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(3)

‘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, deoiled cakes, etc); wood produced in dedicated energy plantations or

recovered from wild bushes/weeds whichever permissible; and the wood waste produced in

some industrial operations;

(4)

‘Capital cost’ means the capital cost as defined in the relevant sub regulations of these

Regulations;

(5)

‘Central Agency’ means the agency operating the National Load Dispatch Centre or such other

agency as the Central Commission may designate from time to time;

(6)

“Certificate” means the renewable energy certificate issued by the Central Agency in accordance

with the procedures prescribed by it and under the provisions specified in the Central Electricity

Regulatory Commission (Terms and Conditions for recognition and issue of Renewable Energy

Certificate for Renewable Energy Generation) Regulations, 2009 as amended from time to time;

(7)

‘Central Electricity Regulatory Commission (CERC)’ means the Central Electricity Regulatory

Commission referred to in sub-section (1) of section 76 of the Act;

(8)

‘Commission’ means the Haryana Electricity Regulatory Commission;

(9)

‘Conduct of Business Regulations’ means the Haryana Electricity Regulatory Commission

(Conduct of Business) Regulations, 2019 as amended from time to time;

(10)

‘Control Period or Review Period’ means the period during which the norms for determination

of tariff and other provisions specified in these regulations shall remain valid;

(11)

‘Floor Price’ means the minimum price determined by the Central Commission in accordance

with these regulations at and above which the renewable energy certificate can be traded in the

power exchange;

(12)

‘Forbearance price’ means the ceiling price as determined by the Central Commission in

accordance with the Central Electricity Regulatory Commission (Terms and Conditions for

recognition and issue of Renewable energy Certificate for Renewable Energy Generation)

Regulations, 2010, as amended from time to time, within which the Certificate can be traded in

power exchange;

(13)

‘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;

(14)

‘Gross station heat rate’ or ‘GHR’ means the heat energy input in kCal / kWh required to

generate one kWh of electrical energy at generator terminals of a renewable energy generating

station;

(15)

‘Hybrid Solar Thermal Power Plant’ means the solar thermal power plant that uses other forms

of energy input sources along with solar thermal energy for electricity generation, and wherein

not less than 75% of electricity is generated from solar energy component;

(16)

‘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 at the generator

terminals/Solar Inverter in MW / MVA), as the case may be;

(17)

‘Inter-connection Point’ shall mean interface point of renewable energy generating facility

including Waste to Electricity projects with the transmission system or distribution system,

in relation to wind energy projects, Solar Photovoltaic Projects, renewable hybrid energy

projects and renewable energy with storage Projects, inter-connection point shall be line

isolator on outgoing feeder on High Voltage (HV) side of the pooling sub-station;

in relation to small hydro power, biomass power, Waste to Energy projects 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;

Whereas, ‘Pooling Sub-Station’ means a Sub-Station consisting of a step-up transformer and

associated switchgear to the Low Voltage (LV) side of which several Wind or Solar Energy Generators

are connected.

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Provided that, where a Generating Unit is connected through a common or an individual feeder

terminating at a Sub-Station of a Distribution Licensee or the State Transmission Utility, such

Sub-Station shall be treated as the Pooling Sub-Station for such Wind or Solar Energy Generator for the

purposes of these Regulations.

(18)

‘Non 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;

(19)

“Levellised Tariff” means the tariff calculated by carrying out levelisation for ‘useful life’ of

each technology considering the discount factor for time value of money.

(20)

‘MNRE’ means the Ministry of New and Renewable Energy of the Government of India;

(21)

“Municipal Solid Waste” means and includes commercial and residential wastes generated in a

municipal or notified area in either solid or semi solid form excluding industrial hazardous

wastes but including treated bio-medical waste;

(22)

‘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 including

Bagasse.

(23)

‘Obligated entity’ means an entity in the State of Haryana which is mandated to fulfill renewable

purchase obligation under these Regulations and include the following:-

(i)

Distribution licensee(s)

(ii)

Open Access consumers including short term open access consumers, and

(iii)

Fossil Fuel based Captive Power Plant of 5 MW and above including Fossil Fuel based

Co-generation captive plant of 5 MW and above.

(24)

‘Operation and maintenance expenses’ or ‘O&M expenses' means the expenditure incurred on

operation and maintenance of the project, or part thereof, and includes the expenditure on

manpower, repairs, spares, consumables, insurance and overheads;

(25)

“Power Exchange’ means any exchange operating as the power exchange for electricity as

approved by the CERC;

(26)

‘Preferential tariff’ or “Feed in Tariff” means the tariff fixed by the Commission for sale of

energy from a generating station based on renewable energy sources to a distribution licensee;

(27)

‘Project' means a generating station or 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;

(28)

‘Renewable Energy’ means the electricity generated from renewable energy sources;

(29)

‘Renewable Energy Power Plants’ means the power plants other than the conventional power

plants generating electricity from renewable energy sources;

(30)

‘Renewable Energy Sources’ means renewable sources such as small hydro, wind, solar

including its integration with combined cycle, biomass (including Bagasse), bio fuel, urban or

municipal waste and other such sources as approved by the MNRE;

(31)

‘Small Hydro’ means Hydro Power projects with a station capacity up to 25 MW or as specified

in the National Tariff Policy or by the Central Government from time to time;

(32)

‘Pumped storage hydro project’ means a hydro power projects which generates power through

water stored as potential energy, pumped from a lower elevation reservoir to higher elevation

reservoir;

(33)

‘Renewable energy with storage project’ means a combination of renewable energy project with

storage or a combination of renewable hybrid energy project with storage at the same

inter-connection point;

(34)

‘Renewable hybrid energy project’ means a renewable energy project that produces electricity

from a combination of renewable energy sources, connected at the same inter-connection point;

(35)

‘Solar PV power’ means the Solar Photo Voltaic power project that uses sunlight for direct

conversion into electricity through Photo Voltaic Cells;

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(36)

‘Solar Thermal power’ means the Solar Thermal power project that uses sunlight for conversion

of heat energy into electricity through Concentrated Solar Power technology based on either line

focus or point focus principle;

(37)

“Storage” means energy storage system utilizing methods and technologies like, solid state

batteries, flow batteries, pumped storage, compressed air, fuel cells, hydrogen storage or any

other technology, to store various forms of energy and to deliver the stored energy in the form of

electricity;

(38)

‘State agency’ means the agency in the State of Haryana to be designated by the Commission to

act as the agency for accreditation and recommending the renewable energy projects for

registration and to undertake functions under these regulations;

(39)

‘Tariff period’ means the period for which tariff / price for sale of power is determined by the

Commission on the basis of norms specified in these Regulations;

(40)

‘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:

(a)

Wind energy power project 25 years.

(b)

Biomass power project, non-fossil fuel cogeneration 20 years.

(c)

Small Hydro Plant 40 years.

(d)

Solar PV/Solar thermal power plants 25 years.

(e)

Processed Municipal Solid Waste (MSW) WtE based power projects – 20 years.

(f)

Biomass gasifier power plants 20 years.

(g)

Biogas power plants 20 years.

(h)

Renewable hybrid energy project - Minimum of the Useful Life of different

RE technologies combined for Renewable Hybrid Energy Project for Composite Tariff as

specified under Regulation 57.

(i)

Renewable energy with storage project - Same as Useful Life of project assuming that

there is no storage.

(41)

‘Year’ means a financial year.

(2)

All other expressions used herein but not specifically defined herein but defined in the Act shall have

the meaning assigned to them in the Act. The other expressions used herein but not specifically defined

in the regulations or in the Act but defined under Haryana Electricity Reform Act, 1997 (Act 10 of

1998) or the Indian Electricity Grid Code or the Haryana Grid Code or the Haryana Electricity

Regulatory Commission (Terms and Conditions for determination of Tariff for Generation,

Transmission, Wheeling and Distribution & Retail Supply under Multi Year Tariff ) Regulations, 2019,

as amended / reenacted from time to time, shall have the meanings assigned to them respectively in the

Haryana Electricity Reform Act, 1997 (Act 10 of 1998) or the Indian Electricity Grid Code or the

Haryana Grid Code or any other relevant Regulations in vogue , provided that such definitions in the

Haryana Electricity Reform Act, 1997 are not inconsistent with the provisions of the Electricity Act,

2003;

Eligibility Criteria.— For the purpose of these regulations, a project shall be treated as renewable

energy power project, as acknowledged by MNRE only, meeting the following criteria:–

(a)

Wind power project – located at the wind sites having minimum annual mean Wind Power

Density (WPD) of 200 Watt/m2 measured at hub height of 100 meters and using new wind

turbine generators;

(b)

Small hydro project – located at the sites approved by State Nodal Agency / State Government /

self identified sites using new plant and machinery, and installed power plant capacity to be

lower than or equal to 25 MW at single location.

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(c)

Biomass power project – Biomass power projects using new plant and machinery using biomass

fuel sources.

(d)

Non-fossil fuel based co-generation project – The project that uses new plant and machinery,

and is based on topping cycle mode of co-generation.

Topping cycle mode of co-generation – Any facility that uses non-fossil fuel input,

including bagasse, 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 crushing season.

Explanation.— For the purposes of this clause,

(i)

‘Useful power output’ is the gross electrical output from the generator. There will be an

auxiliary consumption in the cogeneration plant itself (e.g. the boiler feed pump and the

FD/ID fans). In order to compute the net power output, it would be necessary to subtract

the auxiliary consumption from the gross output. For simplicity of calculation, the useful

power output is defined as the gross electricity (kWh) output from the generator.

(ii)

‘Useful Thermal Output’ is the useful heat (steam) that is provided to the process by the

cogeneration facility.

(iii)

‘Energy Consumption’ of the facility is the useful energy input that is supplied by the

fuel (normally bagasse or other such biomass).

(iv)

‘Topping Cycle’ means a co-generation process in which thermal energy produces

electricity followed by useful heat application.

(e)

Processed Municipal Solid Waste based WtE power projects – The project shall qualify to be

termed as Municipal Solid Waste based WtE power projects, if it is using new plant and

machinery and using Municipal solid waste as fuel source for generation of electricity.

(f)

Solar PV and Solar Thermal Power Projects – Based on Technologies approved by MNRE /

HAREDA.

(g)

Biomass Gasifier Power Projects – The projects shall qualify as gasifier based power project

provided it is using new plant and machinery and having a grid connected system that

uses 100% syngas/producer gas engine with MNRE approved gasification technology and shall

use non fossil fuel as approved by MNRE.

(h)

Biogass Power Projects - The projects shall qualify as biogas based power project provided it is

using new plant and machinery and having a grid connected system that and uses 100% biogas

fired engine with MNRE approved technology.

(i)

Renewable hybrid energy project – The rated capacity of generation from one renewable energy

source is at least 25% of the rated capacity of generation from other renewable energy source(s),

which operate at the same point of interconnection:

Provided that energy is injected into grid at the same interconnection point and metering

is done at such common interconnection point accordingly.

(j)

Renewable energy with storage project – The renewable energy project including renewable

hybrid energy project that uses, partly or fully, renewable energy generated from such project to

store energy into storage facility which is connected at the same point of interconnection as the

renewable energy project.

Explanation:

The necessity of new plant and machinery shall be applicable where tariff is determined by

the Commission under Section 62 of the Act as well as procurement of power by the Distribution

Licensee(s) under Section 63 of the Act in case the bidding documents / guidelines so provides. The

dispensation shall include the RE Projects where capital subsidy is claimed by the project developer.

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Chapter – 2

Norms

Control Period or Review Period. – The Control Period for the purpose of tariff determination under these

Regulations shall be from the FY 2021-22 to the FY 2024-25.

Provided that the benchmark capital cost and tariff for Solar PV rooftop, ground mounted, canal

based / Water Works solar projects, wind power, small hydro shall be determined on case specific basis only.

Provided also that the revision in Regulations for next Control Period shall be undertaken at least

six months prior to the end of the first Control Period and in case Regulations for the next Control Period are

not notified until commencement of next Control Period, the tariff norms as per these Regulations shall

continue to remain applicable until notification of the revised Regulations and the Control Period shall be

deemed to have been extended up to the date of notification of the next Control Period.

Tariff Period. –

(1)

The Tariff Period for Renewable Energy power projects shall generally correspond to their

respective project life or as may be agreed upon in the PPA.

(2)

Tariff period under these Regulations is for Renewable Energy Power Plants with entirely new

plant and machinery. The first year tariff shall be applicable from the CoD of the project and shall

continue for 12 months from the CoD and thereafter the tariff for the second year shall be

applicable on year to year basis i.e. for first 12 months from CoD, first year tariff shall be

applicable, then for next twelve months second year tariff shall be applicable and so on and each

period of such 12 months shall be termed as the tariff year.

(3)

Tariff determined as per these Regulations shall be applicable for Renewable Energy power

projects, only for the duration of the Tariff Period as stipulated under Regulation 5(1).

Project Specific tariff. –

(1)

Subject to the “Scope and Extent of application” of these Regulations, the project specific tariff, on

case to case basis, may also be determined by the Commission for the following types of projects:

(a)

Processed Municipal Solid Waste (WtE) Projects

(b)

Poultry litter / Cow dung etc.

(c)

small / micro hydro power projects of 25 MW and below

(d)

Renewable energy with storage projects

(e)

Biomass project other than that based on Rankine Cycle technology application with water

cooled / air cooled condenser.

(f)

Non-fossil fuel based co-generation project

(g)

Any other new renewable energy technologies that may be approved by MNRE i.e. Solid

oxide fuel cell (SOFC) etc.

(2)

Determination of Project specific Tariff for generation of electricity from such renewable energy

sources shall be in accordance with such terms and conditions as stipulated by the Commission.

Provided that the financial and operational norms as specified in these Regulations, shall be ceiling

norms while determining the project specific tariff.

Provided further that the levelized tariff of project calculated on the basis of norms specified in

these Regulations shall be the ceiling tariff.

(3)

Scope and extent of application:

These Regulations shall apply to the RE Power Projects set-up / to be set – up in Haryana and

where the tariff is determined by the Commission u/s 62 of the Act for Grid Connected RE Projects up to an

installed capacity of 2 MW except the general provisions for banking, RPO, Late Payment Surcharge / rebate

etc. applicable for all concerned.

Provided that the Discoms/HPPC shall endeavor to purchase all electricity through competitive

bidding route in accordance with the provisions of Section 63 of the Electricity Act, 2003

Provided where tariff is adopted by the Commission under section 63 of the Act, the terms and

conditions of the Guidelines as mentioned in section 63 of the Act and the bidding documents thereto shall

prevail.

Provided HAREDA shall endeavour to promote better and efficient usage of biomass disposal such

as setting up of Compressed Bio Gas (CBG), ethanol, bio fuel, Green Hydrogen etc., so as incineration of

biomass/bio waste/municipal waste even under controlled environment for electricity generation be

minimized.

PART III]

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Petition and proceedings for determination of tariff. –

(1)

The Commission shall determine the indicative tariff on the basis of suo-motu petition at least six

months in advance at the beginning of each year of the Control period for renewable energy

technologies for which norms have been specified under the Regulations.

(2)

A petition for determination of project specific tariff shall be accompanied by such fee as may be

specified in the HERC Fee Regulations in vogue and shall be accompanied by the following:-

Information in forms 1.1, 1.2, 2.1 and 2.2 as the case may be, and as appended to these

regulations;

Detailed project report outlining technical and operational details, site specific aspects,

premise for capital cost and financing plan etc.

A statement of all applicable terms and conditions and expected expenditure for the period

for which tariff is to be determined.

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 include the proposed tariff calculated without consideration of the

subsidy and incentive.

Following documents in case of petition for determination of project specific tariff by

renewable energy projects, where tariff from such renewable energy sources is generally

determined through competitive bidding process in accordance with provisions of

Section 63 of the Act:

Rationale for opting project specific tariff instead of competitive bidding; and

ii.

Competitiveness of the proposed tariff vis-à-vis tariff discovered through

competitive bidding/ tariff prevalent in the market.

iii.

Comparative details showing that the tariff proposed is aligned with the prevalent

market conditions.

Any other information that the Commission may require the petitioner to submit.

(3)

The proceedings for determination of tariff shall be in accordance with the HERC (Conduct of

Business) Regulations 2019, as amended from time to time.

Tariff Structure.–

(1)

The tariff for renewable energy technologies shall be single part tariff consisting of the following

fixed cost components:-

(a)

Return on equity capital;

(b)

Interest on loan capital;

(c)

Depreciation;

(d)

Interest on working capital including margin money;

(e)

Operation and maintenance expenses;

Provided that for renewable energy technologies having fuel cost component, like biomass power

projects and non-fossil fuel based cogeneration, single part tariff with two components, fixed cost

component and fuel cost component, shall be determined. The fuel cost component may be subjected to

escalation/de-escalation for computing level lised generic tariff for entire useful life of the project as

provided in these Regulations.

Provided that MAT/Corporate Tax shall be a pass through on submission of supporting documents.

The same shall be limited to applicable tax rate on the normative return on equity.

Tariff Design. –

(1)

The generic tariff, for the control period as per these Regulations, shall be determined, for the entire

tariff period/useful life of the project.

Provided that for renewable energy projects having single part tariff with two components

viz. fixed cost component shall be determined on levelized basis considering the year of

commissioning of the project while fuel cost component shall be determined on annual basis and

the same shall also be prospectively (i.e. from the date of the Order) applicable for the projects

commissioned during the previous control periods.

The State Nodal Agency i.e. HAREDA shall collect the relevant data on fuel cost and submit

the same to the Commission on a half yearly basis.

PART III]

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Chapter – 3

Financial Principles

11.

Capital Cost. – The norms for the Capital cost as specified in the subsequent technology specific chapters

shall be inclusive of land cost, pre-development expenses, all capital work including plant and machinery,

initial spares, civil work, erection and commissioning, financing and interest during construction, and

evacuation infrastructure up to the 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, including DPR, Lender’s Engineer Report and

justification (item-wise) for any time/cost over-run.

Provided further that in case where land for the project is acquired on lease basis, the cost of land to

be considered as part of capital cost shall be determined as per the Land Lease Agreement (s).

12.

Debt Equity Ratio. –

(1)

For generic tariff to be determined, based on suomotu petition, the normative debt equity ratio shall

be 70: 30.

(2)

For Project specific tariff, 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 also that debt equity ratio shall be considered after deducting the amount of grant or

capital subsidy received for the project for arriving at the amount of debt and equity.

Explanation-The premium, if any, raised by the generating company, while issuing share capital

and investment of internal resources created out of its free reserve, for the funding of the project, shall be

reckoned as paid up capital for the purpose of computing return on equity, subject to the ceiling limit

of 30%, only if such premium amount and internal resources are actually utilised for meeting the capital

expenditure of the renewable energy project. The un-discharged liabilities, if any, shall be reduced from the

capital cost.

13.

Loan and Finance Charges. –

(1)

For the purpose of determination of tariff, loan tenure of 13 years shall be considered.

(2)

(a)

The loans arrived at in the manner indicated above shall be considered as gross normative

loan for calculation for interest on loan. The normative loan outstanding as on 1st April of

every year shall be worked out by deducting the cumulative repayment up to March 31st of

the previous year from the gross normative loan.

(b)

For the purpose of computation of tariff, the normative interest rate shall be considered as the

average Marginal Cost of funds-based lending rate (MCLR) (one-year tenor) of SBI

prevailing during the last six months plus a margin of up to 200 basis points i.e. 2%.

(c)

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.

14.

Depreciation. –

(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 10%.

Provided that, no depreciation shall be allowed to the extent of grant or capital subsidy received for

the project. Provided further that land is not a depreciable asset, and hence, its cost shall be

excluded while computing 90% of the original cost of asset eligible for depreciation.

(2)

Depreciation per annum shall be based on ‘Differential Depreciation Approach’ over loan tenure

and period beyond loan tenure over useful life computed on ‘Straight Line Method’. The

depreciation rate for the first 13 years of the Tariff Period shall be 5.38% per annum charged on the

capital cost and the remaining depreciation (i.e. 90% of the capital cost as reduced by the

depreciation charged in first 13 years) shall be spread over the remaining useful life of the project

from 14th year onwards.

(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 on pro rata basis.

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[PART III

15.

Return on Equity. –

(1)

The value base for computing equity eligible for return shall be lower of the two either 30% of the

capital cost or actual equity (in case of project specific tariff determination) as determined under

these Regulations.

(2)

The normative Return on Equity shall be as under:-

14% per annum calculated on normative Equity Capital.

MAT/Corporate Tax applicable shall be considered as pass through.

Provided that the applicable MAT / Corporate Tax shall be separately invoiced as per the

actual paid at the rate as declared by the Income Tax Department. The Generator shall raise the bill

for reimbursement of MAT / Corporate Tax applicable on Return on Equity in 12 equal installments

which shall be payable by the beneficiaries.

16.

Interest on Working Capital. –

(1)

The Working Capital requirement in respect of wind energy projects, small hydro power, solar PV

and Solar thermal power projects and Processed Municipal Solid Waste (WtE) projects shall be

computed in accordance with the following :-

(a)

Operation & Maintenance expenses for one month;

(b)

Receivables equivalent to 2 (two) months of fixed and energy charges for sale of

electricity calculated on the normative CUF / PLF;

(c)

Maintenance spare @ 15% of operation and maintenance expenses.

(2)

The Working Capital requirement in respect of biomass power projects (Rankine Cycle

Technology), Biomass Gasifier / Bio gas based projects and bagasse / non-fossil fuel based

co-generation projects shall be computed as under:-

(a)

Fuel costs for four months at normative PLF;

Provided that fuel cost for six months at normative PLF shall be provided for

projects using Paddy Straw as single fuel.

(b)

Operation & Maintenance expense for one month;

(c)

Receivables equivalent to 2 (Two) months of fixed and variable charges for sale of

electricity calculated on the normative PLF;

(d)

Maintenance spare @ 15% of operation and maintenance expenses.

(3)

Interest on Working Capital, for the purpose of tariff determination, shall be computed at the

average Marginal Cost of funds based lending rate (MCLR) (one year tenor) of SBI prevailing

during the last available six months plus an appropriate margin not exceeding 200 basis

points i.e. 2%.

(4)

In case of renewable hybrid energy projects, the Working Capital requirement shall be the sum of

the Working Capital requirement determined as per norms applicable for renewable energy sources,

in proportion to their rated capacity in the project.

17.

Operation and Maintenance Expenses. –

(1)

‘Operation and Maintenance or O&M expenses’ shall comprise repair and maintenance (R&M),

establishment including employee expenses, and administrative and general expenses.

(2)

Operation and maintenance expenses shall be determined for the Tariff Period based on normative

O&M expenses specified in these Regulations for the first Year of the Control Period.

(3)

Normative O&M expenses allowed during the first year of the Control Period under these

Regulations shall be escalated at the rate of 2.93% per annum over the Tariff Period.

18.

Rebate. –

(1)

For payment of bills of the generating company through letter of credit, a rebate of 2% shall be

allowed.

(2)

Where payments are made other than through letter of credit within a period of 30 days of

presentation of bills by the generating company, a rebate of 1% shall be allowed.

Explanation.— In case of computation of 30 days, the number of days shall be counted

consecutively without considering any holiday. However, in case the last day

or 30th day is official holiday, the 30th day for the purpose of rebate shall be

construed as the immediate succeeding working day.

PART III]

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19.

Late payment surcharge. –

(1) Late Payment Surcharge shall be payable on the payment outstanding after the due date at the base

rate of Late Payment Surcharge applicable for the period for the first month of default.

(2) The rate of Late Payment Surcharge for the successive months of default shall increase by 0.5 percent

for every month of delay provided that the Late Payment Surcharge shall not be more than 3 percent

higher than the base rate at any time:

Provided that the rate at which Late Payment Surcharge shall be payable shall notbe higher

than the rate specified in the agreement, if any.

Provided further that, if a distribution licensee has any payment including Late Payment

Surcharge outstanding against a bill after the expiry of seven months from the due date of the bill, it

shall be debarred from procuring power from a power exchange or grant of short-term open access till

such bill is paid.

Whereas;

“base rate of Late Payment Surcharge” means the marginal cost of funds based lending rate

(MCLR) for one year of the State Bank of India, as applicable on the 1st April of the financial year in which

the period lies, plus five percent and in the absence of marginal cost of funds based lending rate, any other

arrangement that substitutes it, which the Central Government may, by notification, in the Official Gazette,

specify;

Provided that if the period of default lies in two or more financial years, the base rate of Late Payment

Surcharge shall be calculated separately for the periods falling in different years.

“due date” means the date by which the bill for the charges for power supplied by the generating

company are to be paid, in accordance with the Power Purchase Agreement, Power Supply Agreement, as

the case may be, and if not specified in the agreement, forty-five days from the date of presentation of the

bill by such generating company.

“Late Payment Surcharge” means the charges payable by the distribution company to a generating

company for power procured from it on account of delay in payment of monthly charges beyond the due

date.

20.

Sharing of CDM Benefits. –

(1) The proceeds of carbon credit from approved CDM project, after deduction of expenses incurred by

the generating company for registration and approval of the project as CDM project shall be shared

between generating company and beneficiaries concerned in the following manner:-

100% 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 i.e. 12 months

from CoD;

In the second year, the share of the beneficiaries shall be 10% which shall be progressively

increased by 10% every year till it reaches 50%, where after the proceeds shall be shared in

equal proportion, by the generating company and the beneficiaries.

Provided that in case the Concession Agreement or PPA has specific provision regarding sharing of

CDM benefits, the same shall be applicable in such cases.

21.

Sharing of Other Income – Other Income i.e. proceeds from sale of bio-fertilizer/bye products etc. shall be

shared in equal proportion, by the generating company and the beneficiaries.

22.

Subsidy or incentive by the Central / State Government. – The Commission shall take into consideration

any incentive or subsidy offered by the Central or State Government, available across the board to all the

generating company, for the renewable energy power plants while determining tariff under these

Regulations.

Provided, where there is no up-front subsidy/grant/incentive, the tariff shall be worked out without

subsidy/grant/incentive.

Provided further that any such assistance received by the generator shall be immediately passed on to

the beneficiary.

Any grant, subsidy or incentives availed by renewable energy project, which is not considered at time

of determination of tariff, shall be deducted by the beneficiary in subsequent bills after receipt of such grant,

subsidy or incentive in suitable instalments or within such period as may be stipulated by the Commission.

23.

Taxes and Duties. – Tariff determined under these regulations shall be exclusive of taxes and duties as may

be levied by the appropriate Government. Any tax / duty levied by the appropriate Government shall be

allowed as pass through on actual incurred basis and should have been actually paid to the authority (ies)

concerned.

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[PART III

Chapter – 4

Technology specific parameters for Wind Energy

24.

Capital Cost.–

(1)

The capital cost for wind energy project shall include land cost Wind turbine generator including its

auxiliaries, site development charges and other civil works, transportation charges, evacuation cost

up to inter-connection point, financing charges and IDC. Provided in case of land obtained on lease,

cost of land shall be taken as per lease agreement.

(2)

Given the limited potential for setting up wind energy projects in Haryana, the Commission, on an

application received from a prospective wind power generator / developer and willingness of the

Disocoms / HPPC to purchase such power, shall determine capital cost for wind energy projects,

O&M expenses and tariff based on the market trends prevailing during the relevant year w.r.t.

scheduled CoD of such projects on case specific basis only.

25.

Capacity Utilization Factor. –

(1)

CUF norms for the control period shall be as follows:-

Annual Mean Wind Power

Density (W/m2)

CUF

Up to 220

22%

221- 275

24%

276- 330

28%

331- 440

33%

441 +

35%

Provided that the number of hours for calculation of CUF shall be 8766 hours.

(2)

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

(3)

For the purpose of classification of wind energy project into particular wind zone class, the

State-wise wind power density map prepared by Centre for Wind Energy Technology (C-WET) /

MNRE / NIWE , shall be considered.

Provided that the Commission may by notification amend the schedule from time to time, based on

MNRE guidelines / NIWE for wind measurement or by the private developer.

Provided in the case of wind measurement data submitted by wind power developer the same shall

be acceptable in case it is validated by NIWE.

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[PART III

Chapter – 6

Technology specific parameters for Biomass based Power Projects

30.

Technology Aspect. – The norms for tariff determination specified hereunder are for biomass power

projects based on Rankine Cycle technology application using water cooled condenser and air cooled

condenser, with Travelling grate or AFBC boiler.

31.

Capital Cost. –

(1)

The normative capital cost, during the control period under these Regulations, for the biomass

power projects using fuel other than Rice Straw/Stubble shall be Rs. 5.59 Crore / MW (Water

Cooled Condenser) and Rs. 6.0 Crore / MW for projects using Air Cooled Condenser.

Provided for the project using Rice Straw / Stubble as single fuel for generation of power the

Capital Cost, during the control period, shall be Rs. 6.10 Crore / MW (Water Cooled Condenser) and

Rs. 6.52 Crore / MW for projects having air cooled condenser.

32.

Plant Load Factor. –

For the purpose of determination of tariff, the Plant Load Factor shall be considered as 80%.

33.

Auxiliary Energy Consumption. – The auxiliary energy consumption shall be 10% in the case of projects

equipped with water cooled condenser and 12% for air cooled condenser, for the purpose of tariff

determination.

34.

Station Heat Rate. – The Station Heat Rate for biomass power projects shall be 4125kCal / kWh and 4063

Kcal / kWh for projects equipped with travelling grate boiler and AFBC boiler respectively. Provided for the

project using Rice Straw / Stubble as single fuel for generation of power the Station Heat Rate, during the

control period, shall be as under:-

Water Cooled – Travelling Grate

4200 kcal/kWh

Air Cooled – Travelling Grate

4200 kcal/kWh

Water Cooled – AFBC Boiler

4125 kcal/kWh

Air Cooled – AFBC Boiler

4125 kcal/kWh

35.

Operation and Maintenance Expenses. –

(1)

Normative O&M expenses for the first year of the Control period (i.e. FY 2021-22) shall be Rs.

0.4642 Crore /MW.

(2)

Normative O&M expenses allowed at the commencement of the Control Period (i.e. FY 2021-22)

under these Regulations shall be escalated at the rate of 2.93% per annum.

36.

Fuel Mix. –

(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, from time to

time.

(2)

The Biomass Power Generating Companies shall have appropriate fuel management plan to ensure

adequate availability of fuel to meet the respective project requirements.

(3)

Use of Fossil Fuel shall not be permitted. However, at least 30% of the fuel requirement shall be

met from Paddy Straw by all biomass/non- fossil based cogeneration plants.

(4)

The Project developer shall furnish monthly fuel (biomass mix) usage statement and monthly fuel

(biomass mix) procurement statement duly certified by Chartered Accountant to the beneficiary

(with a copy to appropriate agency that may be appointed / designated by the Commission for the

purpose of monitoring fuel consumption and usage) for each month, along with the monthly energy

bill.

(5)

Non-compliance of the aforesaid condition of fossil fuel usage by the project developer, during any

financial year, shall result in withdrawal of applicability of tariff as per these Regulations for such

biomass based power project. In such cases the PPA(s) shall be terminated and the Discoms

(beneficiaries) shall be under no obligation to make any payments for the power supplied by the

seller in breach of the regulation on fuel usage.

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[PART III

Chapter – 7

Technology specific parameters for Non-fossil fuel based Cogeneration Projects

39.

Technology Aspect. – A project shall qualify as a non-fossil fuel based Co-generation project, if it is in

accordance with the definition as specified under these Regulations.

40.

Capital Cost. - The normative capital cost for the non-fossil fuel based cogeneration projects shall be

Rs. 4.925 Crores/MW during the control period, under these Regulations.

41.

Plant Load Factor. –

(1)

For the purpose of determining fixed charge, the plant load factor for non-fossil fuel based

cogeneration projects shall be computed on the basis of plant availability for number of operating

days considering operations during crushing season and off-season.

(2)

The number of operating days shall be 150 days (crushing) + 60 days (off-season) = 210 days

operating days and the Plant Load Factor shall be 53%.

(3)

Plant Load Factor for biomass based co-generation using fuel other than bagasse shall be 80%.

42.

Auxiliary Energy Consumption. – The auxiliary energy consumption factor shall be 8.5% for the purpose

of tariff determination.

43.

Station Heat Rate. –Station Heat Rate of 3600 kCal / kWh for power generation component shall be

considered for computation of tariff for non-fossil fuel based Cogeneration projects.

44.

Calorific Value. – The Gross Calorific Value for Bagasse shall be considered as 2250 kCal/kg. Further, the

Gross Calorific Value for Non Fossil Fuel based Cogeneration (other than Bagasse) shall be considered as

3100 kCal/kg.

45.

Fuel Cost.–

(1)

The price of Bagasse shall be Rs. 1027/ MT and shall be escalated at the rate of 2.93% per annum

for determination of levellised tariff for the entire useful life of the project.

(2)

The price of other Non Fossil Fuel shall be Rs. 3000/ MT and shall be escalated at the rate of 2.93%

per annum for determination of levelized tariff for the entire useful life of the project.

46.

Operation and Maintenance Expenses. –

(1)

Normative O&M expenses during first year of the Control Period shall be Rs. 0.24 Crore / MW.

(2)

The normative O&M expenses allowed at the commencement of the Control Period i.e. the FY

2021-22 under these Regulations shall be escalated at the rate of 2.93% per annum.

PART III]

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154

Chapter – 14

Renewable purchase obligation (RPO) and Renewable Energy Certificate (REC)

62.

Renewable Purchase Obligation. –

(1)

Every obligated entity including distribution licensee, consumers owning captive power plant and

open access consumers including short term open access consumers in Haryana, shall purchase

energy from renewable energy sources under the Renewable Purchase Obligation (RPO) as under:-

Year

Solar RPO*

Non Solar RPO

Total RPO

HPO**

Other Non Solar

RPO*

Total Non Solar

RPO *

2021-22

8.00%

0.00

3.00%

11.00%

2022-23

9.00%

0.35%

5.00%

5.35%

14.35%

2023-24

10.00%

0.66%

6.00%

6.66%

16.66%

2024-25

To be

specified later

1.08%

To be specified

later

To be specified

later

To be specified

later

2025-26

1.48%

2026-27

1.80%

2027-28

2.15%

2028-29

2.51%

2029-30

2.82%

** HPO within Non Solar Renewable Purchase Obligation (RPO) means “Hydropower Purchase

Obligation, to be met from purchase of power/Hydro Energy Certificates from Large Hydropower

Projects having capacity of more than 25 MW (LHPs) which come into commercial operation after

08.03.2019.

(2)

RPO shall be calculated in energy terms as a percentage of total consumption of electricity

excluding consumption met from RE sources and hydro sources (LHPs).

(3)

Solar RPO may be met by power produced from solar power plants — solar photo voltaic or

solar-thermal.

(4)

Other Non-Solar RPO (excluding HPO), may be met from any renewable source other than solar

and LHPs.

(5)

HPO benefits may be met from the power procured from eligible LHPs commissioned on and

after 8.3.2019 and upto 31.03.2030 in respect of 70% of the total generated capacity for a period of

12 years from the date of commissioning. Free power is to be provided as per agreement with the

State Government and that provided for Local Area Development Fund (LADF), shall not be

included within this limit of 70% of the total generated capacity.

(6)

HPO liability of the State/ Discom could be met out of the free power being provided to the State

from LHPs commissioned after 08.03.2019 as per agreement at that point of time excluding the

contribution towards LADF if consumed within the State/Discom. Free power (not that contributed

for Local Area Development) only to extent of HPO liability of the State/Discom, shall be eligible

for HPO benefit.

(7)

In case the free power, as above, is insufficient to meet the HPO obligations, then the State would

have to buy the additional hydro power to meet its HPO obligations or may have to buy the

corresponding amount of Hydro Energy Certificate to meet the non-solar hydro renewable purchase

obligations.

(8)

The Hydro Energy Certificate issued under the mechanism developed by CERC shall be valid

instruments for the discharge of the HPO obligations.

(9)

The above HPO Trajectory shall be trued up on an annual basis depending on the revised

commissioning schedule of Hydro projects.

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[PART III

(10)

Hydro power imported from outside India shall not be considered for meeting HPO.

(11)

On achievement of Solar RPO compliance to the extent of 80% and above, remaining shortfall, if

any, can be met by excess non-solar energy consumed beyond specified Non-Solar RPO for that

particular year. Similarly, on achievement of Other Non-Solar RPO compliance to the extent of

80% and above, remaining shortfall if any, can be met by excess solar or eligible hydro energy

consumed beyond specified Solar RPO or HPO for that particular year. Further, on achievement of

HPO compliance to the extent of 80% and above, remaining shortfall, if any, can be met by excess

solar or other non—solar energy consumed beyond specified Solar RPO or Other Non-Solar RPO

for that particular year.

(12)

RPO for fossil fuel based Captive Power Plants (CPP) of 5 MW and above including Fossil fuel

based co-generation captive plant of 5MW and above, shall be pegged at the RPO level applicable

in the year in which CPP is commissioned. However, RPO of such plants commissioned up to

2018-19 shall be pegged at RPO applicable for the FY 2018-19. As and when the company add to

the capacity of the CPP, it will have to provide for additional RPO as obligated in the year in which

new capacity is commissioned.

(13)

The DISCOMs, while complying with the RPO, shall ensure trade-off between REC & purchase of

RE Power and take financial prudent action accordingly.

Provided further, such obligation to purchase renewable energy shall be inclusive of the purchases,

if any, from renewable energy sources already being made by obligated entity concerned.

Provided also that the power purchases under the power purchase agreements for the purchase of

renewable energy sources already entered into by the distribution licensees and consented to by the

Commission shall continue to be made till validity of the Power Purchase Agreement approved by the

Commission, even if the total purchases under such agreements exceed the RPO as specified in these

regulations.

63.

Certificates under the Regulations of the Central Commission. –

(1)

Subject to the terms and conditions contained in these regulations the Certificates issued under the

Central Electricity Regulatory Commission (Terms and Conditions for recognition and issuance of

Renewable Energy Certificate for Renewable Energy Generation) Regulations, 2010 shall be the

valid instruments for the discharge of the mandatory obligations set out in these regulations for the

obligated entities to purchase electricity from renewable energy sources.

Provided that in the event of the obligated entity fulfilling the renewable purchase obligation by

purchase of certificates, the obligation to purchase electricity from generation based on solar as renewable

energy source can be fulfilled by purchase of solar certificates only, and the obligation to purchase electricity

from generation based on renewable energy other than solar can be fulfilled by purchase of non-solar

certificates.

(2)

Subject to such direction as the Commission may give from time to time, the obligated entity shall

act in consistent with the Central Electricity Regulatory Commission (Terms and Conditions for

recognition and issuance of Renewable Energy Certificate for Renewable Energy Generation)

Regulations, 2010 notified by the Central Commission and as amended from time to time in regard

to the procurement of the certificates for fulfillment of the Renewable Purchase Obligation under

these regulations.

(3)

The Certificates purchased by the obligated entities from the power exchange in terms of the

regulation of the Central Commission mentioned in sub regulation (1) of this Regulation shall be

deposited by the obligated entities to the Commission in accordance with the detailed procedure

issued by the Central Agency.

The Obligated Entities including the Power Utilities in Haryana under these Regulations may meet its RPO

target by way of own generation or procurement of power from RE developer or by way of purchase from other

licensee or by way of purchase of Renewable Energy Certificate or by way of combination of any of the above

options. However, RE power generated in States other than in the State of Captive Generator, by an obligated entity

shall not qualify for fulfilment of RPO in Haryana.

Provided that in the case of an obligated entity with conventional captive power generation plant as defined

in the Electricity Act, 2003, may meet their RPO, solar and non solar as the case may be by self / own generation in

Haryana of respective renewable power.

PART III]

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156

64.

State Agency. –

(1)

The Commission designates Haryana Renewable Energy Development Agency (HAREDA) as the

State Agency for accreditation and recommending the renewable energy projects for registration

and to undertake functions in sync with regulation 38.

(2)

The State Agency shall function in accordance with the directions issued by the Commission and

shall act in consistent with the procedures rules laid by Central Agency for discharge of its

functions under the Central Electricity Regulatory Commission (Terms and Conditions for

recognition and issuance of Renewable Energy Certificate for Renewable Energy Generation)

Regulations, 2010 as amended from time to time.

(3)

The State Agency shall submit quarterly status to the Commission in respect of compliance of

renewable purchase obligation by the obligated entities in the format as stipulated by the

Commission and may suggest appropriate action to the Commission if required for compliance of

the renewable purchase obligation.

(4)

If the Commission is satisfied that the State Agency is not able to discharge its functions

satisfactorily, it may by general or special order, and by recording reasons in writing, designate any

other agency to function as State Agency as it considers appropriate.

65.

Effect of default. –

(1)

If the obligated entities do not fulfill the renewable purchase obligation as provided in these

regulations during any year and also does not purchase the certificates, the Commission may direct

the obligated entity to deposit into a separate fund, to be created and maintained by such obligated

entity, such amount as the Commission may determine on the basis of the shortfall in the RPO

determined under these regulations from time to time at the forbearance price notified by the

Central Commission.

Provided that the fund so created shall be utilized, as may be directed by the Commission,

for purchase of the renewable energy certificates.

Provided further that the Commission may empower an officer of the State Agency to

procure from the Power Exchange the required number of certificates to the extent of the shortfall

in the fulfillment of the obligations, out of the amount in the fund.

Provided also that the distribution licensee shall be in breach of its licence condition if it fails

to deposit the amount directed by the Commission within 30 days of the communication of the

direction or within such period as directed by the Commission.

(2)

Where any obligated entity fails to comply with the obligation to purchase the required percentage

of power from renewable energy sources or the renewable energy certificates, it shall also be liable

for penalty as may be decided by the Commission under section 142 of the Act.

Provided that in case of genuine difficulty in complying with the renewable purchase

obligation because of limited availability of renewable energy or non-availability of certificates, the

obligated entity can approach the Commission for relaxation or carry forward of compliance

requirement to the next year. However, in normal circumstances, the renewable purchase obligation

shall not be waived of.

Provided further that where the Commission has consented in writing on an application made

by the obligated entity to carry forward of compliance requirement, the provision of regulation

65 (1) of these Regulation or the provision of section 142 of the Act shall not be invoked.

(3)

Where any obligated entity being an Open Access Consumer, fails to comply with the obligation to

purchase the required percentage of power from renewable energy sources or the renewable energy

certificates, on or before 30th April next following the relevant Financial Year, in addition to the

consequences mentioned in sub clause 1 & 2 above, Open Access shall not be granted to such

consumers w.e.f. 01st May, till the time such Open Access Consumer fulfills RPO obligations.

Such obligated Open Access Consumers, shall have to submit the proof of compliance of RPO to

DISCOMs.

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[PART III

66.

Banking of RE Power. –

RE based captive generating plants of owner/consumer with 100 per cent equity holdingin the CPP may

bank power, up to contract demand for captive/own use on payment of the banking charges along with the

transmission and distribution losses (Technical loss) for availing the open access on the transmission or

distribution network of the licensees for banking and drawl of banked power from the Discoms after entering

into the banking agreement with the Discoms concerned at the terms and condition specified as under:

The RE power shall be allowed to be banked with the distribution licensee(s), upto the cumulative

contract capacity of 100 MW only, by levying banking charges @ Rs. 1.50/unit, after which the

Commission shall review the provisions of banking taking into consideration of the financial impact

on distribution companies.

The Energy Banked shall be permitted to be carried forwarded from month to month. The banked

power shall be utilized within the same financial year failing which the unutilized energy at the end of

the financial year shall lapse, and no compensation whatsoever shall be claimed/ paid for such lapsed

banked energy, provided the solar energy banked during the last quarter of the financial year shall be

carried forward to the next financial year.

Banked energy not drawn as per schedule, shall be considered as dumped energy & shall lapse.

The banking shall be allowed throughout the year, however, the drawl of banked power shall not be

allowed during the peak months (May to September).

The drawl of banked power shall also be not allowed during peak load hours as mentioned in the ToD

tariff approved by the Commission.

The Banked Energy Shall be calculated at the end of a month as follows:-

Banked Energy at the end of month (Ebi)= {Eg(1-losses)-Ec} * (1-b) + Eb (i-1)

* Eg = Energy Generation for the ith month

* Ec = Energy consumption for the ith month

* Eb (i-1) = Energy Banked at the end of previous month

*b = Banking charges in kind.

Further, as far as scheduling and deviation mechanism is concerned, the same shall be governed by

the separate Regulations notified by the Commission.

The RE power shall be adjusted as first charge in order of consumption of energy by a consumer. The

banking will be counted on daily basis for the purpose of monthly account.

Settlement of wheeled energy at consumer End shall be in the following order of priority:

RE generation after deduction of losses.

Captive Power

Banked Energy

Open Access Power through Exchange / Bi-lateral transactions

Discom power

67.

Cost of Evacuation System. – The State transmission utility or the Transmission/Distribution Licensee

shall bear the cost of Extra High Voltage (EHV)/ High Voltage (HV) transmission line up to a distance

of 10 Kms. from the inter-connection point, in case power is supplied to DISCOMs under PPA. In case the

distance between the inter connection point and point of grid connectivity is more than 10 Kms. then the cost

of transmission line for the distance beyond the 10 Kms. shall be borne equally between the Independent

Power Producer and the licensee. However, for canal based solar power projects, the transmission lines shall

be provided by the utilities, free of cost, irrespective of the distance of the project from the substation,

subject to the conditions that the solar power is generated and utilized within the state of Haryana and is

counted towards RPO of the Distribution Licensee(s).Transmission/Distribution Licensee shall bear the cost

of Extra High Voltage (EHV)/ High Voltage (HV) transmission line up to a distance of 10 Kms. and shared

cost after 10Kms, only in the case where the power is to be supplied to DISCOMs under approved PPA. RE

Power producers installed by Independent Power Producers (IPP) for merchant sale or captive consumption,

should bear the cost themselves. It is further clarified that the terms & conditions for cost of evacuation of

power in respect of PPA entered into by DISCOMs/HPPC with RE Power Producers under competitive

bidding, shall be governed by the terms of such PPA.

Further, the power utilities concerned, on being informed about the Scheduled Commissioning Date

(SCOD), shall complete the evacuation system well in time.

PART III]

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158

68.

(1)

Notwithstanding anything contained in any other Regulation(s) notified by the Commission,

Wheeling and Transmission Charges will be exempted for the entire life of the project from the date of

commissioning for all Captive Solar Power Projects which have submitted applications to Haryana

Renewable Energy Development Agency (HAREDA) for registration of project, purchased land or have

taken land on lease for thirty years and have bought equipment & machinery or invested at least Rs. one

crore per Mega Watt for purchase of equipment & machinery for setting up of such Captive Solar Power

Projects till 13th February, 2019, while cross subsidy surcharges and additional surcharges are not applicable

for Captive Solar Power Projects as per provisions of HERC Regulations (Electricity Act 2003). For

determining the investment of Rs. One crore per MW, payment for equipment should be made into the bank

accounts of equipment supplier before 13th February, 2019 and proof of the same is to be submitted.

(2)

No waiver of wheeling and transmission charges, cross subsidy surcharges and additional surcharges

shall be given to solar/non solar power Projects set up by IPP/generators for third party sale.

(3)

Against the waivers, Renewable Purchase Obligation (RPO) benefit will be provided to Power

Utilities.

However, the losses, as determined by the Commission, shall be recovered in kind by the Haryana

Power Utilities. Further, banking charges as per these Regulations, shall be applicable so that the Haryana

Power Utilities are not burdened un-reasonably.

69.

Cluster of rooftops of public / private buildings.– Some percentage capacity (to be fixed from time to

time) for the setting up of ground mounted mega watt scale grid connected power plants, to meet the solar

RPO shall be developed by setting up of grid connected rooftop solar power plants. For that the offers shall

be invited by Renewable Energy Department, Haryana/HAREDA from the independent power producers for

development of grid connected rooftop solar power plants, of capacity ranging from 250 kWp to 1 MW, on a

cluster of public private buildings on the last lowest tariff discovered and conveyed by HPPC. The entire

power produced by power producers who set up plants within four years from the date of notification of this

policy shall be purchased by the HPPC or any entity of Haryana Govt. Alternatively, the developer can also

supply/provide the power for the captive use of the premises where the system is installed along with net

meter and can sell the remaining power to HPPC or any entity of Haryana Govt. on the last lowest tariff

discovered and conveyed by HPPC or to third party as per HERC regulations.

The rooftop space available in the government organization, institutions, buildings or vacant land of

the same can also be provided on lease/rent to the Independent Power Producer/ RESCO developer for

setting up of solar power projects.

For such sites the lease/rent rate shall be decided by a Committee of Deputy Commissioner of

concerned district, PWD (B&R) Department and the Department owning the building. The developer can

also supply/provide the power for the captive use of the premises where the system is installed along with

net meter and can sell the remaining power to HPPC on the minimum last tariff discovered and conveyed by

HPPC or to third party as per the HERC Regulations.

70.

Discount Factor. – The discount factor for working out levelised generic tariff shall be the weighted

average cost of capital (WACC).

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[PART III

Chapter – 15

Miscellaneous

71.

The levelized tariff of the project calculated on the basis of the norms, specified in these regulations shall be

the ceiling levelized tariff.

72.

The provisions, if any, contained in any other regulation relating to reduction of contract demand

shall not be applicable for Rooftop Solar PV Power.

In case of additional cost on account of GST, the generator can approach the Commission with

necessary details for allowing additional tariff.

The imbalance charges as per Open Access Regulation will not be applicable for Solar Power

generated and consumed within the State in real time. However, Open Access consumers/generators

shall pay Rs. 1.50/unit for injection/drawal of solar power in the grid as reliability charges.

73.

Power to Relax. – The Commission may by general or special order, for reasons to be recorded in writing,

and after giving an opportunity of hearing to the parties likely to be affected may suo moto relax any of the

provisions of these regulations or on an application made before it by an interested person.

74.

Issue of orders or directions. – Subject to the provisions of the Act and these regulations, the Commission

may, from time to time, issue orders and procedural directions with regard to the implementation of these

regulations and specify the procedure to be followed on various matters, which the Commission has been

empowered by the regulations to direct and matters incidental thereto.

75.

Power to amend. – The Commission may, at any time, add, vary, modify or amend any of the provisions of

these regulations.

76.

Power to remove difficulties. – If any difficulty arises in giving effect to any of the provisions of these

regulations, the Commission may, by general or special order, make such provisions, which in the opinion of

the Commission are necessary or expedient to do so.

77.

Savings. – Nothing in these Regulations shall limit the inherent power of the Commission to make such

orders as may be necessary to meet the ends of justice or to prevent abuses of the process of law / statutes.

Nothing in these Regulations shall bar the Commission from adopting, any other procedure, which may be at

variance with any of the provisions of these Regulations, as long as they are in conformity with the

provisions of the Electricity Act, 2003 and the policies framed by the Central / State Government thereto.

Provided that the reasons for any such deviating shall be recorded in writing.

Provided also that nothing in these regulations shall, expressly or implicitly, bar the Commission

from dealing with any matter under these Regulations or exercising any power under the Act for which no

regulations have been framed.

PART III]

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

160

APPENDIX

Form-1.1: Template for (Wind power projects/ Small hydro projects/ Solar PV power projects/ Solar thermal

power projects/ Renewable energy hybrid power projects / Renewable energy with storage projects)

Sl.

No.

Assumption

Head

Sub-head

Sub-head (2)

Unit

Parameter

Power

Generation

Capacity

Installed Power Generation

Capacity

Capacity Utilization Factor

(CUF)

Auxiliary Consumption

Commercial Operation Date

(COD)

dd/mm/yyyy

Useful Life

Years

Project Cost

Capital Cost

Normative Capital Cost

Rs. Crore/ MW

Capital Cost

Rs. Crore

Capital Subsidy, if any

Rs. Crore

Net Capital Cost

Rs. Crore

Financial

Assumption

Debt Equity

Tariff Period

Years

Debt

Equity

Debt Component

Total debt amount

Rs. Crore

Total equity amount

Rs. Crore

Loan Amount

Rs. Crore

Moratorium Period

Years

Repayment Period

(incl moratorium)

Years

Interest Rate

Equity Component

Equity Amount

Rs. Crore

Return on Equity for

First 20 years

% p.a.

Return on Equity after 20 years

% p.a.

Discount Rate

Depreciation

Dep Rate for 1st 15 years

Dep rate 16th year onwards

Incentives

GBI, if any

Rs. Crore

Period for GBI

Years

PART III]

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

162

Form-1.2: Template for (Biomass/MSW/RDF)

Sl.

No.

Assumption

Head

Sub-head

Sub-head (2)

Unit

Parameter

Power Generation Capacity

Installed Power Generation

Capacity

Aux Consumption

PLF (1st year)

PLF (2nd year onwards)

Commercial Operation Date

dd/mm/yyyy

Useful Life

Years

Project Cost

Capital Cost/

Normative Capital Cost

Rs. Crore /MW

Capital Cost

Rs. Crore

Capital Subsidy, if any

Rs. Crore

Net Capital Cost

Rs. Crore

Financial

Assumption

Debt Equity

Tariff Period

Years

Debt

Equity

Debt

Component

Total debt amount

Rs. Crore

Total equity amount

Rs. Crore

Loan Amount

Rs. Crore

Moratorium Period

Years

Repayment Period (including

moratorium)

Years

Interest Rate

Equity

Component

Equity Amount

Rs. Crore

Return on Equity for First 20 years % p.a.

Return on Equity after 20 years

% p. a.

Discount Rate

Depreciation

Dep Rate for 1st 15 years

Dep rate 16th year onwards

Incentives

GBI, if any

Rs. Crore

Period for GBI

Years

O&M Expenses

Normative

O & M

Expenses

Rs. Lakh/MW

O & M

Expenses p.a.

Rs. Crore

Escalation

Factor

163

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

[PART III

Sl.

No.

Assumption

Head

Sub-head

Sub-head (2)

Unit

Parameter

Working Capital

O&M

Expenses

Month

Maintenance

Spares

% of O&M Expenses

Receivables

Days

Interest on WC

Fuel Related

assumptions

Station Heat

Rate

During 1st year

kcal/kWh

2nd year onwards

kcal/kWh

Fuel Type and

mix

Biomass Fuel Type-1

Biomass Fuel Type-2

Municipal Solid Waste

Refuse Derived Fuel

Fossil Fuel (Coal)

GCV of Biomass Fuel Type-1

kcal/kWh

GCV of Biomass Fuel Type-2

kcal/kWh

GCV of MSW

kcal/kWh

GCV of RDF

kcal/kWh

GCV of Fossil Fuel (Coal)

kcal/kWh

Biomass Price (Fuel Type-1)/ Yr 1

Rs./MT

Biomass Price (Fuel Type-2)/ Yr 1

Rs./MT

MSW Price/ Yr 1

Rs./MT

RDF Price/ Yr 1

Rs./MT

Fossil Fuel (Coal) Price)/ Yr 1

Rs./MT

Fuel Price Escalation Factor

% p.a.

PART III]

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

164

Form-2.1: Template for (Wind power projects or Solar PV power projects /Solar thermal power projects):

Determination of Tariff Components

Units Generation

Unit

Yr-1

Yr-2

Yr-3

Yr-4

Yr-5

Yr-6

Yr-7

Yr-8

Yr-9

Yr-10 Yr-11 Yr-12

Installed Capacity

Net Generation

Units Generation

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

Installed Capacity

Net Generation

Tariff Components

(Fixed charge)

Unit

Yr-1

Yr-2

Yr-3

Yr-4

Yr-5

Yr-6

Yr-7

Yr-8

Yr-9

Yr-10 Yr-11 Yr-12

O&M Expenses

Rs Lakh

Depreciation

Rs Lakh

Interest on term loan Rs Lakh

Interest on working

Capital

Rs Lakh

Return on Equity

Rs Lakh

Total Fixed Cost

Rs Lakh

Tariff Components

(Fixed charge)

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

O&M Expenses

Rs Lakh

Depreciation

Rs Lakh

Interest on term loan Rs Lakh

Interest on working

Capital

Rs Lakh

Return on Equity

Rs Lakh

Total Fixed Cost

Rs Lakh

Per Unit Tariff

components

Unit

Yr-1

Yr-2

Yr-3

Yr-4 Yr-5

Yr-6

Yr-7

Yr-8

Yr-9 Yr-10 Yr-11 Yr-12

PU O&M expenses

Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term loan Rs/kWh

PU Interest on working

capital

Rs/kWh

PU Return on Equity

Rs/kWh

PU Tariff Components

Rs/kWh

Per Unit Tariff

components

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

PU O&M expenses Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term

loan

Rs/kWh

PU Interest on

working capital

Rs/kWh

PU Return on

Equity

Rs/kWh

PU Tariff

Components

Rs/kWh

165

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

[PART III

Levelized Tariff

Unit

Yr-1

Yr-2

Yr-3

Yr-4

Yr-5

Yr-6

Yr-7

Yr-8

Yr-9

Yr-10 Yr-11 Yr-12

Discount Factors

Discounted Tariff

components

Rs/kWh

Levelized Tariff

Rs/kWh

Levelized Tariff

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

Discount Factors

Discounted Tariff

components

Rs/kWh

Levelized Tariff

Rs/kWh

PART III]

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

166

Form-2.2:

Template for (Biomass power projects, municipal solid waste based power projects, refuse

derived fuel based power projects or non-fossil fuel based co-generation plants): Determination

of Tariff Components

Units Generation

Unit

Yr-1 Yr-2 Yr-3 Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12

Installed Capacity

Net Generation

Units Generation

Unit Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

Installed Capacity

Net Generation

Tariff Components

(Fixed charge)

Unit

Yr-1 Yr-2 Yr-3 Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12

O&M Expenses

Rs Lakh

Depreciation

Rs Lakh

Interest on term loan

Rs Lakh

Interest on working Capital

Rs Lakh

Return on Equity

Rs Lakh

Total Fixed Cost

Rs Lakh

Tariff Components

(Fixed charge)

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

O&M Expenses

Rs Lakh

Depreciation

Rs Lakh

Interest on term loan

Rs Lakh

Interest on working

Capital

Rs Lakh

Return on Equity

Rs Lakh

Total Fixed Cost

Rs Lakh

Tariff Components

(Variable Charge)

Unit

Yr-1 Yr-2 Yr-3 Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12

Biomass Fuel Type-1

Rs Lakh

Biomass Fuel Type-2

Rs Lakh

Fossil Fuel (coal)

Rs Lakh

Municipal Solid Waste

Rs Lakh

Refuse Derived Fuel

Rs Lakh

Sub-total (Fuel Costs)

Rs Lakh

Fuel cost allocable to power

Total Fuel Costs

Rs Lakh

167

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

[PART III

Tariff Components

(Variable Charge)

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

Biomass Fuel Type-1

Rs Lakh

Biomass Fuel Type-2

Rs Lakh

Fossil Fuel (coal)

Rs Lakh

Municipal Solid Waste

Rs Lakh

Refuse Derived Fuel

Rs Lakh

Sub-total (Fuel Costs)

Rs Lakh

Fuel cost allocable to

power

Total Fuel Costs

Rs Lakh

Per Unit Tariff components

(Fixed)

Unit

Yr-1 Yr-2 Yr-3 Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12

PU O&M expenses

Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term loan

Rs/kWh

PU Interest on working capital

Rs/kWh

PU Return on Equity

Rs/kWh

PU Tariff Components (Fixed)

Rs/kWh

PU Tariff Components (Variable)

Rs/kWh

PU Tariff Components (Total)

Rs/kWh

Per Unit Tariff

components (Fixed)

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

PU O&M expenses Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term

loan

Rs/kWh

PU Interest on

working capital

Rs/kWh

PU Return on Equity Rs/kWh

PU Tariff

Components (Fixed)

Rs/kWh

PU Tariff

Components

(Variable)

Rs/kWh

PU Tariff

Components (Total)

Rs/kWh

Levelized Tariff

Unit

Yr-1 Yr-2 Yr-3 Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12

Discount Factors

Discounted Tariff

components (Fixed)

Rs/kWh

Discounted Tariff

components

(Variable)

Rs/kWh

Discounted Tariff

components (Total)

Rs/kWh

Levelized Tariff (Fixed)

Rs/kWh

Levelized Tariff (Variable) Rs/kWh

Levelized Tariff (Total)

Rs/kWh

PART III]

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

168

Levelized Tariff

Unit

Yr-13 Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25

Discount Factors

Discounted Tariff

components (Fixed)

Rs/kWh

Discounted Tariff

components (Variable)

Rs/kWh

Discounted Tariff

components (Total)

Rs/kWh

Levelized Tariff

(Fixed)

Rs/kWh

Levelized Tariff (Variable) Rs/kWh

Levelized Tariff (Total)

Rs/kWh

169

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

[PART III

Form-2.3:

Template for (Small Hydro projects): Determination of Tariff Components

Units Generation

Unit

Yr-1

Yr-2

Yr-3

Yr-4 Yr-5

Yr-6 Yr-7 Yr-8

Yr-9 Yr-10 Yr-11 Yr-12 Yr-13

Installed Capacity

Net Generation

Units Generation

Unit

Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26

Installed Capacity

Net Generation

Units Generation Unit

Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

Installed Capacity MW

Net Generation

Tariff Components

(Fixed charge)

Unit

Yr-1

Yr-2 Yr-3

Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12 Yr-13

O&M Expenses

Rs. Lakh

Depreciation

Rs. Lakh

Interest on term loan Rs. Lakh

Interest on working

Capital

Rs. Lakh

Return on Equity

Rs. Lakh

Total Fixed Cost

Rs. Lakh

Tariff Components

(Fixed charge)

Unit

Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26

O&M Expenses

Rs. Lakh

Depreciation

Rs. Lakh

Interest on term loan Rs. Lakh

Interest on working

Capital

Rs. Lakh

Return on Equity

Rs. Lakh

Total Fixed Cost

Rs. Lakh

Tariff

Components

(Fixed charge)

Unit

Yr-27 Yr-28 Yr-29 Yr-30

Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

O&M Expenses

Rs. Lakh

Depreciation

Rs. Lakh

Interest on term

loan

Rs. Lakh

Interest on

working Capital

Rs. Lakh

Return on Equity Rs. Lakh

Total Fixed Cost Rs. Lakh

PART III]

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

170

Per Unit Tariff

components

Unit

Yr-1

Yr-2 Yr-3 Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12 Yr-13

PU O&M expenses

Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term loan Rs/kWh

PU Interest on working

capital

Rs/kWh

PU Return on Equity

Rs/kWh

PU Tariff Components Rs/kWh

Per Unit Tariff

components

Unit

Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26

PU O&M expenses Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term

loan

Rs/kWh

PU Interest on

working capital

Rs/kWh

PU Return on Equity Rs/kWh

PU Tariff

Components

Rs/kWh

Per Unit Tariff

components

Unit

Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

PU O&M expenses Rs/kWh

PU Depreciation

Rs/kWh

PU Interest on term

loan

Rs/kWh

PU Interest on

working capital

Rs/kWh

PU Return on

Equity

Rs/kWh

PU Tariff

Components

Rs/kWh

Levelized Tariff

Unit

Yr-1

Yr-2 Yr-3

Yr-4 Yr-5 Yr-6 Yr-7 Yr-8 Yr-9 Yr-10 Yr-11 Yr-12 Yr-13

Discount Factors

Discounted Tariff

components

Rs/kWh

Levelized Tariff

Rs/kWh

171

HARYANA GOVT. GAZ., MAY 11, 2021 (VYSK. 21, 1943 SAKA)

[PART III

Levelized Tariff

Unit

Yr-14 Yr-15 Yr-16 Yr-17 Yr-18 Yr-19 Yr-20 Yr-21 Yr-22 Yr-23 Yr-24 Yr-25 Yr-26

Discount Factors

Discounted Tariff

components

Rs/kWh

Levelized Tariff

Rs/kWh

Levelized Tariff

Unit

Yr-27 Yr-28 Yr-29 Yr-30 Yr-31 Yr-32 Yr-33 Yr-34 Yr-35 Yr-36 Yr-37 Yr-38 Yr-39 Yr-40

Discount Factors

Discounted Tariff

components

Rs/kWh

Levelized Tariff

Rs/kWh

By Order of the Commission

Panchkula:

The 27th April, 2021.

Sd/-

Director (Tariff)

HERC, Panchkula.

[88-1]

9160—C.S.—H.G.P., Pkl.