ceiling norrns.

8.5 In case of biomass projects/co-generation and other projects having fuel cost component, rate of infifln power shall be equal to energy (variable) charges. For other '- projects which do not have fuel cost component, rate of infirm power shall be equal to ' the statutory charges such as water charges, duty and cess actually paid to State Government. Such infirm power shall qualify fo. renewable purchase obligations requirement of the licensee.

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8.6 Petition and'proceedings for determination of tariff

The Commission shall determine the generic tariff on the basis of suo-motu petition six months in advance at the beginning of each year of the Control pefiod for renewable energy technologies for which norms have been gpecified under the Regulations.

8.7 A petition for determination of project specific tariff shall be accompanied by such fee as may be determined by relevant Regulations and shall be accompanied by

i. Information in Forms 1.1,l-2,2.1 and2.2 as the case may be, and as appended in these Regulations;

ii. Detailed project report outlining technical and operational details, site specific aspects, premise for capital cost and financing plan, etc;

Provided that for the existing RE plants, the previous tariff order shall f,orm the basis for capital cost and financing.

iii. Certified copy from the practising Charter Accountant / Cost Auditor as proof of capital cost incurred towards Gross fixed Asset (GFA) clearly indicating sources of funds, debt, equity & subsidies /if any;

iv. A Statement of all applicable terms and conditions and expected expenditure for the period for which tariff is to be determined;

v. A statement containing full details of calculation of any subsidy and incentive received, due or assumed to be due from the Central Govemment and/or State Government. This statement shall also include the proposed tariff calculated without consideration of the subsidy and incentive;

vi. Any other information that the Commission requires the Petitioner to submit for disposal of the petition;

vii. Technical data including data regarding CUF.

8.8 The proceedings for determination of tariff shall be in accordance with the Conduct of Business Regulations of this Commission.

8.9 Project specific tariff shall be determined for the useful life of the project and shall be levellised tariff.

9. Tariff Structure 9.1 The tariff for renewable energy technologies shall be single-part tariff consisting of the following fixed cost components:

I

:

I. Return on equity; II. Interest on loan capital; m. Depreciation; IV. Interest on working capital;

. V. Operation and maintenance expenses;

Provided that for renewable energy technologies having fuel cost component, like biomass power projects and non-fossil fuel based co-generation projects, single-part tariff with two components, viz., fixed cost component and fuel cost component, shall be determined.

, fu-+ ro frgwt zorg 1810 (39) 10. Tariff Design 10.1 The generic tariff shall be determined considering the year of COD of the project, on 1,1"#;TJtT::#',1#rltechnorogieshavingtari*witrrlwocompo,i",,,,, tariff shall be determined on levellised basis considering the year of COD of the project for fixed cost component while the fuel cost component shall be specified on year of operation basis.

10.2 For the purpose of levellised tariff computation, the discount factor equivalent to Post Tax weighted average cost of capital shall be considered.

10.3 Levellisation shall be carried out for the 'useful life'of the renewable energy project.

Provided that for existing RE plants as specified in Regulation 3.2(i) and plants for which project specific tariff has been delermined , no levellisation of tariff will be carried out and tariff will be specified for five years.

10.4 In case of solar, wind and small hydro projects which are nature dependent, any excess generation over and above normative CUFiPLF on annualized basis or the energy specified in the PPA, as the case may be, shall be purchased at 75% of the applicable tariff.

11. Dispatch Principles for electricity generation from Renewable Enerry Sources 11.1 All renewable energy power plants shall be treated as 'MUST RLIN' power plants and shall not be subjected to 'merit order despatch' principles.

ll.2 Notwithstanding any'thing contained in any regulation framed under the Electricity Act2003, all renewable energy power plants except biomass power generating station and non-fossil fuel based co-generation projects shall not be subjected to scheduling and deviation settlement.

Provided that in case of supply of power to multiple beneficiaries within the State, scheduling and deviation settlement shall be applicable.

Chapter 2: Financial Principals

12. Capital Cost l2,l The norms for the Capital Cost as specified in the subsequent technology specific chapters shall be inclusive of all capital work including plant and machinery, civil work, erection and commissioning, financing costs, preliminary and pre-operative expenses, interest during construction, and evacuation infrastructure up to inter- connection point.

Provided that for project specific tariff determination, the generating company shall submit the break-up of capital cost items along with its petition in the manner specified under Regulation 8.

12.2- The Capital Cost, in case of renewable energy projects except for solar PV plants, for each year ofthe control period shall be escalated at the rate of 5oh per annum for the purpose of determination of generic preferential tariff.

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r810 (40)

13. Debt Equity Ratio 13.1 For suo-motu determination of generic tariff, the debt equity ratio shall be considered as 70:30.

13.2 For project specific tariff, if the equity actually deployed is more than 30% of the capital cost, equity in excess of 30Yo shall be treated as normative-loan.

Provided that where equity actually deployed is less than 30Yo of the capital cost, the actual equity shall be considered for determination of tariff; Provided further that the debt/equity invested in foreign currency shall be denominated/ designated in Indian rupees on the date of each investmenl

14. Loan and Finance Charges 14.1 For the purpose of determination of tarifl loan tenure of 13 years shall be considered.

14.2 The loans arrived at in the manner indicated above shall be considered as gross normative loan for calculation of interest on loan. The normative loan outstanding as on April l't of every year shall be worked out by deducting the cumulative repayment up to March 3l't of previous year from the gross normative loan.

14.3 For the purpose of computation of tariff, the normative interest rate of two hundred (200) basis points above the average State Bank of India Marginal Cost of Funds based Lending Rate (MCLR) (one year tenor) prevalent during the last available six months shall be considered.

14.4 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.

Provided that the existing biomass plants having power purchase agreement (PPA) with State DISCOM for which the Commission have determined preferential tariff opt for the project specific tarif| loan and finance charges will be considered as specified in the relevant orders.

15. Depreciation 15.1 The value base for the purpose of depreciation shall be the Capital Cost of the asset admitted by the Commission. The Salvage value of the asset shall be considered as l\Yo and depreciation shall be allowed up to maximum of 90%o of the Capital Cost of the asset.

15.2 The depreciation rate for the first 13 years of the Tariff Period shall be 5.28oh per annum and the remaining depreciation shall be spread over the remaining useful Hfe of the project from 14th year onwards on'Straight Line Method'.

15.3 Depreciation shall be chargeable from the first year of commercial operation. Provided that in case of commercial operation of the asset for part of the year, depreciation shall be charged onpro ratabasis-

16. Return on Equity 16.1 The value base for the equity shall be 30% of the capital cost or actual equity (in case of project specific tariff determination) as determined under Regulation 13.

1810 (41)

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16.2 The normative Return on Equity shall be l6Yo, to be grossed up by prevailing Minimum Alternate Tax (MAT) as on ls April of previous year for the entire useful life of the project.

Provided that the existing biomass plants having power purchase agreement (BeAl with State DISCOM for which the Commission have determined preferential tariff opt for the project specific tariff or the beneficiary/licensee opt for project specific tariff, return on equity will be considered as specified in the relevant orders read with provisions specified in Regulation 3 of these Regulations.

17. Interest on Working Capital 17.1 The Working Capital requirement in respect of wind energy projects, small hydro power, solar PV and Solar thermal power projects shall be computed as per following:

I. Operation & Maintenance expenses for one month; II. Receivables equivalent to 2 (Two) months of energy charges for sale of electricity calculated on the normative CUF;

ilI. Maintenance spare @ ¹⁵% of operation and maintenance expenses The Working Capital requirement in respect of biomass power projects, and non- fossil fuel based co-generation projects, Municipal Solid Waste and Refuse Derived Fuel projects shall be computed as per following:

I. Fuel costs for four months equivalent to normative PLF; II. Operation & Maintenance expense for one month; m. Receivables equivalent to 2 (Two) months of fixed and variable charges for sale of electricity calculated on the target PLF;

17.2 Interest on Working Capital shall be at interest rate equivalent to the normative interest rate of three hundred (300) basis points above the average State Bank of India MCLR (One Year Tenor) prevalent during the last available six months for the determination of tariff.

18. Operation & Maintenance Expenses 18.1 'Operation and Maintenance or O&M expenses' shall comprise repair and maintenance (R&M), establishment including employee expenses, and administrative and general expenses including insurance.

2oh shall be allowed.

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19.2 Where payments are made other than through letter of credit within a period of one month of presentation of bills by the generating company, a rebate of lo/o shall be allowed.

20. Late payment surcharge 20.1 In case the payment of any bill for charges payable under these rdgulations is delayed beyond a period of 60 days from the date of billing, a late payment surcharge at the rate of I.25% per month shall be levied by the generating company.

21. Norms of Operation and Parameters to be Ceiling Norms: 2l.l Norms and parameters specified in these regulations are the ceiling noffns and shall not preclude the project developer or the beneficiary from agreeing to the improved norns of operation and in case the improved norms are agreed to, such improved norms/parameters shall be applicable for determination of project specific tariff.

22. Subsidy or incentive by the CentraUState Government 22.1 The Commission shall take into consideration any capital subsidy/ incentive/grant 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 project specific tariff under these Regulations.

Provided further that in case any Central Government or State Govemment notification specifically provides for any Generation based Incentive over and above tariff, the same shall not be factored in while determining Tariff.

23. Cess, Duties and Water charges/statutory charges 23.1 Tariff determined under these regulations shall be exclusive of cess and duties on generation, auxiliary consumption and sale of electricity as may be levied by the appropriate Government.

Provided that the cess and duties levied by the appropriate Government shall be allowed as pass through on actual incurred basis.

In case of hydro projects, water charges as levied by the State Government shall not be included in the tariff. It is to be paid separately and shall be pass through on actual incurred basis.

24. Sharing of CDM Benefits 24.1 The projects for which the Commission has determined project specific tariff, the proceeds of carbon credit from approved CDM project shall be shared betwtien generating company and concemed beneficiaries in the following manner, namely o 100%o of the gross proceeds on account of CDM benefit to be retained by the project developer in the first year after the date of commercial operation of the generating station;

o In the second year, the share of the beneficiaries shall be 10% which shall be progressively increased by t0% every year till it reaches 50ol0, where after the proceeds shall be shared in equal proportion, by the generating company and the beneficiaries.

1S1o (43)

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Chapter 3: Technolory specific parameters for Wind energy Projects

-and

25. Capital Cost 25.1 The capital cost for wind energy project shall include Wind turbine genelator other civil works, including its auxiliaries, land cost, site development charges transportation charges, evacuation cost up to inter-connection point,-financing charges and IDC. .

25.2 The capital cost for wind energy projects shall be Rs.5.25 cr. per MW (FY 2019-20 during first year of Control Period) and shall be revised for the projects to be commissioned in 6ach subsequent year as outlined under Regulation 12.2.

26. Capacity Utilisation Factor (CUF) 26.1 CUF norms for this control period shall be as follows;

26.2 The annual mean wind power density specified in Regulation 26.1 above shall be measured at 100 meter hub-height.

26.3 For the pu{pose of classification of wind energy project into particular wind zone class, as per MNRE guidelines for wind measurement, wind mast either put-up by NIWE or a private developer and validated by NIWE would be normally extended 10 km from the mast-point to all directions for uniform terrain and limited to appropriate distant in complex terrain with regard to complexity of the site. Based on such validation by NIWE, State Nodal Agency should certify zoning of the proposed wind farm complex.

27, Operation and Maintenance Expenses 27.1 The Commission shall determine only Project Specific O&M Expenses based on the prevailing market information.

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chapter 4: Technolory specific parameters for small Hy{ro projects

28. Capital Cost 28.1 The normative capital cost for hydro projects during first year of the control-period (i.e. year 2019-20 ) shall be as follows;

Proiect Size Capital Cost (Rs. Lakh/l\ztW)

upto5MW 880 above 5 MW to 25 MW 800

This also includes the cost of laying of distribution/transmission lines for evacuation of power.

28.2 Capital cost for Small Hydro Plants, achieved COD before April0l , 2Ol2 will be governed through respective approved Orders of the Commission.

29. Capacity Utilisation Factor (CUF) 29.1 For determination of generic tariff, capacity utilisation factor for hydro projects shall be 30%. For project specific tariff, CUF shall be determined by the Commission on case to case basis.

30. Auxiliary Consumption 30.1 Normative Auxiliary consumption for the hydro projects shall be 1.5%.

31. Operation & Maintenance Expenses 31.1 Normative O&M expenses for the first year of the control period (i.e. FY 2019-20) shall be as follows:

31.2 Normative O&M expenses allowed under these Regulations shall be escalated at the rate of ⁵.⁷²% per annum for the Tariff Period for the purpose of determination of tariff.

,:

32. Tarifffor Mini/lVlicro Hydro Projects 32.1 Tariff for Mini/Micro Hydro Projects shall be higher by Rs 0.50/kwh or such other higher amount as may be stipulated by Commission from time to time over and above the generic tariff applicable for Hydro Projects as decided by the Commission. However this will not be applicable for the developers/licensee opts for project specific tariffand on canal based projects.

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1810 (4s) Chapter 5: Technology specific parameters for Biomass Power Projects based on Rankine Cycle Technolory

33. Technology Aspect 33.1 The norms for tariff determination specified hereunder are for biomass power projects based on Rankine cycle technology application using water cooled c-ondenser.

34. Capital Cost and Capital Cost Indexation Mechanism 34.1 The Commission shall determine only project specific capital cost and tariff based on prevailing market trends for biomass energy project.

35. Target Capacity Utilization Factor and recovery of charges (fixed and enerry) 35.1 Threshold Capacity Utilization Factor for determining fixed charge component of Tariff shall be:

a) Dwing Stabilisation: 60Yo

b) Drning the remaining period of the first year (after stabilizanon): 70%o

c) From 2 Year onwards: 80 o%

35.2 The stabilisation period shall not be more than 6 months from the date of commissioning of the project.

36. Auxiliary Consumption 36.1 The auxiliary power consumption shall be considered as l0% for the determination of tariff.

37. Station Heat Rate 37.1 The station heat rate for the biomass power projects shall be 4000 kcal/kWh.

38. Operation and Maintenance Expenses 38.1 Normative O&M expenses for the first year of the control period (i.e. FY 2019-20) shall be Rs. 44.7 Lakh per MW.

38.2 Normative O&M expenses allowed at the commencement of the tariff Period shall be escalated at the rate of 5.72% per anmrm for the subsequent years of the control period.

39. Fuel i 39.1 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.

39.2 The Biomass Power Generating Companies shall ensure fuel management plan to ensure adequate availability of fuel to meet the respective project requirements and . submit to the beneficiary.

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40. Use of Fossil Fuel - Fuel Mix 40.1 The use of fossil fuels shall not be allowed.

3t.03.2019, in t6rms of the date of Provided that for the biomass power projects commissioned on or before the use of fossil fuels to the extent of l5Yo or as prescribed by MNRE calorific value on annual basis shall be allowed for the tariff perlod from COD.

41. Monitoring Mechanism for the use of fossiUbiomass fuel 4l.l The project developer shall furnish a monthly fuel procurement statement and monthly fuel usage statement duly certified by Chartered Accountant/Cost Accounted to the beneficiary, with complete details as may be required to the satisfaction of the beneficiary, with whom the power purchase agreement has been made (with a copy to appropriate agency i.e. CREDA appointed by the Commission for the purpose of monitoring the fossil and non-fossil fuel consumption) for each month, along with the monthly energy bill. The statement shall cover details such as -

i. Sources of fuel procurement ii. Opening fuel stock quantity (in tonnes), for each type of fuel, iii. Receipt of fuel quantity (in tonnes) at the power plant site for each type of fuel during the month,

iv. Quantity of fuel (in tonnes) for each fuel type (biomass fuels and fossil fuels) consumed during the month for power generation purposes,

v. Closing fuel stock quantity (in tonnes) for each fuel type (biomass fuels and fossil fuels) available at the power plant site at the end of the month,

vi. Cumulative quantity (in torures) of each fuel type (biomass and fossil fuel) procured till the end of that month during the financial year,

vii. Cumulative quantity (in tonnes) for each fuel type (biomass and fossil fuel) consumed till end of that month during the financial year),

viii. Actual (gross and net) energy generation (denominated in lakh of units) during the month,

ix. Cumulative actual (gross and net) energy generation (denominated in lakh of units) until the end of that month during the financial year,

41.2 In case designated agency is satisfied, that the generator has reached to a stage whereby compliance of the fuel mix criterion on annualised basis (financial year) is not possible, it will intimate to the concern beneficiaries and generators with details of such conclusions. Thereafter beneficiary shall issue notice to the generator with reasons and instead of paying the preferential tariff, shall deal with the issuer in accordance to express provisions given in Regulations 41.3. Appropriate mechanism shall be incorporated in the power purchase agreement between the parties with due approval of the Commission for the compliance of fuel mix ration as prescribed by MNRE.

41.3 Non-compliance with the condition of fossil fuel usage by the project developer (achieved CoD before and after AprilOl, 2019), during any financialyear, shall render such biomass power project to be ineligible to avail preferential tariff determined as per these Regulations in the year of default during such financial year when such default occurs. However, such defaulting Biomass Power Project shall continue to sell power to concern distribution licensee even during the period of default. The rate of

lsro (47)

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supply to distribution licensee will be weighted average pooled price at which the distribution licensee has purchased the electricity including cost of self generation, if any, (in the defaulting year of biomass planO from all the long-term and short-term energy suppliers, but excluding those based on renewable energy sources, as the case may be, for the entire year of default and additional paymenl arrived to such p6wer project will be adjusted in future bills in six equal monthly instalments.

42. Power to iequire statistics & returns by Monitoring agency 42.1 The Chhattisgarh Renewable Energy Developmenl Agency (CREDA) shall be responsible for monitoring compliance of fuel mix ratio of biomass projects.

42.2 CREDA shall also maintain such data, including technical and commercial details (including year of CoD, prescribed fuel mix ratio, source of fuel etc.) of biomass projects in the State and shall make the data available in the public domain by publishing the same on its website with quarterly updation.

42.3 The project developer shall submit the information to CREDA as required under Regulation 41 in the format as specified in schedule format 3.1 and3.2.

42.4 CREDA shall submit an annual report on an affidavit duly notarised, for the entire financial year to the Commission for each biomass power plant (achieved CoD before and after April0l, 2012) on the use of fossil fuel and biomass fuel by the biomass based plant during the preceding year, by the end of April every year.

42.5 CREDA shall also submit the same annual report (as mentioned in Regulation 42.4) for the entire financial year to the beneficiary for each biomass power plant (achieved CoD before and after Apri101, 2012) on the use of fossil fuel and biomass fuel by the biomass based plant during the preceding year, by the end of April every year. Non- compliance of the stipulation with regard to use of fossil fuel by any generating plant and use of such fuel in excess of the specified percentage during any financial year shall render the plant to be treated as any other thermal generator and all benefits given to such plants including tariff, as renewable energy source shall stand withdrawn. Beneficiary shall issue notice to such generators for non compliance with regard to usage of fossil fuel and instead of paying the preferential tariff, shall deal with the issue in accordance to express provisions given in Regulations 41.3.

Also project developer shall submit documents related to long term fuel supply arrangement to the beneficiary as well as to the CREDA.

43. Calorific Value 43.1. The average Calorific Value of the biomass fuel(s) used for the purpose of determination of tariff for biomass power projects shall be 3l00kca1/kg. i 44. Fuel Cost 44.1 Biomass fuel price for the I'tyear of the control period (i.e. FY 2019-20) shall be Rs.

3388 per MT.

44.2 Biomass fuel price shall be escalated at 5Yo to arrive at the base price for subsequent years of the Control Period.

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Chapter 6: Technology specific parameters for Non-fossil fuel b,ased Cogeneration Projects

, 45. Technolory Aspect 45.1 A project shall qualify as a non-fossil fuel based co-gen6ration project, if it is in accordance with the eligibility criteria as specified under Regulation 4.4.

46. Capital Cost 46.1 The normative capital cost for the non-fossil fuel based co-generation projects shall be considered as Rs.492.5 Lakh/MW for the first year of the Control Period (i.e. FY 2019-20).

47. Capacity Utilization Factor 47.1 For the purpose of determining fixed charge, the plant load factor for non-fossil fuel based co-generation projects shall be computed on the basis of plant availability for number of operating days considering operations during crushing season and off- season as specified under Regulation 47.2below and load factor of 92Yo.

47.2 The number of operating days shall be as follows:

Oneratins Davs Plant Load Factor (7o) 90 days (crushing)+ 60 days (off-season)

38%

: 150 davs ooeratins davs

48. Auxiliary Consumption 48.1 The auxiliary power consumption shall be 8.5% for determination of tariff.

49. Station Heat Rate 49.1 The station heat rate of 3600 kcal/kWh for the power generation component alone shall be considered for computation of tariff for non-fossil fuel based co-generation projects.

50. Calorific Value 50.1 The Gross Calorific Value for bagasse shall be considered as 2250 kcal/kg. For the use of biomass fuels other than bagasse, calorific value as specified under Regulation 43 shall be applicable.

ii' 51. Fuel Cost 51.1 The price of bagasse shall be Rs 2166 per MT during first year of the tariff Control Period (i.e. FY 20t9-20) and thereafter shall be escalatedto SYo for the base price for subsequent years during the control period.

51.2 For use of biomass other than bagasse in co-generation projects, the biomass prices as specified under Regulation 44 shall be applicable.

51.3 For the purpose of determining levellized tariff, a normative escalation factor of 5Yo per annum shall be applicable on bagasse prices.

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1810 (4e) 52. Operation and Maintenance Expenses

52.1 Normative O&M expenses for the first year of the tariff period (i.e. FY 20Ig-20) shall be Rs.23.61 Lakh per MW.

52.2 Normative O&M expenses allowed at the corlmencement of -the tariff Period rfnder these Regulations shall be escalated at the rate of 5.72% per annum.

Chapter 7: Technolory specific parameters for Solar PV Power Projects

53. Technolory Aspects 53.1 Norms for Solar Photovoltaic (PV) power under these Regulations shall be applicable grid corurected 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.

53.2 The Commission shall determine generic tariff for the solar PV plants of capacity 0.5 MW to 2 MW and above 2 MW to 5 MW.

54. Capital Cost 54.1 The normative capital cost for setting up Solar Photovoltaic Power Project shall be determined every year. For FY 2019-20, it shall be as follows;

0.5 MW to 2 MW Rs.4.5 croreAvlW above 2 MW to 5 MW Rs. 4.0 crore/IVIW

54.2 Capital cost for Solar PV power projects, achieved COD before April0l, 2019 will be govemed through respective approved Orders of the Commission till the currency of the Order.

55. Capacity Utilisation Factor 55.1 The Capacity utilisation factor for Solar PV project shall be l9%. Provided that the Commission may deviate from above nofin in case of project specific tariff determination in pursuance of Regulation 7 and Regulation 8.

56. Operation and Maintenance Expenses 56.1 The O&M Expenses shall be Rs. 7.0 Lakh/MW for the l't year of operation.

56.2 Normative O&M expenses allowed at the commencement of the tariff Period undef these Regulations shall be escalated at the rate of 5.72% per annum.

57. AuxiliaryConsumption 57.l The auxiliary consumption factor shall be 0.25% of gross generation.

Provided that the Commission may deviate from the above norm in case of project specific tariff determination in pursuance of Regulation 7 and Regulation 8.

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Chapter 8: Technolory specific parameters for Solar Thermal Power Projects

58. Technolory Aspects 58.1 Norms for Solar thermal power under these Regulations shall be applicable for Concentrated solar power (CSP) technologies viz. line focuiing or point focusing, as may be approved by MNRE, and uses direct sunlight, concentrdtirtg 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.

59. Capital Cost 59.1 The Commission shall determine only project specific capital cost and tariff based on prevailing market trends for Solar Thermal project.

60. Capacity Utilisation Factor 60.1 The Capacity utilisation factor for Solar Thermal project shall be 23Yo. Provided that the Commission may deviate from the above norm in case of project specific tariff determination in pursuance of Regulation 7 and Regulation 8.

61. Operation and Maintenance Expenses 61.1 The Commission shall determine only project specific O&M expenses based on prevailing market trends for Solar Thermal project.

62. Auxiliary Consumption 62.1 The auxiliary consumption factor shall be 10%.

Provided that the Commission may deviate from the above norm in case of project specific tariff determination in pursuance of Regulation 7 and Regulation 8

63. Hybrid Solar Thermal Power Plants 63.1 The capital cost, auxiliary consumption factor, capacity utilization factor, O&M expenses and other relevant parameters for hybrid solar thermal power plants shall be decided by the Commission on case to case basis.

Chapter 9: Technolory specific parameters for MSW and RDF Projects based on Rankine Cycle Technology

ll 64. Technolory Aspect 64.1 The norms for tariff determination specified hereunder are for power projects which use municipal solid waste (MSW) and refuse derived fuel (RDF) and are based on Rankine cycle technology application, combustion or incineration, Bio-methanation, Pyrolysis and High end gasifier technologies.

65. Capital Cost Oi.f The Commission shall determine only project specific capital cost and tariff based on prevailing market trends for MSWRDF projects.

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66. Capacity Utilization Factor 66.1 Threshold Plant Load Factor for determining fixed charge component of Tariff shall be:

a) During Stabilisation: 65%o b) Dtning the remaining period of the first year(after stabilinaonj: ⁶⁵%o c) Fro-m 2 Year onwards: 7 5o/o for MSW based technologies and 80% for RDF based technologies.

66.2 The stabilisation' period shall not be more than 6 months from the date of commissioning of the project.

67. AuxiliaryConsumption 67.1 The auxiliary power consumption for the power projects which use municipal solid waste and refuse derived fuel shall be l5%o.

68. Station Heat Rate 68.1 The Station Heat Rate for power projects which use municipal solid waste and refuse derived tuel shall be 4200 kcal/kWh.

69. Operation and Maintenance Expenses 69.1 The Commission shall determine only project specific O&M expenses based on prevailing market trends for MSWRDF projects.

70. Calorific Value 70.1 The Calorific Value of the municipal solid waste and refuse derived fuel used for the purpose of determination of tariff shall be at2500 kcal/Ifu.

71. Fuel Cost 7l.l Retuse derived tuel (RDF) price during FY 2019-20 shall be Rs 1,985 per MT. For each subsequent year of the Tariff Period, the normative escalation factor of 5Yo per annum shall be applicable at the option of the refuse derived fuel (RDF) project developer. No fuel cost shall be considered for determination of tariff for the power projects using municipal solid waste (MSW).

72. Monitoring Mechanism for the use of MSWRDF 72.1 The project developer shall furnish a monthly fuel procurement statement and monthly fuel usage statement duly certified by Chartered Accountant to the beneficiary licensee, with complete details as may be required to the satisfaction of the beneficiary licensee, with whom the power purchase agreement has been made (with a copy to appropriate agency i.e. CREDA for the purpose of monitoring MSWRDF consumption) for each month. The statement shall cover details such as i. Opening fuel stock quantity (in tonnes), for each type of fuel, ii. Receipt of fuel quantity (in tonnes) at the power plant site for each type of fuel during the month,

iii. Quantity of fuel (in tonnes) for each fuel type consumed during the month for

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power generatron purposes,

iv. Closing fuel stock quantity (in tonnes) for each fuel type available at the power plant site at the end ofthe month,

the end-of that v. Cumulative quantity (in tonnes) of each fuel type procured till

month during the financi al year,

till end of that vi. Cumulative quantity (in tonnes) for each fuel type consuried

mbnth during the financial year,

vii. Actual (gross and net) energy generation (denominated in lakh of units) during the month,

viii. Cumulative actual (gross and net) energy generation (denominated in lakh of units) until the end of that month during the financialyear,

72.2 Non compliance of the above provisions to be brought to the notice of the Commission. Appropriate mechanism shall be incorporated in the power purchase agreement between the parties with due approval of the Commission for the compliance of uses of MSWRDF fuel.

72.3 Non-compliance with the condition of MSWRDF usage by the project developer, during any financial year, shall render such waste to energy project to be ineligible to avail preferential tariff determined as per these Regulations in the year of default during such financial year when such default occurs. However, such defaulting waste to energy project shall continue to sell power to concern distribution licensee even during the period of default. The rate of supply to distribution licensee will be weighted average pooled price at which the distribution licensee has purchased the electricity including cost of self generation, if any, (in the defaulting year of waste to energy project plan| from all the long-term and short-term energy suppliers, but excluding those based on renewable energy sources, as the case may be, for the entire year of default and additional payment arrived to such power project will be adjusted in future bills in six equal monthly instalments.

73. Power to require statistics & returns by Monitoning agency 73.1 The Chhattisgarh Renewable Energy Development Agency (CREDA) shall be responsible for monitoring compliance of fuel these projects.

73.2 CREDA shall also maintain such data, including technical and commercial details (including year of COD, uses of fuel), source of fuel etc.) of waste to energy projects in the State and shall make the data available in the public domain by publishing the same on its website with quarterly updation.

73.3 The project developer shall submit the information to CREDA as required uniler Regulation 72 inthe format as designed by CREDA.

73.4 CREDA shall submit an annual report on an affidavit duly notarised, for the entire financial year to the Commission for each waste to energy plant on the use of MSWRDF fuel during the preceding year, by the end of April every year. CREDA shall also submit the same annual report for the entire financial year to the beneficiary distribution licensee.

1810 (s3)

ChapterL0: Miscellaneous

74. Deviation from norms 74.1 Tariff for sale of electricity by the generating company may also be determined in deviation from the nonns specified in these Regulations subject to the conditions that the reasons for deviation from the norms specified under these-Re-gulations shall be recorded in writing.

75. Power to Relax 75.1 The Commission'may by general or special.ordet, for reasons to be recorded in writing, and after giving an opportunity of hearing to the parties likely to be affected may relax any of the provisions of these Regulations on its own motion or bn an application made before it by an interested person.

76. Power to remove difficulties 76.1 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.

77. Repeal & Savings 77.1 On commencement of these Regulations, the Chhattisgarh Electricity Regulatory Commission (Terms and conditions for determination of generation tariff and related matters for waste to energy projects) Regulations, 2016 shall stand repealed.

77.2 Notwithstanding anything contained in Regulation 77.L, generic preferential tadff order issued by the Commission in accordance with provisions in the Chhattisgarh Electricity Regulatory Commission (Terms and conditions for determination of generation tariff and related matters for waste to energy projects) Regulations,2016 shall continue to be valid till the expiry of the tariff period.

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(Asha V.Deg Deputy Secretary.

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Form-l.l. Template for (Wind Power / Small Hydro Project / Solar PV / Solar thermal): Parameter Assump.tions

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