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1 INDEX S. No DESCRIPTION PLACED AS PAGE NO. 1 Petition 2-7 2 Affidavit verifying the Petition Annexure -1 8-9 3 Board resolution Authorising filing of petition Annexure -2 10-13 4 MNRE's letter no. No.32/72/ 2008-09/PVSE Dated: 28th February, 2009 Annexure -3 14-15 5 Detailed Project Report Annexure -4 16-115 6 RREC’s Proposal for 1 MWp Solar PV plant dt. 29.01.2010 Annexure -5 116 7 MNRE's sanction letter no 32/104/ 2009-10/PVSE Dated: 12th March, 2010 Annexure -6 117-118 8 NIT of RREC dt. 23.06.2010 Annexure -7 119-120 9 Copy of Letter of intent no. RREC/1 MW SPV/2010/TN-4/ D.147228-147231dated 11.11.2010 on M/s L&T Annexure -8 121-122 10 RERC’s Solar Tariff Order dt. 25.05.2010 Annexure - 9 123-187 11 Consent letters for purchase of Power from (a) Jaipur Vidyut Vitaran Nigam Limited (b) Ajmer Vidyut Vitaran Nigam Limited (c) Jodhpur Vidyut Vitaran Nigam Limited Annexure -10 (a, b, c) 188-190 12 Govt. of Rajasthan Energy Department’s letter dt. 30.06.2010 Annexure -11 191-192 13 Calculations of generation tariff Annexure -12 193-200

Transcript of RRREC_Solar Tariff Petition

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INDEX

S. No DESCRIPTION PLACED AS PAGE NO.

1 Petition 2-7

2 Affidavit verifying the Petition Annexure -1 8-9

3 Board resolution Authorising filing of petition Annexure -2 10-13

4 MNRE's letter no. No.32/72/ 2008-09/PVSE

Dated: 28th February, 2009 Annexure -3 14-15

5 Detailed Project Report

Annexure -4 16-115

6 RREC’s Proposal for 1 MWp Solar PV plant dt.

29.01.2010

Annexure -5 116

7 MNRE's sanction letter no 32/104/ 2009-10/PVSE

Dated: 12th March, 2010

Annexure -6 117-118

8 NIT of RREC dt. 23.06.2010 Annexure -7 119-120

9

Copy of Letter of intent no. RREC/1 MW

SPV/2010/TN-4/ D.147228-147231dated

11.11.2010 on M/s L&T

Annexure -8 121-122

10 RERC’s Solar Tariff Order dt. 25.05.2010 Annexure - 9 123-187

11

Consent letters for purchase of Power from

(a) Jaipur Vidyut Vitaran Nigam Limited

(b) Ajmer Vidyut Vitaran Nigam Limited

(c) Jodhpur Vidyut Vitaran Nigam Limited

Annexure -10

(a, b, c) 188-190

12 Govt. of Rajasthan Energy Department’s letter dt.

30.06.2010

Annexure -11 191-192

13 Calculations of generation tariff Annexure -12 193-200

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BEFORE THE RAJASTHAN ELECTRICITY REGULATORY

COMMISSION,

NIYAMAK BHAWAN, SHAHKAR MARG, JAIPUR (RAJASTHAN) Filing No………….…

Case No…………...…

IN THE MATTER OF Determination and approval of discount on Generic tariff to be passed on the State Discoms for tail end 1.0 MWp solar PV (Crystalline) power plant of Rajasthan Renewable Energy Corporation Limited at Phagi Dakshin (Rajasthan). IN THE MATTER OF Rajasthan Renewable Energy Corporation Limited (RREC)

E-116, Yudhisthir Marg,

C- Scheme, Jaipur.

PETITIONER

V/s (i) Jaipur Vidyut Vitaran Nigam Limited, Vidyut Bhawan, Janpath, Jaipur. (JVVNL) (ii) Ajmer Vidyut Vitaran Nigam Limited,

Ajmer. (AVVNL)

(iii) Jodhpur Vidyut Vitaran Nigam Limited, Jodhpur. (JdVVNL)

RESPONDENTS

M/s Larsen and Toubro Limited (L&T),

ECC Division, Mount Poonamallee Road,

Manapakkam, P.B. No. 979,

Chennai-600089

NECESSARY PARTY

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Hon’ble Chairman and Members,

The petitioner submits as under.

1. To promote generation of non-conventional energy in Rajasthan and to implement the scheme of the Ministry of New & Renewable Energy (MNRE), Government of India as well as of the State Government, Rajasthan Renewable Energy Corporation (RREC), as State Nodal Agency, has been playing a leading role in development of these sources in the State.

2. The Government of India, Ministry of New and Renewable Energy vide No.32/72/ 2008-09/PVSE Dated: 28th February, 2009 has notified the scheme of Central Govt. grants for establishing the demonstration projects under “Demonstration Programme on Tail end grid connected Solar Power Plants” (vide Annexure- 3). These solar power plants at the tail-end of the grid would provide voltage support to strengthen the grid and to provide additional power for day time use. The detailed project report of which is also annexed as vide Annexure-4.

3. The Rajasthan Renewable Energy Corporation Limited, the State Nodal Agency responsible for the development of renewable energy sources in Rajasthan, proposed to setup 1 MW peak solar photovoltaic (PV) power plant at village Phagi Dakshin at estimated capital cost of Rs.16.19 crores. The proposal was sent to MNRE vide letter dated 29.01.2010 (vide Annexure- 5). The Government of India, Ministry of New and Renewable Energy has sanctioned the proposal vide No.32/104/ 2009-10/PVSE Dated: 12th March, 2010 (vide Annexure- 6) with grant of Rs. 8,09,50,000/- (Rs. Eight crore nine lakh fifty thousand only) equal to 50% of the installed cost of 1 MWp power plant excluding the cost of land, extension (i.e. interconnection) of line and Annual Maintenance Charges.

4. The petitioner RRECL invited tenders for the Design, Engineering, Manufacture, Supply, Erection, Testing and Commissioning of 1MWp Tail End Grid Interactive SPV(Crystalline) Power Plant in Village Phagi Dakshin, Jaipur (Rajasthan) on Turnkey Basis with 25 Years O&M Contract with guaranteed annual generation dated 24.06.2010. The Notice Inviting (NIT) has been attached as annexure-7. Seven parties responded to the tender enquiry. After scrutiny of Technical bids, price bids of 4 qualified

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bidders were opened on 28.7.10. On the basis of quoted price, guaranteed generation and operation & maintenance charges and considering the cost benefit factor, M/s Larsen and Toubro stood first Lowest at the evaluated price (i.e. Project Cost Rs.16.35 Cr. plus 25 years’ O & M charges Rs. 5.25 Cr.) of Rs. 21.60 crores. Discussions/Negotiations were held with L1 bidder M/s L&T, who thereafter agreed for project cost plus 25 years O&M charges at Rs.20.00 crores, out of which project cost is Rs.14.75 crores exclusive of cost of land, boundary wall. The Letter of Intent was issued vide no. RREC/1 MW SPV/2010/ TN-4/ D.147228-147231 dated 11.11.2010 (vide Annexure- 8).

5. Petitioner submits that the net generation and O & M charges considered in the present petition are at variance from those as specified by the Hon’ble Commission vide its order dated 25.5.10 (vide Annexure-9). The Hon’ble Commission vide this order determined the Generic tariff for Solar PV power projects as Rs. 15.32 per kWh.

6. The Net Minimum Guaranteed Generation and the O&M charges inclusive of insurance charges as quoted by M/s Larsen & Toubro are tabulated below:

Year Generation in units O & M charges in Rs. 1 1715000 1100000 2 1704710 1155000

3 1694482 1212750

4 1684315 1273388 5 1674209 1337057

6 1664164 1403910 7 1654179 1474105 8 1644254 1547810 9 1634388 1625201 10 1624582 1706461 11 1615809 1791784 12 1607084 1881373

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13 1598405 1975442 14 1589774 2074214

15 1581189 2177925 16 1572651 2286821 17 1564159 2401162 18 1555712 2521220 19 1547311 2647281 20 1538956 2779645

21 1530645 2918627 22 1522380 3064559

23 1514159 3217787 24 1505983 3378676 25 1497850 3547610 Total 4,00,36,350 5,24,99,809

7. Looking to the specific nature of this project, the petitioner submits the following for kind consideration of the Hon’ble Commission:

(a) Capital cost of Rs.15.05crores (Including Land). (b) Financial structure considering Government of India's grant of 50% of the project cost (Excluding land) i.e. Rs. 7.485 crores,

(c) Guaranteed net generation at 11 kV bus bar given by M/s L&T.. (d) Interest charges as per RERC's norms, (e) Depreciation charges being towards replacement cost of plant to be considered on loan & equity cost considering the of Govt. of India's grant. (f) O&M charges (including insurance charges) as given by M/s L&T and land lease charges considered as per prevalent rate. Land requirement of power plant is 12 bigha and its cost based on 10% of DLC rate i.e. Rs.65625/- per bigha has been assumed as Rs.787500/- (say Rs. 8.0 lakh). (g) Return on equity as per RERC regulations grossed up for MAT / Corporate tax at prevalent rate.

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(h) RRECL may like to avail accelerated depreciation benefit. If it avails, tariff shall be reduced by its benefit.

8. The requisite calculations of solar power plant tariff as per RERC regulations, considering the Net Minimum Guaranteed Generation and Operation & Maintenance Charges as quoted by M/s L & T are annexed at Annexure-12.

9. The Jaipur Vidyut Vitaran Nigam Limited (JVVNL) (vide Annexure- 10(a)), Ajmer Vidyut Vitaran Nigam Limited (AVVNL) (vide Annexure- 10(b)) and Jodhpur Vidyut Vitaran Nigam Limited (JdVVNL) (vide Annexure- 10(c)) have given consent to purchase power at the tariff to be approved by the Commission. Letter of intent issued by RREC to M/s L&T also provides for approval of tariff by Rajasthan Electricity Regulatory Commission (vide Annexure-8).

10. Petitioner, therefore submits this petition under the directions of the State Govt. given to the petitioner vide Letter No. F. 20(2) Energy/ 08 dated 30.6.2010 (vide Annexure-11).

11. Petitioner further submits that the Hon’ble commission may consider and approve the discount to be passed on to the State Discoms on the Generic Tariff of Rs. 15.32 per kWh without accelerated depreciation and Rs.13.19 per kWh with accelerated depreciation for Solar PV projects.

12. The petitioner has worked out the levelised tariff and discounts after considering the impact of grant as under:

Tariff Discount (i) Levelised tariff for 25 years without accelerated depreciation 8.08 7.24 (ii) Levelised tariff for 25 years with accelerated depreciation 7.02 6.17

13. The fees toward the petition filing is submitted to the Hon’ble commission in the form of demand draft with amount Rs. ………. vide No. ………… dated……….

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PRAYER:

14. Petitioner humbly prays to this Hon’ble Commission:

(i) To approve the discount on levelised tariff for 25 years

for Solar Power supply to JVVNL/ AVVNL /JdVVNL at Rs. 7.24 per kWh without accelerated depreciation and Rs. 6.17 per kWh with accelerated depreciation.

(ii) Any other relief deemed appropriate by the commission.

PETITIONER

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Annexure- 1

BEFORE THE RAJASTHAN ELECTRICITY REGULATORY

COMMISSION, JAIPUR (RAJASTHAN)

Filling No…………..

Case No…………….

(To be filled in by the Commission Office)

IN THE MATTER OF Determination and approval of discount on Generic tariff to be passed on the State Discoms for tail end 1.0 MWp solar PV (Crystalline) power plant of Rajasthan Renewable Energy Corporation Limited at Phagi Dakshin (Rajasthan). AND

IN THE MATTER OF

Rajasthan Renewable Energy Corporation Limited

E-116, Yudhisthir Marg,

C-Scheme, Jaipur

PETITIONER

V/s (i) Jaipur Vidyut Vitaran Nigam Limited, Vidyut Bhawan, Janpath, Jaipur. (JVVNL)

(ii) Ajmer Vidyut Vitaran Nigam Limited,

Ajmer. (AVVNL)

(iii)Jodhpur Vidyut Vitaran Nigam Limited, Jodhpur. (JdVVNL)

RESPONDENTS

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Affidavit verifying the Petition

I, M. M. Vijaivergia, son of Late Mr. H. P. Vijaivergia aged 60 years Residing at B-254,

Sector-8, Vidhyadhar Nagar, Jaipur do solemnly affirm and say as follows:

1) I am Director Technical & Executive Director of M/s Rajasthan Renewable Energy

Corporation Limited, E-116, Yudhisthir Marg, C-Scheme, Jaipur and make

this affidavit on behalf of such corporation as a Petitioner in the above matter and am

duly authorized by the said petitioner (vide certified copy of corporation’s resolution

attached) to make this application on its behalf.

2) The statement made in paragraphs 1 to 14 of the Petition are based on information and I

believe them to be true.

DEPONENT

Verification

I solemnly affirm, this………day of…...... 2010 that the contents of above

affidavit are true to my knowledge & no part of it is false and nothing material has been

concealed there from.

ATTESTED DEPONENT

NOTARY PUBLIC

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Annexure- 2

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BEFORE THE RAJASTHAN ELECTRICITY REGULATORY

COMMISSION, JAIPUR (RAJASTHAN)

Filing No………….…

Case No…………...…

IN THE MATTER OF Determination of tariff for tail end 1.0MWp solar PV power plant of Rajasthan Renewable Energy Corporation Limited at Phagi Dakshin (Rajasthan) AND

IN THE MATTER OF

Rajasthan Renewable Energy Corporation Limited E-116, Yudhisthir Marg, C-Scheme, Jaipur

PETITIONER V/s (i) Jaipur Vidyut Vitaran Nigam Limited,

Vidyut Bhawan, Janpath, Jaipur. (JVVNL)

(ii) Ajmer Vidyut Vitaran Nigam Limited, Ajmer. (AVVNL)

(iii) Jodhpur Vidyut Vitaran Nigam Limited, Jodhpur. (JdVVNL)

RESPONDENTS

I, Naresh Pal Gangawar, Chairman & MD, RREC Jaipur hereby authorise Mr. M. M. Vijaivergia Son of Late Mr. H. P. Vijaivergia whose signatures are attested below, to represent me as petitioner in the above matter.

……………………………… (M. M. Vijaivergia) Signature of the authorised representative. ………………………… (Naresh Pal Gangawar) Signature attested. ……………………… (Naresh Pal Gangawar)

Signature of petitioner

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Annexure- 3

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Annexure- 4 DETAILED PROJECT REPORT

Prepared by

RAJASTHAN RENEWABLE ENERGY CORPORATION LIMITED

(Government of Rajasthan Undertaking) E-166, Yudhisthir Marg, C-Scheme, Jaipur

Tel: 0141-2225859, 2228198 & 2221650 Fax: 0141-2226028 E-mail: [email protected]

1 MW TAIL END GRID CONNECTED DEMONSTRATION SOLAR PV PLANT

AT VILLAGE - PHAGI DAKSHIN TEHSIL – PHAGI

DISTRICT- JAIPUR (RAJASTHAN) (UDER CFA SCHEME OF MNRE)

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INDEX

Chapter

No. CONTENTS

1) Preamble 2) Introduction 3) Proposal 4) Necessity of the Project 5) Technology Option 6) Selection of Technology 7) Location

8) Solar PV Modules & Balance of System Design, Bill of Material, Module Specifications.

9) Technical specification of 1.0 MW Solar Power Plant 10) Cost of Project and Financial Analysis ENCLOUSER & ANNEXURES

1. Implementation of the scheme on Demonstration Programme on Tail-end grid connected Solar Power Plant (Annexure-“1”with Annexure –I to VI.)

2. Agenda & Minutes of meeting held on 23.09.2009 (Annexure-“2”)

3. Letter to MNRE for implementation of the scheme on Demonstration Programme on Tail-end Grid Connected Solar Power Plant for 2009-10 (Annexure-“3”)

4. Single line diagram for 33KV S/S. Phagi (Annexure-“4”)

5. Load study for proposed case before & after implementation. (Annexure-“5”)

6. 11 kV line diagram Supply near proposed site of 1.0 MW SPV Power plant. (Annexure-“6”)

7. Detail of Khasra & Maps is placed at (Annexure-“7”) 8. Details of Solar radiation, Insolation etc.(Annexure-“8”)

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C H A P T E R -1

1. PREAMBLE In all developing countries the demand of electricity is increasing at faster rate than the increase

in Generation capacity, resulting in gap between demand and supply of electricity. In India, this phenomenon is observed in all the States including Rajasthan. To bridge this gap, all possible measures are being taken by the Government of India, along with setting up of non-conventional power plants in both public and private sector. Thrust is also given for harnessing, non-conventional energy sources.

In view of the rapid depletion of fossil and extremely limited reserves, the cost of generation of electricity from conventional energy sources is increasing sharply while with technological innovations, and the possibility of mass scale solar applications in the field of energy generation, the cost of generation of electricity from solar energy will come down drastically. It is expected that over the course of the next 10 to 15 years, the cost of generation of electricity from solar energy will come down below that of conventional energy. Thus the world is now poised for the next major technological revolution when solar energy becomes cost effective and large scale generation of electricity from solar energy is possible.

Solar energy is now considered as most viable option, due to following criteria:

(i) The technology of electricity generation from solar has been developed fully for smooth and trouble-free operation as well as for its economical viability.

(ii) It is pollution free and Eco-friendly, eliminating all hazards of conventional generation.

(iii) Low gestation period – only six months from concept to commissioning, enabling fast bridging of power gap in remote areas.

(iv) Free and never ending supply of fuel, resulting almost free electricity after recovery of capital cost.

(v) It can be developed in modular form with facilities for extension at a later date.

Development made in last one decade in harnessing solar power for generation of electricity has been established as a new viable alternative to conventional power generation.

1 National Action Plan on Climate Change (NAPCC) On June 30, 2008, Prime Minister Manmohan Singh released India’s first National Action Plan on Climate Change (NAPCC) outlining existing and future policies and programs addressing climate mitigation and adaptation. The plan identifies eight core “national missions” including “National Solar Mission” running through 2017 and directs ministries to submit detailed implementation plans to the Prime Minister’s Council on Climate Change.

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1.2 National Solar Mission (NSM):-

The NAPCC aims to promote the development and use of solar energy for power generation and other uses with the ultimate objective of making solar competitive with fossil-based energy options. The National Solar Mission has been launched on 18.11.2009. The NSM have the target/proposed roadmap to insure large scale deployment of solar generated power for grid connected as well as distributed and decentralized off-grid provision of commercial energy services. The deployment across the application segment is envisaged as follows:-

S. No.

Application segment

Target for Phase-1 (2010-13)

Target for Phase-2 (2013-17)

Target for Phase-3 (2017-22)

1 Solar collectors 7 million square meters

15 million square meters

20 million square meters

2 Off grid solar applications

200 MW 1000 MW 2000 MW

3 Utility grid power, including roof top

1000-2000 MW 4000-10,000 MW 20000 MW

The mechanism for sale of Power from Solar Power Plants has been finalized in the Mission. The NTPC Vidyut Vyapar Nigam (NVVN) would be designated as Nodal Agency and would be mandated to enter into PPAs with solar power developers to purchase solar power fed to 33 KV and above grid, in accordance with the tariff and PPA duration as fixed by the Central Electricity Regulatory Commission (CERC). The Ministry of Power shall allocate to NVVN equivalent megawatt capacity, from the Central unallocated quota, from NTPC power stations, at the rate notified by the CERC for bundling together with solar power. NVVN will undertake the sale of the bundled power to State utilities at the rates determined as per CERC regulations. This arrangement shall be applicable for maximum capacity 1000 MW to be developed in first phase i.e. from 2009-10 to 2012-13. The solar part of bundled power procured by the State utility from NVVN shall be utilized by State utility for meeting their Renewable Energy Portfolio Obligation.

The Mission has also set a target of 100 MW for the rooftop solar and other small solar power plants, connected to LT/11 KV grid. In this Scheme it is envisaged that distribution utility will pay the tariff determined by the State Electricity Regulatory Commission for the metered electricity generated from such applications (whether consumed by the grid connected owner of the rooftop / ground mounted installation or fed into the grid). Under the Solar Mission, a normative Generation Based Incentive will be payable to utility and would be derived as the difference between the solar tariff

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determined by the Central Electricity Regulatory Commission for concerned solar generation technology, less an assumed base price of Rs.5.50/ kWh with 3% annual escalation. The funds will be disbursed through Indian Renewable Energy Development Agency (IREDA) to the concerned distribution utility. The energy so purchased by the distribution utility shall also be utilized for fulfillment of Renewable Energy Portfolio Obligations.

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C H A P T E R -2

2. INTRODUCTION

2.1 Rajasthan Renewable Energy Corporation Limited (RREC) Govt. of Rajasthan merged Rajasthan Energy Development Agency (REDA) with the Rajasthan State Power Corporation Ltd. (RSPCL) to constitute a new organization named Rajasthan Renewable Energy Corporation Limited (RREC) on 9.8.2002. It is the State Nodal Agency for development of energy from renewable energy sources in the State of Rajasthan as well as the State Designated Agency for promoting energy efficiency and energy conservation in the State.

To promote generation of non-conventional energy in Rajasthan and to implement the schemes of the Ministry of New & Renewable Energy (MNRE), Government of India as well as of the State Government, RREC has been playing a leading role in development of these sources in the State. 2.2 Policy Framework for Development of New & Renewable Energy Sources in Rajasthan

The Government of Rajasthan has accorded a high priority to setting up power projects based on non conventional energy sources in the State. With a view to promote generation of power from these sources, Government of Rajasthan issued a “Policy for Promoting Generation for Electricity from Non Conventional Energy Sources” in Oct. 2004. Keeping in view the requirements from time to time, this Policy has been amended from time to time. The Policy issued by the State of Rajasthan is amongst the most comprehensive policies for promoting the renewable energy sources.

2.3 Necessity of large scale solar energy generation;

Rajasthan is endowed with one of the best solar radiations in the world. For setting up solar energy power plants of capacity 100,000 MW, the land requirement is about 3600 sq.km. Rajasthan has a desert area of more than 208000 sq.km. Therefore, Rajasthan can become a solar power house of the country in the decades to come. Rajasthan has also got a potential of around 5400 MW of wind energy which is primarily located in district of Jodhpur, Barmer and Jaisalmer. As Government of Rajasthan is making efforts of harnessing the entire wind and solar potential of State, the transmission and distribution utility have developed a very strong evacuation system comprising of 400 KV, 220 KV and 132 KV network for evacuation of wind power generated in these three districts. In addition to this, most of lignite resource of Rajasthan is also located in Barmer & Bikaner districts and major Central sector and State sector lignite based power generation projects are located in these areas. The Transmission and Distribution utilities have also developed strong transmission evacuation system for lignite based power project in desert

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area of Rajasthan. Therefore, suitable evacuation system for evacuating solar power in desert area, where the potential of solar energy is maximum, already exists.

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2.4 Rajasthan’s initiatives: MNRE, Govt. of India started Generation Based Incentive Scheme in year 2008 which envisages installation of 50 MW capacity of Grid Interactive Solar Power Project in the country. It is also envisaged in the Scheme that maximum 10 MW capacity can be sanctioned in one State. As generation cost of energy from solar based power plants is Rs.15-16 per unit, MNRE will provide upto Rs.12 per unit as incentive to the State and the remaining part of tariff is to be paid by the Discoms. Under this Scheme two project of 5 MW and 3.0 MW have been sanctioned to M/s Reliance Industries and M/s Par Solar Limited respectively. Sanction of MNRE, GOI has been issued. Rajasthan Electricity Regulatory Commission (RERC) has passed order of renewable energy purchase obligation of 50 MW for Discoms. The tariff for these projects is to be determined by RERC on case to case basis, on the principle of cost plus return on equity. Government of Rajasthan has sanctioned 11 Grid Interactive Power Projects of 66 MW capacity to private sector Developers. The Developers have filed their tariff petition before RERC. While, RERC was in process of determination of tariff, NSM was launched. The project sanction under this Scheme by Govt. of Rajasthan can be taken up immediately under National Solar Mission in Phase-1. These projects are at the advanced stage of preparedness. In most of the cases land has already been allotted or at the advanced stage of process of allotment and for all the projects evacuation system has been approved and all statutory clearances from the State Government have been issued With a view to leverage advantage of availability of bundled power at lower tariff, the State Govt. considered it appropriate to migrate these 66 MW capacity power projects under NSM Phase-1. The proposal has already been sent to MNRE vide GoR letter No D.O.No.20(2)Energy/08 Jaipur, dated 3.1.2010 . Government of Rajasthan has also done advance preparation of identifying suitable land for Solar Based Grid Interactive Power Projects in Desert district of Jodhpur, Jalore, Barmer, Jaisalmer, Bikaner, Nagaur and Churu. The land bank for Jodhpur, Jalore, Barmer, Jaisalmer and Bikaner, has already been prepared and land bank for Nagaur and Churu is under preparation. The private sector Developers can access these land banks for selection of sites for development of Grid Interactive Solar Power Project in Rajasthan. More than 165 locations in five districts of Jodhpur, Jalore, Barmer, Bikaner & Jaisalmer have been identified which are sufficient for installation of grid interactive solar power project of more than 5000 MW. Till date 120 private sector Developers have registered their applications with RREC for development of more than 4000 MW of Grid Interactive Solar Power Projects. These Developers can be allotted capacity for development of Grid Interactive Solar Power Project under Phase-1 of National Solar Mission in Rajasthan. The Developers who have registered their project with RRECL, have also identified land for allocating their solar based power projects and some of them have already applied for allotment of land to Government of Rajasthan. Their applications for allotment of land are at the advanced stage. The evacuation plans for some of their projects have already been approved by the concerned utility. As Rajasthan State is in the advanced stage of preparedness for installation of grid interactive solar power projects, a capacity of more than 400 MW can be installed in Rajasthan in phase-1 of National Solar Mission. Government of Rajasthan has already issued a Policy for harnessing Renewable Energy in Rajasthan in year

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2004. As per the Policy, land is made available to Renewable Energy Projects at 10% of the DLC rate and there is a provision of single window clearance for renewable energy projects. The renewable energy projects are cleared by an Empowered Committee constituted under the Chairmanship of Chief Secretary. The state is also in process for purchasing Solar Power through competitive bidding process. PFCCL has been appointed for selection of developers through bidding process for setting up 50 MW SPV & 50 MW CSP projects.

2.5 Awards to Rajasthan for outstanding works in Renewable Energy

• Rajasthan State has recently been awarded the First Prize to Rajasthan (RREC) for their

outstanding work in the field of Solar Photovoltaic (2002-2007) in the country (non-special category States) by the Ministry of New Renewable Energy in November’ 2007.

• RREC was honored with “IEEMA Power Award-2009” by NDTV Profit in category

“Excellence in Renewable Energy Development-Solar”.

• RREC was honored with 2nd INDIA POWERAWARDS-2009” by Power Utility fit in category “Greening the Earth”.

2.6 Objective of this report Ministry of New and Renewable Energy, Government of India vide No 32/71/2009-10/PVSE dated 24.6.2009 (Annexure-“1”) has declared, Implementation of the scheme on “Demonstration Programme on Tail-end-grid connected Solar Power Plants” for which Ministry will provide Central Financial Assistance (CFA) up to 50% of the installed cost of Solar Power Plant, excluding cost of land, extension of line for power evacuation, civil work and cost of AMC, or a maximum of Rs. 10.00 Cr per MW. The main objective of the Demonstration Programme is to connect solar power plant at the tail-end of the grid for providing voltage support to strengthen the grid and to provide additional power for day time use. This project will help to understand & execute the project while perfecting this art to sharpen its skills on project execution and technology. The Tail-end grid connected solar power generation plant of a maximum installed capacity of 25 kWp per plant at a single location and a maximum capacity of 1MWp per plant at a single location that can be connected to LT grid or 11 kV grid will be eligible for CFA under this Demonstration Programme. The agenda for Proposal for Setting up 1 MW Solar Photovoltaic Power Project in the State of Rajasthan under Central Financial Assistance (CFA) Scheme of MNRE was discussed in detail in RREC 59th Board meeting on dated 23.09.2009 wherein, it was RESOLVED that “in principle

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approval of the Board be and is hereby accorded for setting up 1 MW Solar Photovoltaic Power Plant at a suitable location under Central Financial Assistance Scheme of MNRE. RREC Board also decided that this Project be taken as CDM Project”. The Board’s resolution is placed at Annexure-“2”.

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C H A P T E R -3

3. PROPOSAL Board of Director have accorded in principle approval for setting up 1 MW Solar Photovoltaic Power Plant at a suitable location under Central Financial Assistance Scheme of MNRE, RREC is setting up 1 MW Solar Photovoltaic Power (Tail End) in the State of Rajasthan under Central Financial Assistance (CFA) scheme of MNRE as a Demonstration Project. RREC vide letter dated has already requested to MNRE to accord in-principle approval of the project. A copy of letter dated is annexed as Annexure- “3”. The main objective of this report is to indicate our willingness for setting up a “Tail-end-grid connected Solar Power Plants” of Capacity 1 MWp at Village – Phagi Dakshin Tehsil-Phagi Distt – Jaipur in the state of Rajasthan. We have identified the land & have discussed the Power Evacuation option with RVPNL. The 33/11 KV Sub-Station Phagi is located about to 4.5 km distance from the proposed Solar Plant. The 33/11 KV Sub-Station Phagi is connected with 220/132/33 kV Grid Sub Station, Sanganer which is about 50 kM. from the Phagi Sub-Station. This 33 kV line is catering the supply to seven 33/11 kV Sub-Stations. The entire length of the 33 kV lines is emanating from 220 kV GSS Sanganer (Jaipur) is 84 kM approximately. The detail of other Grid Sub-station connected on the feeder is as under:

Sr.No. Name Of 33 kV Sub Station T/F Capacity connected 1 Pawalia 1x3.15 MVA 2. Mahabatpur 1x3.15 MVA 3. Rainwal 1x3.15 MVA 4. Pipla 1x1.50 MVA 5. Dasra 1x1.50 MVA 6. Ladana 1x1.50 MVA 7. Phagi 1x1.60 MVA & 1x1.0 MVA 8. Nimera 1x3.15 MVA

Single line diagram of 33 kV line along with connected other 33 kV Sub Station placed at Annexure – “4”. The study of the System has been done to access the feasibility of 1.0 MW Solar Power Plant at Phagi. The system study sheet revealed that there is significant improvement in total losses and system voltage. The system study sheet for 33kV feeder is at Annexure-“5”. The total load on 33/11 kV Phagi GSS is 2.6 MVA. And 6 Nos of 11 kV feeders are emanating from this GSS. The Phagi feeder is connected to 1.6 MVA transformer. The availability of 11 kV supply on this feeder is round the clock. The entire length of this 11 kV feeder emanating from Phagi Sub-Station is 7.0 km approx and total load connected to this feeder is 700 kVA (approx.). The nearest 11/.44 kV transformer from the proposed site is about 1kM and LT line closure to the site. The line diagram of 11 kV feeder along with LT distribution system is at Annexure-“6”.

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The system configuration proposed on the technology based on Multi crystalline Silicon Modules. The power generation from the plant will be at 415 V & evacuation of Power will be at 11kV grid.

The total project cost including photovoltaic panels, balance of the system, civil works, power evacuation, land and site development, etc is estimated at Rs. 14.75 crores. The plant is envisaged to sell 1.7 MU/annum of electricity to the grid annually. The life of project is envisaged as 25 years; however, levelised tariff for computation of project IRR is taken for 20 years. This project report covers necessity of solar power, selection &comparison of solar PV technology, location of plant site, site infrastructure, plant facilities & power evacuation requirements.

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C H A P T E R -4 4. NECESSITY OF THE PROJECT 4.1 Global Scenario

Energy issues are likely to remain at center stage for the balance of this decade and well into the next. Globally, we are approaching a peak in world oil production, if we have not already reached it. There are two billion people worldwide who have no access to clean energy which severely constraints their socio-economic developments. The issue of climate change is real and is getting attention from everyone around the world.

The total primary energy demand in the world increased from 5,536 Giga tone oil equivalent (GTOE) in 1971 to 10,345 GTOE in 2002, representing cumulative growth rate of 2%. New research from McKinsey Global Institute revels that global energy demand is on a path to grow by 2.2% over the next 15 years. The growth in energy demand coupled with climate change provides a unique business opportunity to develop “clean energy” as the future energy source.

Figure 1 shows the distribution of world total primary energy sources. It is obvious from Figure 1 that the currently there is not significant clean energy production. The International Energy Agency (IEA) data shows that globally the electricity demand almost tripled from 1971 to 2002. This is not unexpected, since electricity is becoming the preferred form of energy for all applications.

FIGURE 1: Current contributions of various energy sources to the world total

primary energy

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Figure 2 shows the various type of fuels used for generating electricity worldwide. Obviously, electricity production is one of the main sources of global warming.

FIGURE 2: World electricity production by fuel in 2003 Figure 3 shows world green-house gas emission for various sectors. The data of Figures 1, 2 and 3 show that fossil fuel is the biggest source of carbon emission. Therefore substituting fossil fuels by renewable energy must be an important part of any strategy to reduce global carbon emission.

FIGURE 3: World greenhouse-gas emission for various sectors

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4.2 Environmental Issues and Global Warming

The present oil price at USD 70 plus per barrel which reached upto USD 130 per barrel in the year 2008 has changed the world energy scenario to focus on importance of renewable energy sources for augmenting power production worldwide. Of these, solar and wind power are the most important sources. Solar is now contributing only 0.2% of the world energy source with 1.2GW production and s pitched to grow 1.1% by 2010 20% by 2040. By 2040 solar will be the major source of energy surpassing Oil, Gas & Coal. Life span of solar cells is warranted for 25 plus years.

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4.3 Renewable Energy is the Answer

Source: solarwirtschaft.de

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The above figure depicts that according to a German study, 50% of the world will be on renewable energy by 2050.Recent entry of Applied Materials (a California based corporation and number one semiconductor equipment manufacturer with annual revenue of about $10 billion) as a turn-key plant builder for manufacturing photovoltaic modules has changed the dynamics of PV manufacturing. Due to modular nature, power generation by PV can reach rural world in a way similar to the growth of cell phones (without the need of a telephone line). 4.4 Clean, Green in Demand.

Today panels generate a miniscule 0.04% of the world’s energy needs. International Energy Agency (IEA) estimates that govt. and the private sector will invest $10tn in the next 30 years to expand and upgrade global energy infrastructure. Energy needs to grow 50% by 2030.

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Grid prices are going up with the growth in demand and governments liberalizing their energy markets. Fossil fuel prices will continue to rise. Average of residential prices over 70 countries show grid prices rose by 4% CAGR from 1998 to 2005 and 9% CAGR for the past 5 years.

Despite rapid growth in the last 10 years, solar’s contribution is tiny, leaving significant room for rapid adoption of this technology Photo-Voltaic with the highest growth It contributes to 0.1% Market Share of Electricity Capacity being one among the fastest growing segment in Solar Energy Market. o Growth of 23% (20-yr. CAGR) o Growth of 44% (5-yr. CAGR)

23%

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4.5 Governments supporting Worldwide

4.6 Indian Scenario Renewable Energy Sources (RES) will turnout to be one of the most important and crucial element of India’s power policy aimed to meet the power needs of remote areas in an environmentally friendly way. Certain forms of renewable energy sources (such as solar, wind energy, small-hydro and biomass) have taken off. Strong private participation is seen in sectors like wind power, in response to the policy and initiatives. 4.6.1 Key Issues Facing the Sector The major issues currently being faced by the renewable energy sector are as the following:

High capital costs and low plant factors raise the cost of renewable energy. However, technological evolution and the huge power deficit make 34tilized34 an active choice for power utilities, especially in the future years.

Private sector interest is dependent on regulatory certainty on tariff and other conditions. Increased competition for land use in certain renewable technologies needs to be

managed. Lack of grid presence or transmission capacity in remote areas where renewable energy

opportunities exist, is a major constraint in power evacuation. 4.6.2 Policy and Regulatory Framework Some of the key legislative, policy and other measures initiated by the various stakeholders for promoting RES are:

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The Electricity Act provides for State Commissions to fix a minimum percentage for purchase of energy from renewable energy sources.

The policy recognizes that renewable energy sources should be offered preferential tariffs till they can evolve and compete with other conventional sources.

Generation and distribution in notified rural areas have been de-licensed. Fiscal benefits and financial support has been extended to interested investors. A number of fiscal benefits in form of duty exemptions, income-tax holidays, accelerated

depreciation norms, etc have been extended. In addition, Indian Renewable Energy Development Agency has also been extending financial support to interested investors.

4.6.3 The India Opportunity India has an enormous potential of renewable energy across the various sources as indicated in the table below.

The current installed capacity is so minuscule compared to the installed generation capacity. Given the low utilization percentage, there is an exciting opportunity for various participants, including generator and equipment manufacturers.

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C H A P T E R -5 5 TECHNOLOGY OPTION Solar Energy is the most promising source as it is the least exploited till now, globally & costs of electricity generated by solar PV have been falling. Given the high solar incidence in India, and the need to electrify vast remote off-grid areas, India is set to become a huge market for solar energy. Government subsidies will be crucial in order to ensure affordability in off-grid locations. 5.1 Introduction to Solar Power Since the invention of solar cells in 1954, photovoltaic (PV) has gained the reputation of a reliable power source for space and certain terrestrial applications. Mankind’s dependence on fossil fuels has negatively impacted the environment and is responsible for global warming. Photovoltaic (PV) offers a unique opportunity to solve the 21st century’s energy and the environmental problems simultaneously because solar energy is essentially unlimited and solar cells can convert it into electrical energy without any undesirable impact on the environment. Thus photovoltaic (PV) is an ideal clean and reliable renewable source of electricity generation for space and terrestrial applications. The potential of photovoltaic (PV) can be judged from the fact that 30 minutes of global collected solar energy is equivalent to yearly worldwide energy consumption. 1% of the Sahara surface would be sufficient to supply the global electricity demand via Solar electricity plants. Of all renewable energy (wind, geothermal, biomass, solar photovoltaic (PV), hydro & tide) PV is ready to make same impact in electricity production as the microelectronics based on the silicon chip has impacted virtually on every human being. PV manufacturing over years has been supported partially by Oil companies. Other than Sharp and some material suppliers, no major semiconductor company has played a significant role in PV manufacturing.

5.2 World Scenario The following is a list of all the photovoltaic power plants globally:

Capacity (MW)

Location Technology Status

154 Australia Concentrated Photovoltaic

Under construction. Resumes operation in 2013

11 Portugal Silicon Panels Resumed operation in January 2007 10 Germany Silicon Panels Resumed operations since March 2006

62 Portugal Silicon Panels Under construction of phase 1. 40 Germany Thin Film Panels Under construction.

Will resume operations in December 2009. 41 Spain Silicon Panels Close to starting operations 23 Spain Silicon Panels Resumed operation in January 2008. 20 Spain Silicon Panels Operating since September 2007 14 USA Silicon Panels Resumed operation in December 2007

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22 Germany Silicon Panels Resumed operations As is evident from the above table, most of the large photovoltaic powers plants in the world are above the 5 MW scale. Most of these power plants are using the silicon panel approach to generate power. In the entire project cost for a photovoltaic power plant, the cost of the power generating panels is normally the highest proportion of the cost. At 5 MW scale also, the cost of the panels is essentially the largest cost of the project. In addition, at 5MW scale, the entire utility of the balance of system (supporting equipment) is completely realized, hence making this scale will be more economical. 5.3 Rajasthan: An Investment Opportunity as Solar PV Developers Rajasthan is one of the states in India, which receives the highest solar radiation and thus is the most ideal location for solar PV. Rajasthan is a desert state and is blessed with abundant land with little or no vegetation, which would be ideal for Solar PV. These two facts together translate into a huge potential for solar power. Solar is also the most viable option in a sun‐drenched state like Rajasthan. The first 1 MW capacity will help to understand & execute the project while perfecting this art to sharpen its skills on project execution and technology selection.

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C H A P T E R -6

6 SELECTION OF TECHNOLOGY

6.1 General Overview of the Technologies

Three key elements in a solar cell form the basis of their manufacturing technology. The first is the semiconductor, which absorbs light and converts it into electron�hole pairs. The second is the semiconductor junction, which separates the photo�generated carrier (electrons and holes), and the third is the contacts on the front and back of the cell that allow the current to flow to the external circuit. The two main categories of technology are defined by the choice of the semiconductor: either crystalline silicon in a wafer form or thin films of other materials. Historically, crystalline silicon (c�Si) has been used as the light�absorbing semiconductor in most solar cells, even though it is a relatively poor absorber of light and requires a considerable thickness (several hundred microns) of material. Nevertheless, it has proved convenient because it yields stable solar cells with good efficiencies (12�16%, half to two�thirds of the theoretical maximum) and uses process technology developed from the huge knowledge base of the microelectronics industry. Two types of crystalline silicon are used in the industry. The first is mono�crystalline, produced by slicing wafers (up to 150�156 mm diameter and 200�300 microns thick) from a high�purity single crystal bowl. The second is multi�crystalline silicon, made by sawing a cast block of silicon first into bars and then wafers. The main trend in crystalline silicon cell manufacture is toward multi�crystalline technology. Compared to single�crystalline silicon, multi�crystalline silicon material is stronger and can be cut into one�third the thickness of single�crystal material. It also has slightly lower wafer cost and less strict growth requirements. However, their lower manufacturing cost is offset by the lower cell efficiency. The dominance of crystalline Si (about 91% of the market) was maintained in 2007. However, the industry has had to face a major shortage of its starting material, electronic�grade poly�silicon feedstock. This is the result of the strong growth of photo�voltaic over the last few years, a steady demand from microelectronics (each sector now consumes about half of the production) and a lack of anticipation of the needs by the feedstock producers. The shortage has resulted in an acceleration of the trend towards reducing silicon consumption in solar cell manufacturing. In order to meet as much as possible the strong demand for wafers, wafer producers are quickly decreasing the wafer thickness, thereby producing more wafers per ingot. Whereas in 2004, the standard thickness in production was still around 300μm, the typical wafer thickness in the industry is now 250μm, with a general use of 200μm thick wafers around the corner. Mono c-Si Multi c-Si

4 .1 4 .3 5.6 4 .6 4 .4 3 .3 2 .9 2 .60 .2 0 .2 0 .2 0 .6 0 .4 0 .2 0 .2

12 .3 9 .6 8 .96 .4 4 .5 4 .4 4 .7 4 .7

0 .50 .3 0 .5

0 .71.1 1.1 1.4 2 .7

4 2 .1 4 8 .250 .2

51.6 57.254 .7 52 .3

4 6 .5

4 0 .83 7.4 3 4 .6 3 6 .4

3 2 .23 6 .2 3 8 .4

4 3 .4

0 .2

1999 2000 2001 2002 2003 2004 2005 2006

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Others Figure 1: Photovoltaic Technologies market share

6.2 Crystalline Silicon 6.2.1 Mono Crystalline Silicon Single�crystal silicon cells are the most common in the PV industry. The main technique for producing single crystal silicon is the Czochralski (CZ) method. High�purity poly�silicon is melted in a quartz crucible. A single�crystal silicon seed is dipped into this molten mass of poly�silicon. As the seed is pulled slowly from the melt, a single crystal ingot is formed. The ingots are then sawed into thin wafers about 200�300 micrometers thick (1 micrometer = 1/1,000,000 meter). The thin wafers are then polished, doped, coated, interconnected and assembled into modules and arrays. Single�crystal silicon has a uniform molecular structure. Compared to non�crystalline materials, its high uniformity results in higher energy conversion efficiency� the ratio of electric power produced by the cell to the amount of available sunlight power i.e. power�out divided by power�in. The higher a PV cell’s conversion efficiency, the more electricity it generates for a given area of exposure to the sunlight. The conversion efficiency for commercial single crystal silicon modules ranges between 12�16 %. Not only are they energy efficient, single�silicon modules are highly reliable for outdoor power applications. About half of the manufacturing cost comes from wafering, a time consuming and costly batch process in which ingots are cut into thin wafers with a thickness no less than 200 micrometers thick. If the wafers are too thin, the entire wafer will break in wafering and subsequent processing. Due to this thickness requirement, a PV cell requires a significant amount of raw silicon and half of this expensive material is lost as sawdust in wafering. 6.2.2. Poly Crystalline Silicon: Polycrystalline solar cells use wafers sliced from ingots cast using silicon melted in a crucible. These ingots are not formed from a single crystal, unlike mono�crystalline silicon which is slowly built up by revolving a seed crystal. The ingots can also be cast in a square shape, instead of the cylinders of polycrystalline silicon. Consisting of small grains of single�crystal silicon, multi�crystalline PV cells are less energy efficient than single crystalline silicon PV cells. The grain boundaries in multi�crystalline silicon hinder the flow of electrons and reduce the power output of the cell. The energy conversion efficiency for a commercial module made of multi�crystalline silicon ranges between 10 to 14%. A common approach to produce multi�crystalline silicon PV cells is to slice thin wafers from blocks of cast multi crystalline silicon. An emerging technology which has seen significant development in multi�crystalline arena is that of string ribbon silicon technology in which silicon is grown directly as thin ribbons or sheets with the approach thickness for making PV cells. Since no sawing is needed, the manufacturing cost is lower. The

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most commercially developed ribbon growth approach is EFG (edge�defined film�fed growth).

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Figure 2: Process flow for Multi–crystalline solar cell 6.3 Amorphous Silicon or Thin Film Due to the high shortage in silicon non crystalline or thin film technology had got a lot of boost in the recent past. The major technologies in the thin film segment are: Amorphous Silicon, Cadmium Telluride, and Copper Indium (gallium) Diselenide (CIS or CIGS). Typically these technologies are not mature and the production of their solar cells unstable. These technologies also have much lower light to electricity conversion efficiencies than crystalline cells. The drawbacks of thin�film solar cells include an energy conversion efficiency of only around 9%, compared to & around in excess of 14% for solar cells based on silicon wafers. Due to their lower production costs and hence lower selling prices, thin film has found application in solar farms where space is not a constraint. However, crystalline silicon cells continue to be the preferred option for roof top applications. Furthermore, the production equipment costs of thin�film solar cells are high. Crystalline silicon will still remain key technology in Photo�voltaic in near future. By far, it’s still the dominant type of solar cell, and its production costs are declining steadily, at a rate of seven to ten percent per year. Further with easing in the tight supply and demand gap of the poly-silicon and stabilizing of poly-silicon prices and with use of thinner wafers the demand of crystalline technologies will remain.

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6.4 Comparison Between Crystalline, Thin Film & CPV Technology

S.No. Parameter Crystalline Thin Film CPV

1) Types of Materials Polycrystalline Amorphous Silicon,

CdS, CdTe, CIGS etc. Triple Junction GaAs Cell

& lens , tracker

2) Power Efficiency 12-16% 6-9% 20-25%

3) Technology Well Developed Under development Under development

4) Module Weight Light weight per

watt Heavier weight per

module Heaviest System

5) Area utilization

Higher power generated per unit area due to high

efficiency

Less power per unit area Highest power per unit

area

6) Temperature Effects

Temperature variations affect

output

Lesser impact of Temperature variations

High variation

7) Irradiance Used particularly

for Normal radiations

Better performance with Diffuse radiations

Works only for Normal radiations

8) Module quantity Lesser nos required

due to high efficiency

More modules required Lowest nos. of modules

required

9) Output per MW installed

High Higher Very High

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10)Transportation

Cost Lower

Transportation cost Higher cost High cost

11)Mounting Structure Per kW

Fewer Mounting structure required

More Mounting structures required

Sophisticated mounting required

12) Land Requirement Lesser space

required per MW Larger space requirement

Lowest space required

13) Inverter High inverter

flexibility Limited inverter

flexibility Limited inverter

flexibility

14) Cost High cost per Watt Lower cost per Watt Highest cost per Watt

15)Environment

Effects Less Sensitive Sensitive Sensitive

16) Stabilization Stable power

output from initial stages

Stability achieved after 4-6 months

Unknown

17) Availability Easily available Limited supply Limited supply

18)Power Degradation

Less degradation

Highest degradation for initial 5-7 years

High Degradation

19) Plant Maintenance Less maintenance Less maintenance High maintenance

required

20) Repair Relatively easy Difficult due to complex

structure Difficult due to complex

structure

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21)Cooling

Requirement Not required Not required

Requires active or passive cooling which could

increase cost

22) Cabling Low Cabling higher cabling Lower Cabling

23)Suitability for Grid

Technology Good Good Good

6.5 Conclusion Rajasthan Renewable Energy Corporation Limited considered the use of the above mentioned technology for this solar power plant in Rajasthan. RREC have analyzed the various advantages and disadvantages of these technologies. Each of the above technologies has their own particular strengths and weaknesses which have played a role in decision making. It has been decided to use Poly crystalline silicon photovoltaic technology as preferred technology. These advantages and disadvantages in addition with their market availability and costing are the key parameters on basis of which we have decided our technology. Below are description of various technologies, and justification of selection of particular technology. Among the various photovoltaic technologies in use, crystalline Silicon technology is most widely used technology globally. This is primarily because the technology is well understood, and was amongst the first developed photovoltaic technologies. The installation and integration of these modules is relatively easier as against the above compared technology. The electrical losses per panel of this technology are well understood. In addition to this, more than 90% of the global manufacturing is based on this technology which is approximately evenly shared between mono-crystalline cells and multi-crystalline cells. For this power plant, it believes that approximately 4400 panels of this technology will be installed. This number total modules installed is lower than the number of modules required for thin film technologies but is marginally higher than CPV technology. As a result of this, the operations and maintenance of this power plant will be relatively easier and the associated cost will also be lower. The acreage for this power plant will be lower in comparison with other technologies. This will be a great advantage during the operations of this power plant. The cost of individual balance of systems (i.e. module stands, DC cabling between arrays etc) will be significantly lower. While, the pricing of the panel is significantly high, the cost reduction in balance of system makes it an attractive proposition against other technologies. Also keeping in mind that the generation is significantly stable not only against other technologies but also year over year, this point is tremendous value addition for determining the levelized cost of electricity at a favourable level .Within the domain of Silicon cell based technology, RREC has decided to use the multi-crystalline panels solely because of a slight cost advantage and relatively easier availability with

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vendors. The other technologies, concentrated photovoltaic and thin film technologies, are relatively new. RREC is confident on its performance in the long term. In its nascent stage also, CPV has been successful to show its promise, and it believe that towards the end of this year, CPV will deliver on its promise and be as competitive as the silicon technology, offering higher efficiency, and higher output units per kW installed. With increase in the conversion efficiency, the cost per watt installed would also decrease significantly to silicon panel level. Similarly, though thin film technology is rather well upcoming technology, and RREC is confident of its performance in the field, only after efficiency improvements. Even though the panels cost might be lowest, there is a proportional rise in the balance of system cost. The acreage required is also significantly high and this is an additional cost. The degradation during the time shortly after installation is also high. Also, this is the exact same time period during which the feed in tariff is allotted, so this would affect the revenue significantly. In conclusion, we decide to use multi-crystalline silicon technology for this project. 6.6 Justification And Cost Benefit Analysis For Selected Technology RREC has considered using Poly-Crystalline Photovoltaic technology for the project because it is easily available, easy to integrate, has lower maintenance cost and requires less area to install as against amorphous silicon thin film panels. Moreover, 90% of the PV market is dominated by crystalline silicon technology and as a result of this high market share of the crystalline silicon technology, the availability is much faster and easier, as against amorphous silicon thin film panels. As regards cost benefit analysis of the technology, RREC believes that the performance to cost ratio for thin film amorphous silicon technology versus multi-crystalline technology is very comparable and the decision is purely affected by the overriding market forces and various guidelines.

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C H A P T E R -7 7. LOCATION The proposed land is located in Phagi which is about 39 km. from Jaipur city on Diggi-Malpura state highway. It is surrounded by lush green agriculture fields, which makes its environment pollution free and provides plenty of fresh air all the time. The proposed site is near Village – Phagi Dakshin, Tehsil – Phagi. The Jaipur District is situated in the eastern part of Rajasthan. It is bound in the North by Sikar and Alwar, in South by Tonk, Sawai Madhopur, Kota, Ajmer, Udaipur in the West and in East by Bharatpur, Dausa and Agra. Jaipur is 12th Largest Metropolitan of India. Population as per 1981 census was 1.01 million, which has seen a phenomenal growth in the last 20yrs. With the present population standing at Approximately 5.25 million approximately 10% of total Rajasthan Population. Density of population 471 per Sq.kms. Literacy Rate – 70.63.

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7.1 Proposed Site details

7.2 Detail of Khasra & Maps is placed at Annexure-“7”. 7.3 Solar Radiation Data for Jaipur at Proposed Location

The solar radiation data for Phagi (Jaipur). The data is taken from surface metrology and solar energy data NASA Earth Science Enterprise program and is based on 22 Years of Data analysis. Latitude and Longitude data of Phagi has been considered as mentioned below: Latitude : 25° 0’ ˚N Longitude : 83.1’ ˚E Altitude : 431 meters Average annual solar insolation at tilt angle taken for Phagi is 5.38 KWh/m²/day. Details of Solar radiation, Insolation etc. is placed at Annexure – “8”.

7.4 Details of Proposed Project Location: a) Details of proposed capacity of

the solar power plant : 1.0MW SPV (Multicrystalline) power Plant at Phagi

b) Location : Phagi Dakshin, Teh.- Phagi, Distt.-Jaipur c) Distance from existing Grid : 1.0 kM. distance from 11/0.4 kV S/S d) Load profile : 63 kVA, 11/0.4 kV S/Stn. e) Estimated life of PV Power

plant : 25 Years

f) Quantum of electricity expected to be generated & fed to grid

: 1.7 MU

g) Estimated benefit to the stability of the grid

: Improve the voltage and system

h) Details of power shortage during day time

: Power supply is available round the clock

i) Impact of load shifting to : Low voltage

Village Phagi dakshin Tehsil Phagi District Jaipur State Rajasthan Location Phagi dakshin Land Available 28 Bigha Khasra No. 4291 (14-14 Bigha) & 4293 (13-06 Bigha) Type of Land Govt. land Nearest 33/11 kV S/stn. Phagi (4.5 kM approx.)

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evening j) Estimated cost of the project : 14.75 Cr. k) Details of Power evacuation : To be applied. l) Details of permission for

connecting solar power plant : Requested to CE (O&M), JVVNL, Jaipur vide letter

No.12323 dt.02.02.2010.(Annexure-) m) Details of land in possession : Requested to District Collector, Jaipur vide letter

No. 12268 dt.19.01.2010 (Annexure-)

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C H A P T E R -8

8. SPV Modules & Balance of System

RREC proposes to setup a 1 MW tail-end grid connected Solar PV Power Plant with Poly- Crystalline technology out of various technology options in the world.

8.1 Solar PV System Description & Diagram:

When photons from sunlight hits electrons in a photovoltaic module, the electrons get charged up, and direct current (DC) begins to flow. This DC electricity is further converted to alternating current (AC) electricity using a grid-interactive inverter toAC electricity over 3 phases. This is further fed into a transformer that would further elevate the voltage to the grid level of 11kV .

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8.4 Module Specifications

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8.5 Grid Inverters

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Inverter Technical data

Sl no Description Unit Values

General system Particulars

Make: EMERSON NETWORK POWER

Model Name : ENP SSL250 250KW

Input DC

1 Max DC power W 280000

2 Max DC Voltage V 1000

3 PV Voltage range – MPPT V 300-850

4 Max Input current A 600

5 Number of MPP Trackers Nos 1

6 Max. number of strings

( parallel) Nos 8

Output AC

7 Nominal AC output W 250000

8 Max AC power W 275000

9 Rated Output Current. A 380A

10 Nominal AC output/ range V 415 +/- 10%

11 AC grid frequency/ range Hz 50Hz +/- 4.5Hz

(Grid tracking range)

12 Phase shift ( cos phi) 0.99

minimum

13 AC connection/ power balancing single/ three

phase three phase

Efficiency

14 Max efficiency % 98.2

15 Euro – Eta % 97.7

Protection Devices

16 DC reverse polarity protection ( yes/no) YES

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17 DC load disconnecting switch ( yes/no) YES

18 AC short circuit protection ( yes/no) YES

19 Ground Fault monitoring ( yes/no) YES

20 Grid Monitoring ( yes/no) YES

21 Galvanically isolated ( yes/no) NO

General Data

22 Dimensions( W/H/D) in mm mm 600/2120/

1000

23 weight Kg 600

24 Operating temperature range Deg Cel (- 20 to 50)

25 Noise level ( typical) dB <60dBA

26 Consumption : operating

( standby)/night W 850/100

27 Topology Modular Central

Inverter

28 cooling concept Forced Air

29 Mounting Location : indoors/outdoors

( IP65) Indoors IP20

Features

30 DC connection : MC3/MC4/Tyco Pheonix Screw

Terminal

31 AC connection : Screw terminal /

Busbar Busbar

32 LCD YES

33 Interface : Bluetooth/RS485 RS 232/485

34 Warranty : 5 years/ 10 years 5 Years Standard

35 Certificates and approvals CE, IEC

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8.6 Module Mounting Structure

Certain numbers of PV panels are connected in series and in parallel giving a DC output out of the incident solar irradiance. Orientation and tilt of these panels are important design parameters, as well as shading from surrounding obstructions. To get maximum output from the system the structure used will be with manually tilting facility so as to receive maximum solar radiation throughout the year. The array frames proposed for the site utilize different tilt angle capability so that tilt angles along with the latitude degrees during operation of the power plant. The arrays frames are fabricated out of MS galvanized and are protected against the salty air and other environment impacts for any corrosion. The structure is so designed that it can be used on flat, sloping, undulated surfaces. The array frames would be certified for wind and seismic requirements of the area and most importantly, for a remote site, would utilize footings that will minimize the quantity of concrete required. The array frames are designed for simplicity, low cost and ease of installation at site. They would provide a minimum height from the ground around 1m so as to remove any “splash back” from the ground caused by rain.

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8.7 Module Placement: In order to maximize the electricity generation, the module placement is very important. The module placement will be done in such a way that the modules are south facing. Since the sun travels from east to west, the maximum exposure to the sun, will be obtained by the panels facing the south direction. In addition to this, the panels also will be arranged with a uniform profile, so as to reduce shadowing effect. There would be no overlapping of panels in the power plant, and this would reduce any losses that could have occurred due to shadowing.

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8.8 Power Evacuation / Interconnection with Grid:

Photovoltaic system consists out of two parts: 1) Direct current side 2) Alternating current side (PCU)

Basic Operating system:

i. PV arrays convert sunlight into DC power

ii. This generated DC power is passed through the inverter to convert DC power into AC power.

iii. The PCU converts to AC power at 415 V which is then stepped up using a step-up transformer to desired 11 kV.

iv. AC power at 11KV is connected to the grid by using synchronizing equipments, v. Both on DC side of generation as well as AC side of conversion, and at grid inter

connection, protection & safety devices are provided to ensure safe & reliable operation of the complete Solar power generating system.

vi. Monitoring metering & analysis system provided with the power plant will record, store & transfer data that are essential for the relevant purpose.

A simple block diagram, related to the interconnection of various systems for grid connectivity, is shown below for reference. The power from modules is directed to the central inverters through the DC combiner boxes & from the inverters it is routed though the Low voltage panel to the transformer. From transformer, the high voltage power is routed to the metering panel, breakers & eventually to grid through the high voltage 11 kV lines.

LOW VOLTAGE

PANEL

TRANSFORMER

INVERTER

O/P

HIGH

VOLATGE PANEL

LOAD

CIRCUIT BREAKER

GRID

METERING Panel

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TECHNICAL SPECIFICATIONS

1 MW GRID INTERACTIVE SOLAR POWER PLANT (TAIL END)

2 The equipment and materials for 1 MWp Grid Interactive Solar PV Power Plant with associated system (Typical) shall include following:

1. Solar PV modules, of suitable rating in each array 2. Solar PV modules in array totaling 1MWp including mounting frames,

structures, array foundation and module inter connection. 3. Array Junction boxes, distribution boxes and Fuse boxes / circuit breakers. 4. Power Conditioning Units (PCU), common AC power evacuation panel

with bus bars and circuit breakers LT Power Interfacing Panel Plant Monitoring Desk

5. Metering and protection. 6. LT Power and Control Cables including end terminations and other required

accessories for both AC & DC power 7. Earthing system for PV Array, DC power system, lightening protection

system, PCU, transformers and HT switch gear. 8. Data acquisition system with remote monitoring facilities. 9. Spares for 5years maintenance 10. Earthing kit 11. Lighting arrestors/Surge arrester 12. PVC pipes and accessories/trenches 13. Tool kit 14. Control room equipments related to solar system etc 15. Testing, maintenance and condition monitoring of equipments. 16. Mandatory spares& spares for 1years.

1.2 Detailed designing of 1MW Grid Interactive Solar Power Plant and its associated electrical & mechanical auxiliary systems shall also includes preparation of single line diagrams and installation drawings electrical lay outs, erection key diagrams, electrical and physical clearance diagrams, design calculations for Earth mat, Bus Bar & Spacers indoor and outdoor lighting/illumination etc. design memorandum and other relevant drawings and documents.

1.3 Civil erection work shall be performed with respect to the following: 1 Solar PV Array. 2 Power Cables 3 Civil foundation work of transformers, switchgears, etc

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4 Entire GI cable tray inside control room building 5 Fabrication, supply & erection of cable trays, support, brackets and accessories in

case of site fabrication cable tray. 6 Galvanized steel rigid/flexible conduits and accessories, Hume pipes, ferrules,

lugs, glands, terminal blocks, galvanized sheet steel junction boxes, cable fixing clamps, nuts and bolts etc. as required.

7 Supply of necessary steel materials for field fabrication of cable trays, supports, brackets, grounding system etc.

1.4 During the O&M period, the RREC shall keep the measured daily data at 15 minutes

interval in electronic form. 2 General: 2.1 Generated power from 1MWp Solar Power Plant will be feed to the

RVPN/Discom Grid. 2.2 The offered Grid Connected Solar Power Plant Shall generate power through

solar energy and supply clean and green electricity to the grid. RREC will avail carbon credits under clean development mechanism.

2.3 RREC will submit petition to RERC for 1 MW SPV Power Plant, RERC will

decide the tariff for same. 2.6 The supply, erection, commissioning and all other allied works for 1 MW SPV

Power Plant shall be completed within 6 months from the date of order. 2.7 The RREC will sign the PPA with Discom for sale of power. 2.8 Safety of Plant, Machinery, Equipment, Material and personnel shall be

responsibility of contractor and suitable insurance policy shall be taken by Contractor well in advance.

2.9 The minimum array capacity at STC shall be of 1 MWp at the time of installation

and after 1 year of operation for first unit of 1 MWp. In case of any degradation of the module in the first year, the same shall be taken care of by RREC by asking to the supplier to provide additional capacity at the time of installation to achieve minimum 1 MWp of each unit at the end of respective one year.

3 System Design / Philosophy

3.1 The SPV array generally consisting of number of SPV modules which directly

produces DC electricity power on receipt of solar irradiation. This DC power is

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converted to AC power by battery of PCUs. The AC output at 400 V level is stepped up to 11 kV by transformers. The modules in a PV array are usually first connected in series to obtain the desired voltage; the individual strings are then connected in parallel to allow the system to produce more current. They are then protected by encapsulation between glass and a tough metal, plastic or 59tilized59t back. This is held together by a aluminium frame to form a module. These modules usually are made up of SPV cells, forming the basic building block of a solar array. Modules may be connected in series or parallel to increase the voltage and current, and thus achieve the required solar array characteristics that will match the load.

3.2 The main objective is the high availability and reliability of the plant. In order to

achieve the main objective, the following principles would be adopted while designing system.

1. Technology: Solar PV crystalline cells of high efficiency. 2. Adequate capacity of SPV module, PCUs, Junction boxes etc to ensure

generation of power as per design estimates. This to be done by applying liberal de-rating factors for the array and recognizing the efficiency parameters of PCUs, Transformers, etc.

3. Use of equipment and systems with proven design and performance that have a high availability track record under similar service conditions.

4. Selection of the equipment and adoption of a plant layout to ensure ease of maintenance.

5. Strict compliance with the approved and proven quality assurance norms and procedures during the different phases of the project.

6. Proper monitoring in the synchronizations which ensures the availability of power to the grid.

7. The plant instrumentation and control system shall be designed to ensure high availability and reliability of the plant to assist the operators in the safe and efficient operation of the plant.

8. It shall also provide for the analysis of the historical data and help in the plant maintenance people to take up the plant and equipment on preventive maintenance.

9. Generation voltage of 415 V has to be stepped up to 11 kV to the grid voltage at the point of interconnection.

10. The power plant has to operate in parallel with the grid system which is infinite electrical system. Any faults not taken care will result in damage of only SPV power plant without effecting RVPN/DISCOMS infinite system. Thus the power plant has to protect its equipment against any of possible fault or other disturbances from the grid.

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3.3 The basic and detailed engineering of the plant will aim at achieving high

standards of operational performance especially considering following:

1. Optimum availability of modules during the day time. 2. Ensuring module layout to prevent shading. 3. Fixed structure of manual tracking system if site condition requires or 4. High DC system voltage and low current handling requirements 5. Selection of PCUs with high efficiency and readily availability of requisite

spares. 6. Careful logging of operation data / historical information from the Data

Monitoring Systems, and periodically processing it to determine abnormal or slowly deteriorating conditions.

7. SPV power plant shall be designed to operate satisfactorily in parallel with the grids within permissible limits of high voltage and frequency fluctuation conditions, so as to export the maximum possible units to the grid. It is also extremely important to safeguard the system during major disturbances, like tripping / pulling out of big generating stations and sudden overloading during falling of portion of the grid loads on the power plant unit in island mode, under fault / feeder tripping conditions.

4 Technical Specification for SPV Power Plant:

A typical power line diagram of SPV Grid connect system is indicated solar power plant

part at sketch 1 and power evacuation part at sketch 2. Solar Power Plant consists of mainly following:

1. Solar PV modules 2. Module mounting structures 3. Sub- Junction Box 4. Junction Boxes 5. Solar PV Array 6. Power Conducting Unit 7. LT Power Interfacing Panel 8. DC DB Board 9. Plant Monitoring Desk 10. Cable and installation accessories 11. Earthing & Protection

These technical features are detailed in foregoing paras.

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6. SPV Modules:

6.1 SPV modules shall have declared output of 230 Wp or more. Number of modules

in system shall be worked out accordingly. 6.2 Stabilized output of the Solar Power Plant shall not be less than 1MWp, under

Standard Test Condition after one year of operation. 6.3 Peak power point voltage and the peak power point current of any supplied

module and/or any module string (series connected module) shall not be more than 3% from the respective arithmetic means for all modules and/or for all module strings, as the case may be.

6.4 Each module shall have low iron tempered glass front for strength & superior light transmission. It shall also have tough multi-layered polymer back sheet for environmental protection against moisture & provide high voltage electrical insulation.

6.5 The module frame shall be made of aluminium or corrosion resistant material, which shall be electrically compatible with the structural material used for mounting the modules.

6.6 Solar modules to be used in the plant shall be duly certified as per IEC 61215-2005 and IEC 61730-1, -2.

6.7 SPV module shall contain mono/poly crystalline high power silicon solar cells. The solar cell shall have surface anti-reflective coating to help to absorb more light in all weather conditions.

6.8 Solar PV module array shall consist of high efficiency Solar Modules utilizing Crystalline Silicon Solar PV cells. Power output Guarantee for the SPV Module shall not be less than 25 years. Individual Solar Module rating shall not be less than 230 W at Standard test conditions.

6.9 Crystalline high power cells shall be used in the Solar Photovoltaic module. Solar module shall be laminated using lamination technology using established polymer (EVA) and Tedlar/Polyester laminate.

6.10 The solar modules shall have suitable encapsulation and sealing arrangements to protect the silicon cells from the environment. The arrangement and the material of encapsulation shall be compatible with the thermal expansion properties of the Silicon cells and the module framing arrangement/material. The encapsulation arrangement shall ensure complete moisture proofing during life of the solar modules.

6.11 Photo conversion efficiency of SPV Module shall be of 13.8%. Module shall be made of high transmissivity glass front surface giving high encapsulation gain.

6.12 All materials used shall be having a proven history of reliable, light weight and stable operation in external outdoor applications and shall have service life of more than 25 years.

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6.13 Module rating shall be considered under standard test conditions, however Solar Modules shall be designed to operate and perform under site condition including high temperature, and dust (sometimes).

6.14 Module shall be in accordance with the requirements of IEC 61215 / IEC61730 with appropriate certificate.

6.15 Solar PV Module design shall conform to following Mechanical requirement:

• Toughened, low iron content. • High transmissivity front glass. • Anodized Aluminium frame • Ethyl Vinyl Acetate (EVA) encapsulate • Silicon edge sealant around laminate • Tedlar/Polyester tri laminate back surface • Weatherproof DC rated MC connector and a lead cable coming out as a

part of the module, making connections easier and secure, not allowing for any loose connections.

• Resistant of water, abrasion, hail impact, humidity & other environment factor for the worst situation at site.

6.16 The module shall have a Power warranty of 25 years with degradation of power generated not exceeding 20% of the minimum rated power over the 25 years period and not more than 10% after ten years period.

6.17 Each module shall have low iron tempered glass front for strength and superior light transmission. It shall have back sheet for environment protection against moisture and high voltage electrical insulation.

6.18 The fill factor of module used shall not be less than 0.70 (typical).

5 PV Array Configuration:

The Solar array shall be configured in multiple numbers of sub-arrays, providing optimum DC power to auditable number of sub arrays.

6 Module Mounting Structure:

8.1 The structure design shall be appropriate and innovative and will follow the

existing structure and profile.

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8.2 The structure shall be designed to allow essay replacement of any module and shall be in line with site requirement.

8.3 The support structure design & foundation shall be designed to withstand wind speed applicable for the zone) using relevant Indian wind load codes.

8.4 The structure shall be designed for simple mechanical and electrical installation. It shall support SPV modules at a given orientation, absorb and transfer the mechanical loads to the ground properly with perfect alignment.

8.5 The array structure shall be made of hot dipped galvanized MS angles of suitable size.

8.6 The array structure shall be so designed that it will occupy minimum space without sacrificing the output from SPV panels at the same time.

8.7 Nut & bolts, supporting structures including Module Mounting Structures shall have to be adequately protected from atmosphere and weather prevailing in the area. Suitable provision for expansion be provided in view of high variation in day and night temperature.

8.8 All fasteners shall be of hot dipped galvanized MS. 8.9 The array structure shall be grounded properly using maintenance free earthing

kit. 8.10 The work will be carried out as per design approved by RREC

7 Junction Box:

9.1 The junction box shall be dust, vermin, and waterproof and made of FRP/ABS

Plastic. 9.2 The terminal will be connected to copper bus-bar arrangement of proper size. The

junction boxes shall have suitable cable entry points fitted with cable glands of appropriate sizes for both incoming and outgoing cables.

9.3 Suitable markings shall be provided on the bus-bars for easy identification and cable ferrules will be fitted at the cable termination points for identification. The junction box shall be Protection IP 65.

9.4 The Array junction Box will also have suitable surge protection. The junction Boxes shall have suitable arrangement for the followings (typical):-

8 Combine groups of modules into independent charging sub-arrays that will be wired into the controller.

ii) Provide arrangement for disconnection for each of the groups.

9 Provide a test point for each sub-group for quick fault location.

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iv) To provide group array isolation. v) The current carrying rating of the junction Boxes shall be suitable with

adequate safety factor to inter connect the Solar PV array.

10 Power Conditioning Unit {PCU}

10.1 Power Conditioning Unit {PUC} is critical equipment in Grid Connect SPV

Power plant. This equipment converts DC power generated by SPV array, into 3 phase voltage AC to be connected to Grid. It also provides necessary protections for Grid Synchronization and Data Logging/Monitoring.

10.2 MPPT controller, inverter and associated control and protection devices etc. all shall be integrated into PCU.

10.3 The DC energy produced has to be utilized to maximum and supplied to the DC bus for inverting to AC voltage to extract maximum energy from solar array and provides 400 VAC, 3-ph 50Hz to synchronize with local grid.

10.4 The PCU shall be of very high quality having efficiency not less than 96% and shall be capable of running in isolated mode.

10.5 The PCU shall have protection features such as, over current, short circuit, over temperature to name a few.

10.6 The PCU shall be designed for continuous, reliable power supply as per specification.

10.7 The PCU shall be designed to be completely compatible with the SPV array voltage and grid supply voltage.

10.8 It shall have user friendly LEDs/LCD display for programming and view on line parameters such as:

- DC power input, - DC input voltage, - DC current, - AC power output, - AC voltage (all the 3 phases and line) - AC current (all the 3 phases and line) - Power factor

- Inverter on - Grid on - Inverter under voltage/over voltage - Inverter over load - Inverter over temperature.

10.9 The PCU shall have arrangement for adjusting DC input current and shall trip against sustainable fault downstream and shall not start till the fault is rectified.

10.10 The 3 phase Grid connect PCU shall provide highly reliable and efficient energy conversion from DC to AC.

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10.11 Both AC&DC lines shall have suitable fuses and contactors to allow safe start up and shut down of the system.

10.12 Fuses used in the DC circuit shall be DC rated. 10.13 The PCU shall have provision for input & output isolation. Each solid-state

electronic device shall have to be protected to ensure long life of the inverter as well as smooth functioning of the inverter.

10.14 The PCU shall be capable of complete automatic operation, including wake-up, synchronization & shut down.

10.15 PCU shall be capable to synchronize independently & automatically/ to be phase locked and RVPN/Discom grid power line frequency to attain synchronization and export power generated by the solar panel to RVPN grid.

10.16 Built in with data logging to remotely monitor plant performance through external PC shall be provided (PC shall be provided along with SPV Plant).

10.17 Inverter shall be tested for islanding protection performance. 10.18 Following protections shall be provided: - Over voltage both at input & output. - Over current both at input & output. - Over/under grid frequency. - Over temperature. - Short circuit. - Protection against lightening. - Surge voltage induced at output due to external source. 10.19 The PCU shall be capable of operating in parallel with the grid utility service and

shall be capable of interrupting line fault currents and line to ground fault currents.

10.20 The PCU shall be able to withstand an unbalanced load conforming to IEC standard and relevant Indian electricity condition. The PCU shall include appropriate self protective and self diagnostic features to protect itself and the PV array from damage in the event of PCU component failure or from parameters – beyond the PCU’s safe operating range due to internal or external causes. The self-protective features shall not allow signals from the PCU front panel to cause the PCU to be operated in a manner which may be unsafe or damaging. Faults due to malfunctioning within the PCU, including commutation feature, shall be cleared by the PCU protective devices and not by the existing site utility grid service circuit breaker.

10.21 The PCU shall go to shutdown/standby mode, with its contacts open, under the following conditions before attempting an automatic restart after an appropriate time delay.

When the power available from the PV array is insufficient to supply the losses of the PCU, the PCU shall go to standby/shutdown mode. The PCU control shall prevent excessive cycling of shut down during insufficient solar radiance.

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10.22 Disconnection and Islanding

Disconnection of the PV generator in the event of loss of the main grid supply is to be achieved by inflicts protection within the power conditioner. This may be achieved through rate of change of current, phase angle, unbalanced voltages, or reactive load variants.

10.23 Operation outside the limits of power qualify as described in the technical data sheet shall cause the power conditioner to disconnect the grid.

11 Data monitoring of power plant:

The performance and generation data is recorded using a data logger. The performance and generation data is recorded using a data logger. The monitoring system shall comprise of the following main components:

11.1 PCU to log the inverter performance data and transmits the same to the Data logger.

11.2 Data logger shall than gathers information and monitors the performance of the inverter. It shall supports measurements from external sensors. The data can be acquired remotely via a modem.

11.3 PC Data logging software shall enable automatic long-time storage of measured data form PV- Plant. It shall allow visualization, monitoring, commissioning and service of the installation.

11.4 Communication interface the entire system can be operated and monitored via various interface viz.(RS232, RS485, MPI, Profit-bus, Telephone modem), in addition to the information indicated on the operator panel.

12 LT Power Interfacing Panel:

12.1 The panel shall have adequate inputs to take in from individual PCUs & adequate

outputs to individual transformers with adequate number of spare terminals. 12.2 The panel shall be floor mounted type and shall have all the measuring

instruments such as voltmeter, ammeter, and frequency meter, Electronic Energy Meter {for measuring the deliverable units {KWh} for sale, selector switches and Mimic panel

12.3 All the power cables shall be taken through top/ Bottom of the panel as per site requirement.

12.4 The panel shall fitted with suitable rating & size copper bus, MCCB, HRC fuses/circuit breaker/isolator, indicators for all incomer and outgoing terminals,

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LED voltmeter & Ammeter with suitable selector switches to monitor & measure the power to be evacuated.

12.5 Nut & bolts including metallic shall have to be adequately protected against atmosphere and weather prevailing in the area.

13. Plant Monitoring Desk: 13.1 Computer aided data acquisition unit shall have features for simultaneous

monitoring and recording of various parameters of different sub-systems, power supply of the Power Plant at the DC side and AC side.

13.2 Computer Aided Data Acquisition Unit shall be a separate & Individual system comprising of different transducers to read the different variable parameters, A/D converter, Multiplexer, De-multiplexors, Interfacing Hardware & Software, Industrial Type PC, which will be robust & rugged suitable to operate in the Control Room environment.

13.3 Reliable sensors for solar Radiation, Temperature & other electrical Parameters are to be supplied with the data logger unit.

13.4 The PC Shall of Industrial type, rugged & robust in nature to operate in a hostile environment. The PC shall have minimum Intel 2 Duo processor having 2 ×150 GB HDD with 2 GB RAM. The PC shall also have 21” TFT colour monitor, DVD Drive with writer, multimedia kit and UPS with 4 hours Power back up. The printer shall be of industrial type, rugged & robust in nature. The printer shall be equipped for printing, scanning, copying and fax.

13.5 The data acquisition system shall perform but not limited to the following operations:

• Measurement and continuous recording of (I) ambient Air Temperature

near Array Field (II) Control Room Temperature (III) Module Back Surface Temperature (IV) Wind Speed at the level of Array Plane (V) Solar Irradiation Incidental to Array Plane (VI) Inverter Output (VII) System Frequency (VIII) DC Bus Output (IX) Energy delivered to the GRID in kWhr.

• All data shall be recorded chronologically date wise. The data file shall be MS Excel compatible. The data logger shall have internal reliable battery backup to record all sorts of data simultaneously round the clock. All data shall be stored in a common work sheet chronologically. Representation of monitored data shall be in graphics mode and/or in tabulation form. All instantaneous data can be shown in the Computer Screen.

• The data acquisition system shall be housed in a desk made of sheet steel.

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13 Lightning & Over Voltage Protection:

14.1 The SPV Power Plant shall be provided with Lightning and over voltage

protection connected to proper earth mats. The main aim of over voltage protection is to reduce the over voltage to a tolerable level before it reaches the PV or other sub-system components. The source of over voltage can be lightning or other atmospheric disturbance.

14.2 The lightning Masts shall be made as per applicable Indian Standard/International Standard in order to protect the Yard from Lightning stroke. Necessary structure and foundation for holding the lightning mast, in its position, to be made after giving due consideration to maximum wind speed.

14.3 The lightning Mast shall be earthed through flats and connected to the Earth mats as per applicable Indian Standards with earth pits. Earth mat/earthing strip shall be fitted with individual earth pit as per required Standards including accessories, and providing masonry enclosure with cast iron cover plate having locking arrangement, watering pipe using charcoal or coke and salt as per required provisions of IS.

14.4 RREC shall ensure adequate lightning protection to provide and acceptable degree of protection as per IS for the array yard/Shed. If necessary more numbers of Lightning conductors may be provided. Design calculations and detailed explanations (in 4 sets) shall be duly checked while implementation.

14.5 Lightning- Conductor shall be as per requirements of IS Standards. 14.6 All building earth conductor shall be interconnected through the concept of “Earth

Mats” for interconnection with separate earth pits. 14.7 For each earth pit, necessary Test Point shall have to be provided..

14 Earthing System:

15.1 The earthing for LT side (Solar Power Plant side) array and LT power system

shall be as required as per provisions of Indian Standard/International Standard. Necessary provision shall be made for bolted isolating joints of each earthing pit for periodic checking of earth resistance.

15.2 Each array structure of the SPV Yard/shed shall be grounded properly. The array structure are to be connected to earth pits as per IS standards.

15.3 The earthing for the power plant equipment shall be made with as per provisions of IS. Necessary provisions shall be made for bolted isolating joints of each earthing pit for periodic checking of earth resistance.

15.4 The complete earthing system shall be mechanically & electrically connected to provide independent return to earth. All three phase equipment shall have two distinct earth connections.

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15.5 An Earth Bus shall be provided inside the control room. 15.6 For each earth pit, necessary Test Point shall have to be provided. 15.7 In compliance to Rule 33 and 61 of Indian Electricity Rules, 1956 (as amended up

to date) all non-current carrying metal parts shall be earthed with two separate and distinct earth continuity conductors to an efficient earth electrode.

15.8 Earth resistance of the earth pits shall be got tested in presence of the representative of RREC.

15 Cables & Installation Accessories:

LT Cables:

16 KV Grade, Al. Conductor PVC Armoured Cables shall be used for all LT Power Cables between Power & Motor Control Cubicles, MCC, Respective feeders, etc. These cables shall be laid on structural supports and using Galvanized Cable trays of adequate strength. The cable shall be terminated using Al. Lugs of adequate cross section area. The PMCC’s and the MCC’s shall be located in the Basement with cable entry on top.

Control Cables:

17 KV Grade, Cu. Conductor, PVC Armoured Cables shall be used for all control cables required for the Solar Power Plant. These cables shall be laid on structural supports and using Galvanized Cable trays of adequate strength. The cable shall be terminated using Cu. Lugs of adequate cross section area.

Instrumentation Cables: a. Cu. Conductor, PVC Armoured with miller insulation between each pair and

tinned copper screening. All cables shall be PVC insulated with appropriate grade conforming to IS.

b. The wiring for module inters connection shall be with hard PVC conduit of approved make. All Tees, Bends etc., shall be standard make.

c. Only terminal cable joints shall be used. d. Cables inside the control room shall be laid in suitable Cable Trays of

approved type. e. All wires used on the LT side shall conform to IS and shall be of appropriate

voltage grade. Only copper conductor wires of reputed make shall be used.

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f. Cable terminations shall be made with suitable cable lugs & sockets etc., crimped properly and passed through brass compression type cable glands at the entry and exit point of the cubicles. The panels’ bottoms shall be properly sealed to prevent entry of snakes/lizard etc. inside the panel.

g. All cable/wires shall be marked with good quality letter and number ferrules of proper sizes so that the cables can be identified easily.

h. The terminal end of cables and wires are to be fitted with good quality letter and number ferrules of proper sizes so that the cables can be identified easily.

18 Load Trials & Reliability test at Site for Grid Connect Solar Power Plant:

17.1 Performance Guarantee Test at Site for Grid Connect Solar Power Plant, HT Panel etc.

These tests will be conducted at site as per site conditions at available load and after performing all pre-commissioning check and trials and after readiness of the entire Solar Power Plant system which are required to carry out the load trials.

17.2 All the tests which are mentioned in the load test of Solar Power Plant will be carried out

by RREC at site. 17.3 All the equipments supplied by the vendor will be tested as per relevant standard/ Quality

assurance plan at site conditions and the performance monitored. 18. Bill of Materials For 1 MW Solar PV Plant

Item Details Unit Qty.

PV Module Nos 4368

Module Mounting Structures Set 364

Solar module and Junction Interconnection cable (Cu) Mtr lot

Inverter and Junction box Interconnection Cable(Cu)

Mtr lot

AC Cable Mtr lot

Inverter 250 KW Nos 4

Monitoring system Set 1

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Transformers Set 2

Transformer & Switchyard civil work Set 1

Switchyard Equipments Lot 1

Lightning Arrester Set 2

String Insulator Lot 1

BUS Post Insulator Lot 1

Earth mat for switch yard and equipments Set 1

Main Junction Box Nos L.S

Surge Protection Nos L.S.

Fuses Nos L.S

Security guard accommodation No. 1

Fencing Lot 1

Rubber Mat – 12 mm Lot 1

Foam type fire extinguisher Lot 1

CO2 Extinguisher Lot 1

Sand Bucket Lot 1

Transformer discharge Rod Lot 1

Lighting arrangement for the plant safety Lot 1

Installation cost Lot 1

Local Project Management & Transportation Lot 1

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C H A P T E R -10

10. Cost of Project and Financial Analysis 10.1 Annual Generation: Annual Generation has been taken as guaranteed by M/S Larsen & Toubro Limited as under, Year Generation in units 1 1715000 2 1704710

3 1694482

4 1684315 5 1674209

6 1664164 7 1654179 8 1644254 9 1634388 10 1624582 11 1615809 12 1607084

13 1598405 14 1589774

15 1581189 16 1572651 17 1564159 18 1555712 19 1547311 20 1538956

21 1530645 22 1522380

23 1514159

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24 1505983 25 1497850

10.3 Operation and Maintenance: Operation and maintenance are considered as per the M/S Larsen & Toubro Limited quote as under, Year O & M charges in Rs. 1 1100000 2 1155000

3 1212750

4 1273388 5 1337057

6 1403910 7 1474105 8 1547810 9 1625201 10 1706461 11 1791784 12 1881373

13 1975442 14 2074214

15 2177925 16 2286821 17 2401162 18 2521220 19 2647281 20 2779645

21 2918627

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22 3064559 23 3217787 24 3378676 25 3547610 Total 5,24,99,809

10.4 CDM Benefits: Solar PV plant is a cleanest source of energy; it shall be entitled to and shall claim CDM benefits. CDM benefit, inter-alia, depends on non firm / firm supply of power, as such till experience is gained i.e. during intial years it will be no firm supply and even thereafter, due to annual variation, it may partially be firm and partially be infirm. CDM credit is market dependant. It will not be possible to quantify it beforehand and has not been considered in tariff calculations. RREC shall share the CDM benefits as per clause 42 of RREC tariff regulations. 10.5 Project Cost and Tariff: The total project cost has been considered as Rs. 1505 Lacs. The breakup of cost is as under: A i) Project Cost = 1475 Lacs ii) Cost of the land = 8 Lacs iii) Cost of boundary wall = 17 Lacs iv) Finance Charges including petition charges = 5 Lacs B Grant from the Govt. which is 50% of the installed cost of 1 MWp power plant but excluding the cost of land, extension line and AMC i.e. 50% of (1505-8) = 1497/2 = 748.5 Lacs C Net Cost to RREC = A – B = 756.5 Lacs The Tariff Calculations are annexed as Main Annexure no. 12

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10.6 Basis of Financial Analysis: Following norms are considered for financial analysis: a) Grant - 748.5 Lacs b) Debt: Equity Ratio – 70:30 c) Interest rate on long term loans – 12.75% d) Moratorium period – 0 months e) Loan repayment period – 12 years f) Depreciation – 5.28% g) Salvage Value – 10%

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MNRE Schemes under which the proposal is covered

Ministry of New and Renewable , Government of India No.32/72/ 2008-09/PVSE

,Dated: 28th

February, 2009 conveyed the sanction of the President for undertaking a Demonstration Programme on Tail-end grid connected Solar Power Plants in the country

during the 11th

Plan period, as per the provisions given in the following sections and in the enclosed Annexure-I. 2. Objectives:

The main objective of the Demonstration Programme is to connect solar power plant at the tail-end of the grid for providing voltage support to strengthen the grid and to provide additional power for day time use. 3. Implementation Arrangements

Any distribution company or Electricity Board which is authorized in the State / Uts to distribute or generate electricity will be eligible to take up the projects under the demonstration programme. In addition, State Nodal Agencies are also eligible, provided they connect the plant to the grid at the tail-end and feed power to the tail-end grid. Any of the above mentioned eligible organizations can submit a proposal directly to the Ministry for seeking financial support and that organization will be considered as the project implementing agency. Each proposal must be supported by a Detailed Project Report (DPR). 4. Targets and Central Financial Assistance

Tail-end grid connected solar power plants, with an aggregate capacity up to 4 MWp may be supported under the demonstration programme. The Ministry will provide Central Financial Assistance (CFA) up to 50% of the ‘installed cost’ of Solar Power plant, excluding cost of land, extension of line for power evacuation, civil works and cost of AMC, or a maximum of Rs.10.00 crore (Rupees ten crore) per MW of solar capacity used in the tail-end supported solar power projects. Cost of preparation of DPR will also not be covered under the eligible CFA. One percent (1%) of the MNRE CFA will be provided as administrative charges to the implementing agency, subject to a maximum of Rs. 10 lakh per project. Ministry will provide, on case-to-case basis, full support for training; capacity building; third party monitoring; and impact assessment studies relating to the Demonstration Programme.

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5. Technical & Performance Requirements

The broad technical and performance requirements of tail-end grid connected solar power plants covered under the Demonstration Programme are given in Annexure – I. 6. Monitoring Arrangements

The implementing agencies will devise suitable arrangements for monitoring and evaluation of tail-end grid connected solar power plants sanctioned under this Demonstration Programme in accordance with the guidelines given in Annexure-I. They may also take other measures as considered appropriate for monitoring/inspection / performance evaluation of grid interactive solar PV power generation projects in the field. In addition, if considered necessary, Ministry may inspect the plant or commission other organizations/experts to inspect the plant and undertake performance evaluation study. Director MNRE further conveyed that – 1 Necessary funds for implementation of the Demonstration Programme during 2008-

09 will be drawn from the Ministry’s budget head – ‘2810’ Non-Conventional Sources of Energy (Major Head), 02.120-Photovoltaic (Minor Head), 05-Grid Interactive SPV Power Projects 05.01-Research & Development, 05.01.31-Grants-in-aid, during the year 2008-09 (Plan).

2 This sanction issues in exercise of powers delegated to this Ministry and with the concurrence of IFD vide No IFD/2134/08 dated 19/2/2009 and concurrence dated 28/2/2009. 3 This sanction has been entered at Sl. No 39 on page No. 14 in the register of Grants.

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Annexure I

Guidelines for Demonstration Programme on Tail-end grid connected Solar Power Plants Following are the broad guidelines for submission of proposals by the implementing organizations, technical and performance requirements of tail-end grid connected solar power plants, eligibility criteria, Central Financial Assistance (CFA), monitoring & feedback mechanism and documents required to be submitted. 1. Eligible Organizations

Any company or Electricity Board which is authorized in the States / Uts to distribute or generate electricity will be eligible. In addition, State Nodal Agencies (SNAs) are also eligible, provided they connect the plant to the grid at the tail-end and feed power to the tail-end grid. Any of the above mentioned eligible organizations can submit a proposal direct to the Ministry for seeking financial support and that organization will be considered as the project implementing agency. Each proposal must be supported by a Detailed Project Report (DPR). 2 Eligible Projects & Eligibility Criterion 2.1 Tail-end grid connected solar power generation plants of a minimum installed capacity of 25 kWp per plant at a single location and a maximum capacity of 1 MWp per plant at a single location that can be connected to LT grid or 11 kV grid will be eligible for Central Financial Assistance (CFA) under this Demonstration Programme. 19 A maximum cumulative capacity of 4 MWp of tail-end grid connected solar power plants can be set up under the Demonstration Programme. 2.3 Any eligible organization which 78tilize the procedural requirements and the guidelines specified by the Ministry will be eligible for consideration of CFA. The projects for tail end grid connected solar power plants will be owned by the concerned eligible agency to which the project is sanctioned by the Ministry. 3 Procedures to be followed for availing Central Financial Assistance (CFA)

1.1 A proposal may be submitted to the Ministry to seek Central Financial Assistance (CFA) for setting up a tail-end grid connected solar power plant by any of the eligible organization. Each proposal must be supported by a Detailed Project Report (DPR).

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1.2 The implementing agency will prepare a Detailed Project Proposal for installation of the solar power plant to the tail-end grid. Details of the selected site, the status of the tail-end grid, load profile, details of power shortage during day-time and its impact on load shifting to evenings, etc, would be covered in the proposal. The proposed capacity of the solar plant, its location, distance from the existing grid; estimated life of the PV power plant; quantum of electricity expected to be generated and fed to the grid; estimated benefit to the stability of the grid; and the likely benefits in terms of load being serviced during day-time, etc. will also be provided. The estimated cost of the solar power plants, technical specifications, plant layout, proposed implementation schedule, cost sharing, safety related aspects will also be included. PV modules, control electronics and storage battery etc. which qualify to the international or Indian module qualification standards will be eligible for use in tail-end connected solar power plants. Use of cables, structures and other safety related instrumentation etc. will be as per the existing Indian standards and the provisions of the Indian Electricity Act. The concerned agency will be fully responsible to test and certify the plant for grid connectivity and compliance of related procedures

1.3 In addition, the proposal should be supported by (i) details of the power evacuation point and permission for connecting the solar plant; (ii) consent of the distribution company to take solar power in the tail-end distribution system; (iii) details of the land in possession for setting up the plant and status of clearances, if required.

1.4 If necessary, Ministry may request a presentation on the proposal or seek clarifications about the proposal.

1.5 The supply and installation of tail-end grid connected solar power plant will be done through tendering process, from qualified suppliers, who have experience in installation of grid connected solar power plants in India.

1.6 The implementing agency will be required to install and commission the tail-end grid connected power plants within the time frame communicated at the time of sanctioning the project. First progress report must be submitted to the Ministry within three months from this date. Thereafter, Quarterly Progress Report (QPR) should be submitted till installation and commissioning is reported.

20 A dedicated electronic meter or any other meter(s) as specified and approved by the utility will be installed at the point of power evacuation and/or any other point as considered necessary by the implementing agency. This will be used for monitoring the quantum of net electricity being fed in to the grid from that plant. 3.8 The implementing agencies will maintain a record of power generation, incident solar radiation on the PV array surface and other technical features of the power plant. A

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copy of the data should also be available in electronic form. This record will also be made available to the Ministry, when required. 4. Central Financial Assistance (CFA) and Release of Funds 4.1 The Ministry will provide Central Financial Assistance (CFA) up to 50% of the ‘installed cost’ of the solar power plant, excluding the cost of land, extension of line for power evacuation, civil works and cost of AMC, or a maximum of Rs.10.00 crore (Rupees ten crore) per MW of solar capacity used in the tail-end supported solar power projects. Cost of preparing DPR will also not be covered under the eligible CFA. 4.2 One percent (1%) of the MNRE CFA will be provided as ‘Administrative charges’ to the implementing agency, subject to a maximum of Rs.10.00 lakhs (Rupees ten lakh) per project. 4.3 Ministry will provide full support, on case-to-case basis, for training, capacity building, third party monitoring and impact assessment studies relating to the demonstration programme. Release of Funds: 21 25% of the estimated CFA will be released at the time of the approval/ sanction of the project proposal under the demonstration programme. 22 Another 60% of the eligible CFA will be released on submission of the purchase order placed for installation and commissioning of solar power plant and a progress report of the project in MNRE format as per Annexure II. 23 The implementing agencies will submit in duplicate Utilization Certificate (UC) for the funds released by the Ministry; and audited Statement of Expenditure (SoE) as per formats at Annexure-III and IV. 24 At the time of seeking the final release of CFA, the implementing agencies will submit a detailed project completion report as per Annexure-V and Utilization Certificate & consolidated audited Statement of Expenditure for settlement of accounts as per Annexure III and IV. 25 The balance 15% CFA will be released after successful commissioning of the solar power plant and submission of UC for the funds already released, SoE and the project completion report in the MNRE formats. (vi) The administrative charges will be released at the time of release of the third 80tilized80t of CFA, on commissioning of the plant.

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(vii) For all other activities, the funds will be released in a maximum of two installments. The first installment will be at least 50% of the sanctioned amount. 5.0 Technical Performance Optimization 5.1 With a view to encourage technology development and reduction in the cost of the PV power plant projects, the implementing agencies are expected to utilize the state-of-the art technology to set up the plants. They are expected to use large capacity and higher power output PV modules available for the specific technology used in setting up the power plant. 5.2 Qualification of PV modules, to be used in tail-end grid connected solar PV power plants, in accordance with the standards issued by BIS or IEC 61215 certification or other international certification on qualification of PV modules will be necessary. Use of modules which do not conform to BIS or any international certification is not permitted. 5.3 The electronics, cables, controls, structures, storage batteries (if any), etc. must qualify to latest BIS or international standards which are acceptable to utilities and which fulfill all safety norms for grid connected power projects. 1 The PV power project connected to tail-end grid should be designed to optimize generation in electricity in terms of kWh generated per MWp of PV capacity installed vis-à-vis available solar radiation at the site (may be obtained through use of efficient electronics, lower cable losses, maximization of power transfer from PV modules to electronics and the grid, maximization of power generation by enhancing incident radiation by optional methods like seasonally changing tilt angles etc).

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2 Monitoring and Progress Report 2.4 The implementing agencies will install suitable instruments and make adequate arrangements to monitor the technical performance and ensure satisfactory operation of the tail-end grid connected solar power plants.

2.5 The concerned State Nodal Agency may also visit the project site and provide their feed back and recommendation to the implementing agency and the Ministry.

2.6 All projects set up under the demonstration programme will be open to inspection by the officials from Ministry, IREDA, concerned state nodal agency and any independent organization appointed by the Ministry/IREDA for performance monitoring. 2.7 The Ministry may also undertake field evaluation studies for any of the tail-end grid connected solar plants through professional and independent organizations. 2.8 The implementing agencies will be required to submit quarterly and annual progress report about the project to the Ministry. 26 The implementing agencies will furnish an annual report on generation of electricity from each plant, in the format given in Annexure-VI.

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Annexure II

FORMAT FOR THE QUARTERLY PROGRESS REPORT (QPR)

1. Name of the State: 2. Name of the Implementing agency: 3. Project Location: 4. Name of utility & location where power evacuation is done: 5. Approved PV Capacity for which funds are disbursed: 6. Present status of the plant: 7. Date of project commissioning: 8. Duration for which power is fed to the grid (Quarter No/Year) ….. to …….. 9. Total number of units actually fed to the grid in the quarter 10. Funds released by the Ministry so far 11. Funds required from the Ministry (Please enclose details on separate sheet) 12. Other promotional activities performed

Certified that

27 The above mentioned tail end grid connected solar PV power project is under installation and likely to be commissioned by …….. which is as per approved schedule. A report on the recent progress is enclosed. (In case of delays detailed justification will be necessary)

or 28 The above mentioned tail end grid connected solar PV power project has been commissioned and functioning successfully The progress of implementation of the project is satisfactory and the detailed progress on installation of the tail end solar power plant is enclosed. (ii) Complete technical, performance, generation and other details for the project are available with the agency Date Place

Signature (Name & Designation of the Authorized Officer)

Date & Office Seal

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ANNEXURE –III

FORMAT FOR SUBMITTING UTILISATION CERTIFICATE (To be submitted in duplicate on the letterhead)

S. No. Letter No. & Date Amount (Sanctioned)

(Released)

TOTAL

Certified that out of Rs………. Of grants-in-aid released during the year -----in favour of ----------------------------------------under this Ministry Letter No. given in the margin and Rs.-------------on account of unspent balance of the previous year, a sum of Rs.---------------has been 84tilized for the purpose of -------------------------for which it was sanctioned and that the balance of Rs.------------------remaining unutilized at the end of the year has been surrendered to Government (vide No. --------------------------dated) / will be adjusted during -------towards the grants-in-aid payable during the next year -------------------. 29 Certified that I have satisfied myself that the conditions on which the grants-in-aid was sanctioned have been duly fulfilled / are being fulfilled and that I have exercised the following checks to see that the money was actually utilized for the purpose for which it was sanctioned. Kinds of checks exercised

1 2 3 4 5

Signature -------------- Designation ----------- Date ------------------- Official seal

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ANNEXURE – IV

FORMAT FOR SUBMITTING AUDITED STATEMENT OF ACOUNTS (To be submitted on the Letter Head)

Name of the State Name of the Implementing agency Project Approval Details Total installed capacity (MWp) Funds released by MNRE (sanction order & date wise details)

CFA sanctioned Actual date of commissioning of the plant

(a) Total expenditure incurred on setting up the plant

(b) Expenditure incurred on eligible cost of the plant

(c)Eligible CFA as 50% of the eligible cost, subject to a maximum of Rs. 10 cr per MW, whichever is lower

(d) Administrative charges for @ 1% of the eligible CFA

(e) Total funds to be received from MNRE (c+d)

(f) Funds already released by MNRE (g) Interest Accrued on funds released by MNRE

(h) Total funds available with the agency (f+g)

(i) Balance funds to be released by MNRE (e-h) or to be refunded to MNRE

The above information is based on audited accounts and verifications carried out by the agency and the auditors.

Signature Signature (Name &Designation) Place & Date Seal of Auditor

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Consolidated Statement of Expenditure

(To be sent in duplicate to the Ministry of New and Renewable Energy for the financial year (from ________ to __________) Title of the Project/Demonstration programme:

30 Name of the organization: 31 Ministry of New and Renewable Energy letter No. And date of sanctioning the project : 32 Amount brought forward from the previous financial year : quoting Ministry of New and

Renewable Energy letter No. And date on which the authority to carry forward the said amount was given :

33 Amount released by Ministry of New and Renewable Energy during the financial year: (please give letter No. & date of sanctions showing the amount paid)

34 Interest accrued on funds available 35 Total amount (Sr. No. 4+5+6): 36 Actual expenditure incurred during the financial year : 37 Balance amount available at the end of the financial year : 38 Unspent balance refunded, if any. (Please give details of cheque no. Etc. ) 39 Amount allowed to be carried forward to the next financial year vide letter no. And date :

Certified that the expenditure of Rs. _________ (Rupees _______________ mentioned against Column 7 was actually incurred on the Project / Demonstration programme for the purpose for which it was sanctioned and balance amount of Rs. ________ is available on ___________ or refunded on … .

(Signature & Seal)

(Signature of Head of organization) (Head Finance of the Organization)

(Signature & Seal of Auditor)

Accepted by COMPETENT AUTHORITY MINISTRY OF NEW AND RENEWABLE ENERGY

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Annexure –V

PROJECT COMPLETION REPORT

1. Name of the State: 2. Name of the Implementing Agency: 3. Project Location: 4. Name of utility: 5. Approved PV Capacity for which funds are sanctioned and disbursed 6. Present status of the plant 7. Date of project commissioning 8. Duration for which power is fed to the grid: 9. Total number of units actually fed to the grid (Quarter No/Year)

1 Expenditure Incurred on the project (as per SoE) 2 Funds released so far & balance requested from Ministry (Please provide details)

Certified that 40 The above mentioned tail end grid connected solar PV power plant project has been successfully completed in accordance with the guidelines of the MNRE demonstration programme (ii) Complete technical, performance, generation and other details for the project are available with the agency. Performance data is being collected regularly. The performance of the plant has been inspected by the agency and found to be satisfactory. In addition third party monitoring has been/not been conducted. (Please provide details) 41 Financial year-wise Audited SOE and UC have been submitted (copies enclosed) to the Ministry. Place: Date:

Signature (Name & Designation of the Authorized Officer)

Date & Office Seal

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Annexure VI

FORMAT FOR THE ANNUAL PROGRESS REPORT

1. Name of the State: 2. Name of the Implementing agency: 3. Project Location 4. Name of utility& location where power evacuation is done 5. Approved PV Capacity for which funds are disbursed 6. Present status of the plant and performance data 7. Date of project commissioning 8. Duration for which power is fed to the grid (Quarter No/Year) ….. to …….. 9. Total number of units actually fed to the grid in the quarter 10 Funds released by the ministry so far 11 Funds required from the Ministry (Please enclose details on separate sheet) 42 Other promotional activities performed

Certified that: (i) The above mentioned tail end grid connected solar PV project has been

commissioned and functioning successfully / is under installation and like to be commissioned by, which is as per approved schedule (In case of delays detailed justification will be necessary).

(ii) Complete technical, performance, generation and other details for the project are available.

(iii) Audited SOE and UC have been submitted (copy enclosed) to the Ministry.

Place: Date:

Signature

(Name & Designation of the Authorized Officer) Date & Office Seal

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Annexure – VIII

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Annexure - VIII

SSE

Homepage Find A Different Location Accuracy Methodology Parameters (Units & Definition)

NASA Surface meteorology and Solar Energy - Available Tables

Latitude 26.5 / Longitude 75.5 was chosen.

Geometry Information Elevation: 333 meters

averaged from the USGS GTOPO30

digital elevation model

Northern boundary27

Western boundary 75

Center Latitude 26.5

Longitude 75.5

Eastern boundary 76

Southern boundary26

Show A Location Map

Parameters for Solar Cooking:

Monthly Averaged Insolation Incident On A Horizontal Surface (kWh/m2/day)Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 4.00 4.71 5.46 6.11 6.38 6.24 5.09 4.71 5.12 4.79 4.16 3.74Parameter Definition

Monthly Averaged Midday Insolation Incident On A Horizontal Surface

(kW/m2) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 0.56 0.65 0.73 0.79 0.80 0.77 0.63 0.60 0.69 0.68 0.61 0.56Parameter Definition

Monthly Averaged Clear Sky Insolation Incident On A Horizontal Surface

(kWh/m2/day) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

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22-year Average 4.20 4.99 5.73 6.28 6.54 6.78 6.62 6.20 5.65 4.99 4.23 3.86

Parameter Definition

Monthly Averaged Clear Sky Days (days) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 15 11 9 8 8 5 1 1 5 15 16 16 Parameter Definition

Parameters for Sizing and Pointing of Solar Panels and for Solar Thermal Applications:

Monthly Averaged Insolation Incident On A Horizontal Surface (kWh/m2/day)Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 4.00 4.71 5.46 6.11 6.38 6.24 5.09 4.71 5.12 4.79 4.16 3.74 5.04

Minimum And Maximum Difference From Monthly Averaged Insolation (%)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Minimum -16 -12 -11 -7 -8 -11 -19 -16 -12 -9 -11 -9 Maximum 18 11 14 11 16 11 32 20 8 11 9 17

Parameter Definition

Monthly Averaged Diffuse Radiation Incident On A Horizontal Surface (kWh/m2/day)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 1.02 1.27 1.64 1.98 2.22 2.37 2.47 2.31 1.90 1.44 1.09 0.95 1.72

Minimum 0.66 1.06 1.32 1.74 1.85 2.17 2.16 2.19 1.80 1.24 0.92 0.64 1.48 Maximum 1.22 1.46 1.82 2.09 2.34 2.49 2.43 2.27 2.00 1.56 1.23 1.07 1.83 22-year Average K 0.61 0.60 0.59 0.58 0.57 0.55 0.45 0.44 0.53 0.58 0.60 0.61 0.56

Minimum K 0.51 0.53 0.52 0.54 0.52 0.48 0.37 0.37 0.47 0.53 0.54 0.55 0.49

Maximum K 0.72 0.67 0.67 0.64 0.66 0.61 0.60 0.53 0.57 0.64 0.66 0.71 0.64

Diffuse radiation, direct normal radiation and tilted surface radiation

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NOTE: are not calculated when the clearness index (K) is below 0.3 or above 0.8.

Parameter Definition

Monthly Averaged Direct Normal Radiation (kWh/m2/day) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 6.13 6.22 6.14 6.15 6.02 5.59 3.79 3.52 4.99 5.81 6.10 5.97 5.53

Minimum And Maximum Difference From Monthly Averaged Direct Normal

Radiation (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Minimum -9 -10 -7 -4 -3 -12 -24 -26 -16 -6 -9 -1 Maximum 17 9 16 12 21 14 63 40 8 11 7 18

NOTE:

Diffuse radiation, direct normal radiation and tilted surface radiation are not calculated when the clearness index (K) is below 0.3 or above 0.8.

Parameter Definition

Monthly Averaged Insolation Incident On A Horizontal Surface At Indicated GMT Times (kW/m2)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average@00 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Average@03 0.16 0.19 0.26 0.34 0.38 0.37 0.28 0.27 0.28 0.28 0.23 0.17Average@06 0.56 0.65 0.73 0.79 0.80 0.77 0.63 0.60 0.69 0.68 0.61 0.56Average@09 0.49 0.56 0.63 0.68 0.68 0.66 0.55 0.51 0.55 0.52 0.46 0.44Average@12 n/a n/a 0.14 0.16 0.19 0.20 0.17 0.14 0.11 n/a n/a n/a Average@15 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Average@18 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Average@21 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Parameter Definition

Monthly Averaged Insolation Clearness Index (0 to 1.0) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average K 0.61 0.60 0.59 0.58 0.57 0.55 0.45 0.44 0.53 0.58 0.60 0.61 0.56

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Minimum K 0.51 0.53 0.52 0.54 0.52 0.48 0.37 0.37 0.47 0.53 0.54 0.55 0.49

Maximum K 0.72 0.67 0.67 0.64 0.66 0.61 0.60 0.53 0.57 0.64 0.66 0.71 0.64

Parameter Definition

Monthly Averaged Insolation Normalized Clearness Index (0 to 1.0) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 0.56 0.55 0.54 0.53 0.52 0.50 0.41 0.40 0.48 0.53 0.55 0.55Parameter Definition

Monthly Averaged Clear Sky Insolation Incident On A Horizontal Surface

(kWh/m2/day) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 4.20 4.99 5.73 6.28 6.54 6.78 6.62 6.20 5.65 4.99 4.23 3.86 5.50

Parameter Definition

Monthly Averaged Clear Sky Insolation Clearness Index (0 to 1.0) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 0.64 0.64 0.62 0.60 0.58 0.59 0.59 0.58 0.59 0.61 0.62 0.63Parameter Definition

Monthly Averaged Clear Sky Insolation Normalized Clearness Index (0 to 1.0)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 0.58 0.58 0.56 0.55 0.53 0.54 0.54 0.53 0.53 0.55 0.56 0.57Parameter Definition

Monthly Averaged Downward Longwave Radiative Flux (kWh/m2/day)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 7.17 7.55 8.42 9.07 9.63 10.3 10.3 10.2 9.69 8.61 7.72 7.33 8.85

Parameter Definition

Solar Geometry:

Monthly Averaged Solar Noon (GMT time)

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Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average 0708 0713 0707 0659 0655 0658 0705 0703 0654 0644 0643 0651Parameter Definition

Monthly Averaged Daylight Hours (hours)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average 10.6 11.2 12.0 12.7 13.4 13.7 13.6 13.0 12.3 11.5 10.8 10.5Parameter Definition

Monthly Averaged Daylight Average Of Hourly Cosine Solar Zenith Angles

(dimensionless) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average 0.41 0.50 0.55 0.59 0.63 0.65 0.64 0.61 0.59 0.54 0.44 0.39Parameter Definition

Monthly Averaged Cosine Solar Zenith Angle At Mid-Time Between Sunrise

And Solar Noon (dimensionless) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average 0.48 0.54 0.61 0.66 0.68 0.68 0.68 0.67 0.64 0.57 0.50 0.46Parameter Definition

Monthly Averaged Declination (degrees)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average -20.7 -12.3 -1.8 9.70 18.8 23.0 21.2 13.7 3.09 -8.45 -18.1 -22.8Parameter Definition

Monthly Averaged Sunset Hour Angle (degrees)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average 79.0 83.7 89.0 94.8 99.7 102 101 97.0 91.5 85.7 80.5 77.8Parameter Definition

Monthly Averaged Maximum Solar Angle Relative To The Horizon (degrees)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average 42.7 51.1 61.6 73.2 82.3 86.5 84.7 77.2 66.5 55.0 45.3 40.6

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Parameter Definition

Monthly Averaged Hourly Solar Angles Relative To The Horizon (degrees) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

0000 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 0100 GMT n/a n/a n/a 4.67 9.47 10.5 8.45 5.61 2.88 n/a n/a n/a 0200 GMT 1.71 4.87 11.0 18.0 22.5 23.3 21.3 18.8 16.2 12.9 8.27 4.160300 GMT 13.5 17.4 24.1 31.4 35.8 36.4 34.4 32.2 29.5 25.4 19.9 15.50400 GMT 24.3 29.2 36.7 44.7 49.2 49.7 47.8 45.6 42.3 37.0 30.4 25.60500 GMT 33.4 39.5 48.3 57.4 62.5 63.1 61.2 58.7 54.1 46.9 38.8 33.80600 GMT 39.9 47.3 57.4 68.2 75.3 76.5 74.4 70.6 63.3 53.4 44.1 39.10700 GMT 42.6 51.0 61.6 73.2 82.2 86.5 84.6 77.2 66.5 54.8 45.1 40.50800 GMT 41.0 49.4 58.9 67.7 73.0 75.4 76.1 71.4 61.6 50.4 41.4 37.80900 GMT 35.5 43.1 50.6 56.6 60.1 62.0 63.0 59.6 51.6 41.8 34.1 31.51000 GMT 27.0 33.6 39.5 43.9 46.7 48.6 49.6 46.6 39.5 30.9 24.4 22.61100 GMT 16.5 22.4 27.1 30.6 33.3 35.3 36.2 33.2 26.5 18.7 13.1 12.01200 GMT 4.99 10.1 14.0 17.2 20.0 22.3 23.0 19.8 13.2 5.85 0.96 0.411300 GMT n/a n/a 0.73 3.93 7.09 9.57 10.1 6.57 n/a n/a n/a n/a 1400 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1500 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1600 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1700 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1800 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1900 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2000 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2100 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2200 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2300 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Parameter Definition

Monthly Averaged Hourly Solar Azimuth Angles (degrees) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

0000 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 0100 GMT n/a n/a n/a 81.5 73.6 69.3 70.3 77.2 87.8 n/a n/a n/a 0200 GMT 114 106 97.7 88.0 79.4 74.8 76.0 83.5 94.6 106 115 1180300 GMT 121 114 105 94.9 85.1 79.8 81.4 89.9 102 114 123 126

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0400 GMT 131 123 114 103 91.5 84.9 86.9 97.3 111 125 134 1360500 GMT 143 136 127 115 100 90.8 93.8 107 125 140 148 1490600 GMT 159 153 147 138 118 101 106 127 149 161 165 1640700 GMT 177 175 176 181 189 189 169 177 184 186 185 1820800 GMT 196 198 206 223 246 259 250 229 217 210 204 2000900 GMT 212 217 228 245 261 269 264 250 237 228 220 2151000 GMT 225 231 242 257 269 275 272 261 250 240 232 2271100 GMT 235 242 252 265 276 280 277 269 259 249 241 2361200 GMT 243 250 260 272 281 285 283 275 266 257 249 2431300 GMT n/a n/a 267 278 287 291 288 282 n/a n/a n/a n/a 1400 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1500 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1600 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1700 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1800 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 1900 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2000 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2100 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2200 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 2300 GMT n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Parameter Definition

Parameters for Tilted Solar Panels:

Monthly Averaged Radiation Incident On An Equator-Pointed Tilted Surface (kWh/m2/day)

Lat 26.5 Lon 75.5

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual Average

SSE HRZ 4.00 4.71 5.46 6.11 6.38 6.24 5.09 4.71 5.12 4.79 4.16 3.74 5.04

K 0.61 0.60 0.59 0.58 0.57 0.55 0.45 0.44 0.53 0.58 0.60 0.61 0.56 Diffuse 1.02 1.27 1.64 1.98 2.22 2.37 2.47 2.31 1.90 1.44 1.09 0.95 1.72 Direct 6.13 6.22 6.14 6.15 6.02 5.59 3.79 3.52 4.99 5.81 6.10 5.97 5.53 Tilt 0 3.89 4.67 5.40 5.99 6.35 6.21 5.08 4.68 5.05 4.75 4.03 3.66 4.98 Tilt 11 4.54 5.23 5.73 6.09 6.25 6.05 4.99 4.68 5.24 5.20 4.64 4.32 5.25 Tilt 26 5.20 5.74 5.93 5.97 5.86 5.57 4.67 4.51 5.28 5.58 5.25 5.03 5.38 Tilt 41 5.57 5.93 5.82 5.55 5.18 4.84 4.16 4.13 5.06 5.66 5.56 5.44 5.24

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Tilt 90 4.57 4.36 3.51 2.58 2.05 1.88 1.86 2.02 2.82 3.91 4.41 4.61 3.21 OPT 5.64 5.93 5.93 6.10 6.35 6.21 5.08 4.70 5.30 5.67 5.59 5.55 5.67 OPT ANG 51.0 42.0 28.0 13.0 0.00 0.00 0.00 6.00 21.0 37.0 48.0 53.0 24.8

NOTE:

Diffuse radiation, direct normal radiation and tilted surface radiation are not calculated when the clearness index (K) is below 0.3 or above 0.8.

Parameter Definition

Minimum Radiation Incident On An Equator-pointed Tilted Surface (kWh/m2/day)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

AverageSSE MIN 3.36 4.13 4.84 5.69 5.85 5.54 4.13 3.95 4.50 4.37 3.72 3.39 4.45

K 0.51 0.53 0.52 0.54 0.52 0.48 0.37 0.37 0.47 0.53 0.54 0.55 0.49 Diffuse 1.22 1.46 1.82 2.09 2.34 2.49 2.43 2.27 2.00 1.56 1.23 1.07 1.83 Direct 5.54 5.56 5.66 5.88 5.79 4.87 2.85 2.57 4.19 5.43 5.54 5.89 4.97 Tilt 0 3.27 4.10 4.78 5.57 5.82 5.51 4.12 3.93 4.43 4.33 3.61 3.31 4.40 Tilt 11 3.73 4.52 5.05 5.67 5.74 5.38 4.06 3.93 4.58 4.71 4.09 3.87 4.61 Tilt 26 4.19 4.90 5.18 5.55 5.39 5.00 3.84 3.78 4.60 5.01 4.57 4.44 4.70 Tilt 41 4.42 5.02 5.06 5.16 4.80 4.39 3.46 3.49 4.40 5.05 4.80 4.76 4.56 Tilt 90 3.55 3.65 3.08 2.47 2.01 1.86 1.70 1.81 2.50 3.48 3.77 3.98 2.82 OPT 4.45 5.02 5.18 5.67 5.82 5.51 4.12 3.94 4.62 5.07 4.82 4.83 4.92 OPT ANG 48.0 40.0 27.0 12.0 0.00 0.00 0.00 5.00 20.0 36.0 47.0 52.0 23.8

NOTE:

Diffuse radiation, direct normal radiation and tilted surface radiation are not calculated when the clearness index (K) is below 0.3 or above 0.8.

Parameter Definition

Maximum Radiation Incident On An Equator-pointed Tilted Surface (kWh/m2/day)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

AverageSSE MAX 4.72 5.21 6.25 6.76 7.41 6.94 6.72 5.65 5.51 5.30 4.53 4.38 5.78

K 0.72 0.67 0.67 0.64 0.66 0.61 0.60 0.53 0.57 0.64 0.66 0.71 0.64 Diffuse 0.66 1.06 1.32 1.74 1.85 2.17 2.16 2.19 1.80 1.24 0.92 0.64 1.48 Direct 7.20 6.80 7.14 6.94 7.33 6.42 6.19 4.94 5.44 6.49 6.54 7.08 6.54

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Tilt 0 4.60 5.17 6.18 6.62 7.38 6.91 6.69 5.62 5.43 5.26 4.39 4.28 5.71 Tilt 11 5.49 5.85 6.62 6.76 7.25 6.71 6.53 5.62 5.66 5.81 5.11 5.19 6.05 Tilt 26 6.41 6.49 6.90 6.63 6.74 6.14 6.04 5.40 5.72 6.29 5.83 6.15 6.23 Tilt 41 6.96 6.75 6.80 6.16 5.90 5.28 5.26 4.91 5.49 6.41 6.22 6.75 6.07 Tilt 90 5.81 5.00 4.06 2.74 2.06 1.87 1.94 2.22 3.02 4.45 4.98 5.83 3.66 OPT 7.09 6.76 6.91 6.76 7.38 6.91 6.69 5.64 5.73 6.42 6.27 6.94 6.63 OPT ANG 53.0 44.0 30.0 13.0 0.00 0.00 0.00 6.00 22.0 39.0 49.0 55.0 25.8

NOTE:

Diffuse radiation, direct normal radiation and tilted surface radiation are not calculated when the clearness index (K) is below 0.3 or above 0.8.

Parameter Definition

Parameters for Sizing Battery or other Energy-storage Systems:

Minimum Available Insolation Over A Consecutive-day Period (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Min/1 day 7.00 11.8 22.3 35.8 35.2 8.49 3.92 12.7 4.29 20.4 29.5 17.1Min/3 day 35.6 48.9 59.9 63.7 69.4 30.5 17.3 37.2 35.2 28.1 53.6 54.5Min/7 day 70.2 58.5 73.8 78.3 81.1 61.6 38.2 55.8 48.4 54.5 69.0 78.4Min/14 day 80.9 78.2 79.9 87.2 86.8 74.9 65.4 61.5 76.6 77.6 78.1 82.9Min/21 day 82.6 85.9 84.7 92.0 89.5 83.4 72.2 78.3 83.7 86.0 83.6 85.7Min/Month 84.0 87.6 88.6 93.1 91.6 88.7 81.1 83.8 87.8 91.2 89.4 90.6

Parameter Definition

Solar Radiation Deficits Below Expected Values Incident On A Horizontal Surface Over A Consecutive-day Period (kWh/m2)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

1 day 3.72 4.15 4.24 3.92 4.13 5.71 4.90 4.11 4.90 3.81 2.93 3.103 day 7.72 7.21 6.55 6.65 5.85 13.0 12.6 8.86 9.94 10.3 5.78 5.107 day 8.34 13.6 10.0 9.24 8.42 16.7 22.0 14.5 18.4 15.2 9.00 5.6414 day 10.6 14.3 15.3 10.8 11.7 21.9 24.6 25.3 16.7 15.0 12.7 8.9421 day 14.5 13.9 17.5 10.2 13.9 21.7 29.7 21.4 17.5 14.0 14.3 11.1Month 19.8 16.2 19.2 12.5 16.4 21.0 29.7 23.5 18.6 13.0 13.2 10.8

Parameter Definition

Equivalent Number Of NO-SUN Or BLACK Days (days)

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Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

1 day 0.93 0.88 0.77 0.64 0.64 0.91 0.96 0.87 0.95 0.79 0.70 0.823 day 1.93 1.53 1.20 1.08 0.91 2.08 2.47 1.88 1.94 2.15 1.38 1.367 day 2.08 2.90 1.83 1.51 1.31 2.68 4.32 3.09 3.60 3.18 2.16 1.5014 day 2.66 3.04 2.80 1.77 1.84 3.51 4.83 5.38 3.26 3.13 3.05 2.3921 day 3.64 2.95 3.20 1.67 2.18 3.48 5.83 4.54 3.42 2.92 3.43 2.99Month 4.96 3.44 3.52 2.06 2.57 3.36 5.83 5.00 3.63 2.71 3.17 2.90

Parameter Definition

Parameters for Sizing Surplus-product Storage Systems:

Available Surplus Insolation Over A Consecutive-day Period (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Max/1 day 136 140 138 133 129 139 160 157 139 138 137 127Max/3 day 133 129 131 123 126 134 144 140 130 130 123 124Max/7 day 130 126 130 117 123 128 142 133 127 127 119 121Max/14 day 127 122 122 116 120 124 139 128 116 122 114 119Max/21 day 123 116 119 113 119 121 135 128 112 117 112 117Max/Month 118 111 114 111 116 111 132 120 108 111 109 117

Parameter Definition

Cloud Information:

Monthly Averaged Daylight Cloud Amount (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 23.7 29.3 38.2 37.9 38.2 52.6 74.2 71.2 45.1 25.5 19.3 23.2 40.0

Parameter Definition

Monthly Averaged Cloud Amount At Indicated GMT Times (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average@00 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Average@03 19.8 25.0 32.1 30.5 30.6 44.5 68.7 63.6 34.1 18.3 17.2 20.8Average@06 24.1 29.2 37.0 35.8 36.5 50.7 73.5 70.6 42.1 24.4 20.5 23.9Average@09 27.1 33.8 43.3 45.2 46.1 59.9 78.0 77.0 55.9 33.8 20.4 25.0Average@12 n/a n/a 40.3 40.1 39.5 55.3 76.8 73.5 48.3 n/a n/a n/a

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Average@15 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Average@18 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a Average@21 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Parameter Definition

Monthly Averaged Frequency Of Clear Skies At Indicated GMT Times (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

< 10% @0 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a < 10% @3 63.3 55.3 50.7 50.7 51.1 33.7 12.6 15.5 48.0 68.4 70.4 61.2< 10% @6 57.9 52.0 46.3 45.0 45.0 29.7 9.82 10.5 38.3 62.0 64.3 58.5< 10% @9 53.6 48.8 38.4 34.7 31.3 18.7 7.04 5.28 18.1 47.5 63.6 58.5< 10% @12 n/a 47.0 41.2 39.8 37.6 23.4 7.33 7.77 24.3 n/a n/a n/a < 10% @15 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a < 10% @18 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a < 10% @21 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Monthly Averaged Frequency Of Broken-cloud Skies At Indicated GMT Times

(%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

10 - 70% @0 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a 10 - 70% @3 23.6 26.0 22.1 26.3 24.7 29.5 23.9 26.6 24.2 19.2 16.5 24.310 - 70% @6 24.9 24.7 21.4 26.8 25.0 25.4 21.1 24.4 26.5 19.6 20.3 23.910 - 70% @9 27.7 22.8 23.9 27.8 30.2 26.8 17.4 22.1 36.5 26.1 22.2 23.910 - 70% @12 n/a 29.1 24.4 26.3 32.1 28.7 19.0 24.1 34.6 n/a n/a n/a

10 - 70% @15 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

10 - 70% @18 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

10 - 70% @21 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Monthly Averaged Frequency Of Near-overcast Skies At Indicated GMT Times

(%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

>= 70% @0 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

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>= 70% @3 13.0 18.6 27.1 22.8 24.0 36.6 63.4 57.7 27.7 12.3 13.0 14.3>= 70% @6 17.1 23.1 32.2 28.1 29.9 44.8 69.0 64.9 35.1 18.3 15.3 17.6>= 70% @9 18.6 28.3 37.6 37.4 38.4 54.3 75.5 72.5 45.3 26.3 14.0 17.6>= 70% @12 n/a 23.8 34.3 33.7 30.2 47.7 73.6 68.0 41.0 n/a n/a n/a >= 70% @15 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a >= 70% @18 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a >= 70% @21 n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a n/a

Parameter Definition

Meteorology (Temperature):

Monthly Averaged Air Temperature At 10 m Above The Surface Of The Earth (°C)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 15.0 17.9 24.3 29.0 31.4 30.8 28.3 27.4 27.3 25.7 21.2 16.7 24.6

Minimum 9.56 12.1 18.3 23.0 26.3 27.1 25.5 24.7 23.8 20.3 15.6 11.3 19.8 Maximum 21.1 24.0 29.9 34.1 36.2 34.3 30.9 29.9 30.9 31.2 27.4 23.0 29.4

Parameter Definition

Average Daily Temperature Range (°C) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

22-year Average 11.5 11.8 11.5 11.1 9.91 * 7.19 5.38 5.21 7.15 10.8 11.7 11.6* Warmest month

Parameter Definition

Monthly Averaged Cooling Degree Days Above 18 °C Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Sum 22-year Average 7 36 191 318 411 382 318 289 280 241 107 20 2600

Parameter Definition

Monthly Averaged Heating Degree Days Below 18 °C Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Sum 22-year Average 89 33 0 0 0 0 0 0 0 0 1 45 168

Parameter Definition

Monthly Averaged Arctic Heating Degree Days Below 10 °C

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Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Sum 22-year Average 0 0 0 0 0 0 0 0 0 0 0 0 0

Parameter Definition

Monthly Averaged Arctic Heating Degree Days Below 0 °C Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Sum 22-year Average 0 0 0 0 0 0 0 0 0 0 0 0 0

Parameter Definition

Monthly Averaged Earth Skin Temperature (°C) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 16.8 20.8 29.1 34.0 35.4 33.8 30.0 28.8 29.1 27.9 23.0 18.0 27.3

Parameter Definition

Average Minimum, Maximum and Amplitude Of The Daily Mean Earth Temperature (°C)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

AmplitudeMinimum 8.15 10.8 17.0 21.5 24.9 26.3 25.1 24.3 23.0 18.9 13.9 9.60 Maximum 30.7 35.9 46.8 50.9 49.5 44.4 36.8 35.2 38.4 41.6 37.5 32.0 Amplitude 11.2 12.5 14.8 14.7 12.3 9.06 5.88 5.45 7.67 11.3 11.8 11.2 21.4

Parameter Definition

Monthly Averaged Frost Days (days) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Sum 22-year Average 0 0 0 0 0 0 0 0 0 0 0 0 0

Parameter Definition

Dew/Frost Point Temperature At 10 m (°C) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Daily Average 2.17 2.16 3.75 6.62 11.6 18.8 22.4 22.4 18.7 9.77 3.92 2.63Parameter Definition

Meteorology (Wind):

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Monthly Averaged Wind Speed At 50 m Above The Surface Of The Earth (m/s)Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average10-year Average 2.66 3.18 2.83 3.84 4.47 4.62 3.98 3.29 3.19 2.47 2.40 2.52 3.28

Minimum And Maximum Difference From Monthly Averaged Wind Speed At

50 m (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average Minimum -14 -19 -17 -8 -13 -9 -16 -14 -15 -18 -19 -18 -15 Maximum 11 14 11 8 14 15 33 17 15 26 17 13 16

It is recommended that users of these wind data review the SSE Methodology. The user may wish to correct for biases as well as local effects within the selected grid region.

All height measurements are from the soil, water, or ice/snow surface instead of "effective" surface, which is usually taken to be near the tops of vegetated canopies.

Parameter Definition Units Conversion Chart

Monthly Averaged Percent Of Time The Wind Speed At 50 m Above The Surface Of The Earth Is Within The Indicated Range (%)

Lat 26.5 Lon 75.5

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual Average

0 - 2 m/s 45 36 40 24 17 12 20 29 32 54 57 50 35

3 - 6 m/s 55 64 60 74 71 75 75 71 68 46 43 50 63

7 - 10 m/s 0 0 0 2 13 12 5 0 0 0 0 0 3

11 - 14 m/s 0 0 0 0 0 0 0 0 0 0 0 0 0

15 - 18 m/s 0 0 0 0 0 0 0 0 0 0 0 0 0

19 - 25 m/s 0 0 0 0 0 0 0 0 0 0 0 0 0

Parameter Definition

Monthly Averaged Wind Speed At 50 m Above The Surface Of The Earth For Indicated GMT Times (m/s)

Lat 26.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

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Lon 75.5 AverageAverage@0130 3.14 3.60 3.05 3.85 4.15 4.53 3.90 3.40 3.57 3.04 2.83 2.91 3.49 Average@0430 1.59 1.65 1.33 1.86 2.87 4.34 3.61 2.54 2.10 1.29 1.45 1.61 2.18 Average@0730 1.78 2.50 2.31 2.96 3.84 4.30 3.50 2.84 2.68 1.67 1.44 1.53 2.61 Average@1030 1.92 2.66 2.42 3.46 4.17 3.56 3.08 2.66 2.61 1.91 1.83 1.91 2.68 Average@1330 2.57 3.20 2.90 4.15 4.67 3.80 3.27 2.86 2.75 2.56 2.57 2.60 3.15 Average@1630 3.49 3.95 3.60 4.91 5.38 5.18 4.66 3.84 3.60 3.11 3.20 3.35 4.02 Average@1930 3.48 4.00 3.61 4.92 5.46 5.64 5.00 4.11 4.11 3.08 3.02 3.26 4.13 Average@2230 3.31 3.86 3.42 4.62 5.24 5.59 4.84 4.05 4.11 3.07 2.83 3.09 4.00

Parameter Definition Units Conversion Chart

Monthly Averaged Wind Direction At 50 m Above The Surface Of The Earth (degrees)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

10-year Average 37 32 26 13 347 319 300 293 287 288 303 327Parameter Definition

Monthly Averaged Wind Direction At 50 m Above The Surface Of The Earth

For Indicated GMT Times (degrees) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

Average@0130 58 66 72 55 244 236 225 226 225 149 101 78 Average@0430 68 84 95 89 258 256 248 254 253 154 113 90 Average@0730 64 54 29 286 272 268 260 282 286 239 67 74 Average@1030 11 311 289 285 273 265 263 303 313 355 14 24 Average@1330 2 332 311 297 278 239 222 259 331 33 23 21 Average@1630 16 5 353 326 279 212 201 202 171 72 41 33 Average@1930 30 28 21 353 272 214 208 213 197 102 58 46 Average@2230 44 47 44 19 261 226 219 223 219 131 81 62

Parameter Definition

Monthly Averaged Wind Speed At 10 m Above The Surface Of The Earth For Terrain Similar To Airports (m/s)

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average10-year Average 2.10 2.50 2.24 3.03 3.53 3.65 3.14 2.60 2.52 1.95 1.90 2.00 2.59

It is recommended that users of these All height measurements are from the

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wind data review the SSE Methodology. The user may wish to correct for biases as well as local effects within the selected grid region.

soil, water, or ice/snow surface instead of "effective" surface, which is usually taken to be near the tops of vegetated canopies.

Parameter Definition Units Conversion Chart

Difference Between The Average Wind Speed At 10 m Above The Surface Of The Earth And The Average Wind speed At 50 m Above The Surface Of The

Earth (%) Vegetation type "Airport": flat rough grass

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average 10-year Average -20 -20 -21 -21 -21 -20 -20 -21 -20 -20 -21 -20 -20

Parameter Definition

Monthly Averaged Wind Speed Adjusted For Height And Vegetation Type (m/s)

Height 100 meters Vegetation type "Airport": flat rough grass

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average10-year Average 2.95 3.52 3.14 4.26 4.95 5.12 4.41 3.65 3.53 2.74 2.66 2.80 3.64

Parameter Definition

Monthly Averaged Wind Speed At 50, 100, 150 and 300 m Above The Surface Of The Earth (m/s)

Vegetation type "Airport": flat rough grass Lat 26.5 Lon 75.5

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual Average

50m 2.66 3.18 2.83 3.84 4.47 4.62 3.98 3.29 3.19 2.47 2.40 2.52 3.28 100m 2.95 3.52 3.14 4.26 4.95 5.12 4.41 3.65 3.53 2.74 2.66 2.80 3.64 150m 3.13 3.74 3.33 4.52 5.27 5.44 4.69 3.87 3.76 2.91 2.82 2.98 3.87 300m 3.48 4.16 3.70 5.02 5.84 6.04 5.20 4.30 4.17 3.23 3.14 3.31 4.30

Parameter Definition

Monthly Averaged Wind Speed For Several Vegetation And Surface Types (m/s)Height 100 meters

Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average

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35-m broadleaf-evergreen trees (70% coverage)

3.68 4.40 3.91 5.31 6.19 6.39 5.51 4.55 4.41 3.42 3.32 3.50 4.55

20-m broadleaf-deciduous trees (75% coverage)

3.36 4.05 3.63 4.96 5.85 6.18 5.39 4.40 4.18 3.19 3.08 3.22 4.29

20-m broadleaf

and needleleaf trees (75% coverage)

3.78 4.40 3.81 5.10 5.85 6.01 5.17 4.37 4.29 3.39 3.34 3.57 4.42

17-m needleleaf-evergreen trees (75% coverage)

3.58 4.16 3.63 4.86 5.69 5.92 5.14 4.25 4.12 3.21 3.14 3.36 4.25

14-m needleleaf-deciduous trees (50% coverage)

3.53 4.16 3.65 4.89 5.69 5.84 5.03 4.28 4.26 3.35 3.25 3.40 4.28

Savanna:18-m broadleaf trees (30%)

& groundcover

3.53 4.22 3.76 5.10 5.93 6.13 5.28 4.37 4.23 3.28 3.18 3.36 4.36

0.6-m perennial

groundcover (100%)

3.20 3.83 3.41 4.63 5.38 5.57 4.79 3.96 3.84 2.97 2.89 3.05 3.96

0.5-m broadleaf

shrubs (variable %)

& groundcover

3.20 3.83 3.41 4.63 5.38 5.57 4.79 3.96 3.84 2.97 2.89 3.05 3.96

0.5-m broadleaf

shrubs (10%) with

bare soil

3.20 3.83 3.41 4.63 5.38 5.57 4.79 3.96 3.84 2.97 2.89 3.05 3.96

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Tundra: 0.6-m

trees/shrubs (variable %)

& groundcover

3.20 3.83 3.41 4.63 5.38 5.57 4.79 3.96 3.84 2.97 2.89 3.05 3.96

Rough bare soil 3.09 3.70 3.29 4.47 5.20 5.38 4.63 3.83 3.71 2.87 2.79 2.94 3.82

Crop: 20-m broadleaf-deciduous

trees (10%) & wheat

3.22 3.91 3.31 4.89 5.69 5.88 5.07 4.19 4.06 3.10 2.97 3.09 4.11

Rough glacial

snow/ice 3.39 3.99 3.48 4.66 5.42 5.60 4.83 3.99 3.92 3.10 3.03 3.22 4.05

Smooth sea ice 3.01 3.52 3.07 4.08 4.75 4.91 4.23 3.57 3.53 2.81 2.73 2.88 3.59

Open water 2.85 3.40 3.03 4.11 4.79 4.95 4.26 3.52 3.41 2.64 2.57 2.71 3.52 "Airport": flat rough

grass 2.95 3.52 3.14 4.26 4.95 5.12 4.41 3.65 3.53 2.74 2.66 2.80 3.64

Parameter Definition

Meteorology (Other):

Monthly Averaged Relative Humidity (%) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 45.6 39.0 29.5 28.9 36.3 55.2 73.1 76.2 64.1 41.8 35.1 42.3 47.3

Parameter Definition

Monthly Averaged Humidity Ratio At 10 m Above The Surface Of The Earth (%) at 26.5 on .5

Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec

2-year verage 0.005044 0.005174 0.005774 0.007245 0.010272 0.015553 0.018759 0.018675 0.015182 0.008836 0.005687 0.00519

Parameter Definition

Monthly Averaged Atmospheric Pressure (kPa) Lat 26.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

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Lon 75.5 Average22-year Average 97.6 97.4 97.1 96.7 96.4 96.1 96.1 96.3 96.7 97.1 97.5 97.7 96.9

Parameter Definition

Monthly Averaged Total Column Precipitable Water (cm) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 1.27 1.32 1.60 1.96 2.61 4.11 5.50 5.46 3.92 2.10 1.38 1.28 2.71

Parameter Definition

Monthly Averaged Precipitation (mm/day) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 0.26 0.42 0.20 0.24 0.53 2.27 6.43 6.37 2.69 0.66 0.06 0.17 1.70

Parameter Definition

Supporting Information:

Monthly Averaged Top-of-atmosphere Insolation (kWh/m2/day) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 6.52 7.74 9.21 10.4 11.0 11.3 11.1 10.5 9.57 8.18 6.82 6.12 9.06

Parameter Definition

Monthly Averaged Surface Albedo (0 to 1.0) Lat 26.5 Lon 75.5 Jan Feb Mar Apr May Jun Jul Aug Sep Oct Nov Dec Annual

Average22-year Average 0.19 0.18 0.18 0.20 0.22 0.24 0.21 0.18 0.16 0.16 0.17 0.18 0.18

Parameter Definition

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Back to SSE Data Set Home

Page

Responsible NASA Official: John M. Kusterer Site Administration/Help: NASA Langley ASDC User Services ([email protected]) [Privacy Policy and Important Notices] Document generated on Tue Jan 4 02:04:54 EST 2011

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Annexure-5

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Annexure- 6

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Annexure- 7

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Annexure- 8

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Annexure- 9

RAJASTHAN ELECTRICITY REGULATORY COMMISSION, JAIPUR

Suo-Motu In the matter of determination of generic tariff for sale of electricity, in the State to the Distribution Licensees, from Solar Power Plants, including roof top SPV systems and small solar power plants.

Coram :

Shri D.C. Samant, Chairman Shri K. L. Vyas, Member [T] Shri S.K. Mittal, Member [F]

Date of hearing: 5. 5.2010 Date of Order: 25.5.2010

ORDER

BACKGROUND

1. The Ministry of New and Renewable Energy (MNRE), Government of India, issued Guidelines for Generation Based Incentive (GBI) for grid interactive solar power generation projects vide Circulars Nos. 32/61/2007-08/PVSE in January,2008 and No.8/1/2007-08/ST in March, 2008 .

2. The Guidelines envisaged that the State Electricity Regulatory Commissions (SERCs) shall determine applicable tariff for procurement of power by the distribution licensees within the State from solar power projects to enable the project developers to avail incentive.

3. The Generation Based Incentive, notified by MNRE in January, 2008 for Solar Power generation for the Demonstration Projects with a total target of 50 MW is available for a period of 10 years up to 10 MW per State and a maximum of up to 5 MW for each Project, provided the projects are commissioned before the cut-off date. The projects that have availed MNRE’s GBI are thus limited in number and about 8MW has been added under this scheme as of March 2010.

4. The Commission determined the normative tariff for solar power projects to be commissioned under GBI scheme of MNRE as per RERC Tariff Order dated 2nd April 2008. The Commission has adopted the tariff for solar power projects as the sum of the highest tariff being paid by the utilities for wind power and the maximum permissible GBI from MNRE. The total tariff allowed by the Commission vide order dated 2nd April 2008, inclusive of the generation incentive on solar power payable by GoI, and amended vide order dated 23.12.2009, is as under with the stipulation that all the conditions of MNRE’s guidelines shall apply:

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Table - 1 Sl. Particulars SPV Technology CSP Technology 1. 2. 3. 4.

1. Solar power plants eligible for full GBI as per GoI Scheme

Rs. 15.78/kWh Rs.13.78/kWh

2. Solar power plants eligible for reduced GBI as per GoI Scheme

Rs.15.18/kWh Rs.13.18/kWh

5. The above tariff for solar power project was for ten years only, but the PPA

could be executed for 20 years or life of the plant. The tariff after 10 years was to be determined separately for the next tariff Control Period as per the prevailing Regulations at that time. In pursuance to this, two projects of capacity of 5 MW each of (i) M/s. Reliance Industries Ltd. and; (ii) M/s. Par Solar have been approved by MNRE and they have also executed PPAs with Discoms.

6. In accordance with the provisions of Electricity Act 2003 and Tariff Policy notified by Govt. of India, the Commission under its RERC (Terms and Conditions for Determination of Tariff) Regulations, 2009 had incorporated the enabling provisions for determination of tariff of solar power projects.

7. As per information of Rajasthan Renewable Energy Corporation Ltd (RREC), the State Nodal Agency, proposals of 11 project developers for 66 MW in total have been approved by the State Level Empowered Committee up to 6.11.2009.

8. Project specific tariff petitions, as under, were received from 3 project developers for concentrated solar power (solar thermal) projects and from 8 project developers for solar photovoltaic power projects along with the DPRs wherein the state Discoms were the respondents besides RVPN,and RREC as necessary parties: Petitioners for Concentrated Solar Power Plants (Capacity 10 MW each) 1. M/s. Acme Tele Power Limited, Gurgaon Petition No.RERC/187/09 2. M/s Entegra Limited, New Delhi Petition No.RERC/193/09 3. M/s. Shri Rangam Brokers & Holdings Ltd. Petition No.RERC/204/09

Petitioners for solar Photo Voltaic power Plants (Capacity 5 MW each except Sl.No.8 of 1 MW) 1. M/s.Videocon Industries Ltd., Mumbai Petition No.RERC/188/09 2. M/s Moser Baer Photo Voltaic Limited, New

Delhi Petition No.RERC/189/09

3. M/s.Astonfield Solar Raj.Pvt. Ltd., Mumbai Petition No.RERC/191/09 4. M/s Entegra Limited, New Delhi Petition No.RERC/192/09 5. M/s.OPG Energy Pvt. Ltd., Chennai Petition No.RERC/194/09 6. M/s.Refex Refrigerants Ltd. Chennai Petition No.RERC/195/09 7. M/s.Swiss Park Vanijya Pvt. Ltd.,Kolkata Petition No.RERC/196/09 8. M/s.AES Solar Energy Pvt.Ltd., Gurgaon Petition No.RERC/197/09

9. Public hearings on the petitions were held on 23rd, 24th and 30th of

September and 14th October, 2009, in which persons mentioned in

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Annexure-I participated. During the hearing, petitioners became aware that project specific tariff and norms as well as parameters going into tariff determination would be subject to annual review, and would apply only for the current MYT control period i.e. F.Y. 09-14 only. They also understood that as per the existing regulations of the Commission, long term tariff cannot be determined for any specific project. Most of the petitioners requested for long term tariff, as is applicable in case of generic tariff determined by the Commission in respect of other RE sources i.e. wind and bio-mass. Petitioners expressed their concern regarding financial tie-up and getting loan for their projects in case long term tariff was not declared. It was pointed out that since solar projects in the country are at a nascent stage, financial institutions would require comfort of long term tariff otherwise they would be quite wary in committing funds for solar projects.

10. In consideration of the position narrated in preceding paragraphs six petitioners viz. (i) M/s Entegra Limited, (ii) M/s. Videocon Industries Ltd., (iii) M/s. Astonfield Solar (Raj.) Pvt. Ltd., (iv) M/s. OPG Energy Pvt. Ltd., (v) M/s. Swiss Park Vanijya Pvt. Ltd., and (vi) M/s. AES Solar Energy Pvt. Ltd., presented revised petitions with the request that generic tariff be determined by the Commission instead of project specific tariff sought by them earlier.

11. Government of India has recently announced Jawaharlal Nehru National Solar Mission (JNNSM) for giving big thrust to solar power generation in the country in tune with the objective of enhancing generation and use of clean energy visualised in National Action Plan on Climate Change (NAPCC). The Solar Mission aims at reaching a level of 20,000 MW of solar power capacity by the end of 13th Five Year Plan (in 2022) and will be implemented in 3 stages. It also envisages that due to rapid scale-up in capacity addition along with technological development the solar power prices would come down and would attain parity with grid power by end of the Mission period. In Phase-1, the Govt. of India has set the goal of grid connected solar power capacity of 1000 MW and 100 MW of the roof top grid connected solar devices leading to in total 1100 MW of grid connected solar power. This level is to be reached by the end of Phase-1 i.e. by financial year 2012-13. The Mission also emphasises on R&D and HRD development along with enhancing indigenous content and improving Indian skills to make the Mission sustainable. The R&D programme would seek to address India specific challenges in solar energy generation. Mission also envisages sale of power by NTPC Vidyut Vyapar Nigam (NVVN) by bundling solar power with equal capacity of conventional power thus enabling the sale of the bundled power at Rs 5.50 per kWh to the state distribution utilities.

12. As per the State Government letter dated 3.1.2010 addressed to MNRE, a copy of which was supplied to the Commission, it is observed that the developers who filed petitions for tariff determination are reported to have subsequently consented for migration of their projects to JNNSM for which the tariff determined by CERC would be applicable. However, the Commission has neither received any request from the solar project developers for withdrawal of their Petitions nor has any communication been received from the State’s distribution licensees.

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13. The National Solar Mission also has a provision of providing generation based incentive for operators of roof-top Solar PV devices. However, operators of such roof-top devices would be entitled to get payment for solar energy at the rate determined by the State Electricity Regulatory Commission as tariff determination for such a system falls within the purview of the State Regulatory Commission, as distinct from purchase by NVVN from solar power producers wherein tariff determined by SERC would not be applicable.

14. Considering the above discussed position and the fact that long term levellised feed-in-tariff (for 20 years) has already been determined by the Commission for wind energy; the Commission has came to the conclusion that a similar treatment be given to solar projects also, more-so when CERC has determined the generic tariff as levellised for 25 years in respect of solar projects along with norms and parameters.

15. The Commission has also given due consideration to the following factual/regulatory position, in coming to the conclusion that generic tariff for solar projects needs to be determined:

(1) The Section 61(h) of the Electricity Act (EA), 2003 stipulates that while determining tariff, the Commission shall be guided by the aspect of promotion of co-generation and generation from renewable sources of energy.

(2) The Tariff Policy notified by the Ministry of Power, Government of India, stipulates that the Appropriate Commission has to determine Preferential Tariff for procurement of Renewable Energy (RE) by Distribution Licensees under Renewable Energy Purchase Obligation (RPO) regime as envisaged under Section 86(1) (e) of EA 2003.

(3) Regulation 83 (3) of the RERC Tariff Regulations, 2009 provides that the Commission shall specify the normative parameters and determine the generic tariff as may be necessary through a separate order for the projects not covered under the then prevailing GBI Scheme of Govt. of India for which required inputs shall be taken from various manufacturers recommendation, expert opinion while exercising its prudent check.

(4) The RERC Tariff Regulations 2009, Regulation 83(5) states that the Solar power project developer or investor would have the option to adopt either ‘Generic Tariff’ or ‘Project Specific Tariff’ for determination of applicable tariff for the solar power project.

(5) Submissions made by various solar project developers before the Commission indicate that multiple technological options are available for solar thermal power like solar dish/engine, parabolic trough, solar tower etc. Similarly, there are many options of technology in SPV plants like thin film, crystalline, concentrated PV, etc. Thus, performance parameters and cost structure would differ from one solar power project to another. No standard parameters are available for evaluating capital cost, O&M expenses, material to be used for panel, structures etc., in the Indian context. Data available is with reference to plants established in USA, Spain, etc. In the light of this, exercise of prudence check and evaluation of likely cost for each individual projects would be extremely difficult – an exercise required to be undertaken by the Commission for project specific tariff. This would also require significant expert input and consultation process to understand the technical complexities of the project scheme

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and the technology proposed to be deployed by each project developer.

(6) Further, typical project size is expected to be small (around 1MW to 10 MW) and numbers of projects are expected to be plenty with diverse technological options. Determination of tariff for each solar generation project separately, shall entail significant regulatory cost and time; whereas promotional aspects necessitate that capacity is brought into the system expeditiously.

(7) CERC has also notified regulations for RE Tariff comprising generic norms for Solar power projects recently and Tariff Order based on these norms have been issued on 3.12.2009 (for control period 2009-10) and Gujarat Electricity Regulatory Commission has also announced generic tariff for solar projects vide its order dated 29.1.2010. CERC has also issued final tariff order dtd. 26th April, 2010 for the control period 2010-11 with tariff applicable for projects implemented by March 2012 for SPV and by March, 2013 for CSP.

Petitions and Objections/Comments thereon Concentrated Solar Power (CSP) 16. The capacity, location and proposed technology in respect of the three

petitions of CSP projects are as under: Table-2

S No. Name of the petitioner Technology Proposed

Capacity of the plant & location

1. 2. 3. 4. 1 M/s Acme Tele Power

Limited Solar Tower 10 MW/Bikaner

2 M/s. Entegra Limited Parabolic Trough 10 MW/ Phalodi Tehsil, Jodhpur

3 M/s. Shri Rangam Brokers & Holdings Ltd.

Parabolic dish-sterling engine

10 MW/ Bap Tehsil, Jodhpur

17. As could be seen from the earlier para, the CSP petitions envisage the following technology options:

a. Solar Tower b. Parabolic Trough c. Solar Dish/Engine

18. Public Notices about these petitions were issued and presentations for the public were held on dates given below.

Table-3 S No. Name of the petitioner Date of Public

Notice Date of Presentation

1. 2. 3. 4. 1 M/s Acme Tele Power Limited 18.5.09 25.05.09

2 M/s. Entegra Limited 19.5.09 25.05.09 3 M/s. Shri Rangam Brokers &

Holdings Ltd. 21.08.09 3.11.09

19. Objections and suggestions were received from the following stakeholders and individuals in respect of the said petitions :

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(1) Sh. Shanti Prasad, Ex -Chairman, RERC (2) Rudraksh Energy (3) Sh.G.L.Somani,Ex CE,RVUN (4) Sh. P.N.Mandola (5) Discoms :

(a) Jaipur Vidyut Vitran Nigam Ltd. (b) Ajmer Vidyut Vitran Nigam Ltd. (c) Jodhpur Vidyut Vitran Nigam Ltd.

Petitions and Objections/Comments thereon Solar Photo Voltaic (SPV) Power Plants 20. The capacity, location and proposed technology in respect of the eight

petitions of SPV projects are as under: Table-4

S No. Name of the petitioner Technology Proposed

Capacity of the plant & location

1. 2. 3. 4. 1 M/s Moser Baer Photo Voltaic

Limited, New Delhi Thin film solar technology (a.si)

5 MW/Osiyan Tehsil, Jodhpur

2 M/s. Astonfield Solar Raj.Pvt. Ltd., Mumbai

Thin film solar technology (Cd.Te)

5 MW/Osiyan Tehsil, Jodhpur

3 M/s.OPG Energy Pvt. Ltd., Chennai

Thin film solar technology (a.si)

5 MW/ Khinvsar Tehsil, Nagaur

4 M/s.Swiss Park Vanijya Pvt. Ltd.,Kolkata

Thin film solar technology (a.si)

5 MW/Osiyan Tehsil, Jodhpur

5 M/s.AES Solar Energy Pvt.Ltd., Gurgaon

Thin film solar technology (a.si)

5 MW/Osiyan Tehsil, Jodhpur

6 M/s.Videocon Industries Ltd., Mumbai

Crystalline Solar Technology (C.Si)

5 MW/Osiyan Tehsil, Jodhpur

7 M/s.Refex Refrigerants Ltd. Chennai

Crystalline Solar Technology (C.Si)

5 MW/ Pachpadara Tehsil, Jodhpur

8 M/s Entegra Limited, New Delhi

CSPV 1 MW/ Phalodi Tehsil, Jodhpur

21. Based on technology, the solar photovoltaic power projects could be categorized in the following three categories: a. Thin film solar technology (including amorphous silicon (a-Si) and

Cadmium Telluride (CdTe) solar technologies) b. Crystalline Silicon technology (C-Si) c. Concentrated Solar PV (CSPV or CPV)technology

22. Public Notices about these petitions were issued and presentations for the public were held as per the details below :

Table-5 S No. Name of the petitioner Date of Public

Notice Date of

Presentation 1. 2. 3. 4. 1 M/s Moser Baer Photo Voltaic Limited, 21.5.09 26.5.09

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S No. Name of the petitioner Date of Public Notice

Date of Presentation

1. 2. 3. 4. New Delhi

2 M/s.Astonfield Solar Raj.Pvt. Ltd., Mumbai

23.7.09 29.7.09

3 M/s.OPG Energy Pvt. Ltd., Chennai 28.6.09 2.7.09 4 M/s.Swiss Park Vanijya Pvt. Ltd.,Kolkata 29.6.09 2.7.09 5 M/s.AES Solar Energy Pvt.Ltd., Gurgaon 7.8.09 13.8.09 6 M/s.Videocon Industries Ltd., Mumbai 2.7.09 9.7.09 7 M/s.Refex Refrigerants Ltd. Chennai 21.5.09 29.5.09 8 M/s Entegra Limited, New Delhi 31.8.09 7.9.09

23. Objections and suggestions were received from the following stakeholders

and individuals in respect of the said petitions : (I) Sh. D. S. Agarwal, Executive Director (RSEB)-Retired (II) Sh.Shanti Prasad,EX Chairman,RERC (III) Sh.G.L.Somani,Ex CE,RVUN (IV) Sh.P.N.Mandola (V) Discoms :

(a) Jaipur Vidyut Vitran Nigam Ltd. (b) Ajmer Vidyut Vitran Nigam Ltd. (c) Jodhpur Vidyut Vitran Nigam Ltd.

24. As the Commission has agreed to determine generic tariff as distinct from project specific tariff; specific issues raised by various stakeholders/individuals regarding each petition need not be discussed in this order. The suggestions/comments have been given due considerations while working out norms and various parameters of generic tariff and have been discussed, wherever required, while dealing with norms and parameters of generic tariff. However, Commission wishes to enclose various suggestions and comments with this order for reference. Accordingly, the main points of suggestions/comments from various stakeholders/individuals on the petitions are placed at Annexure-II for CSP petitions and Annexure-III for SPV petitions.

DRAFT TARIFF ORDER 25. Based on the various inputs as stated above, the Commission prepared a

draft order for generic tariff for solar thermal, solar photo voltaic and rooftop power plants and made public on 10.03.2010.A copy of the draft order was sent to all petitioners, stakeholders, State Advisory Committee members and a public notice was also published in the following news papers inviting comments thereon latest by 31.03.2010.

(1) The Times of India published on 12.03.2010 (2) Dainik Bhaskar published on 11.03.2010 (3) Rashdradoot published on 11.03.2010

Objections/Comments on draft tariff order 26. The Commission received objections / comments from petitioners, public

stakeholders and the respondents. A brief of all these comments is given in

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Annexure II A & III A for CSP and for SPV respectively. The comments have been consolidated for each parameter in the succeeding paras.

SNo Parameter SPV CSP 1 PPA period Adopt 25 year period for PPA Adopt 25 years period

for PPA

2 Tariff control period

Make the tariff valid for projects implemented before 31st March 2012

Tariff validity to be extended to 31.03.2013

3 O&M expenses

O&M expenses to be at Rs 9.51 lakhs/MW for 2010-11 considering escalation at 5.72% on 2009-10 rate of Rs 9lacs per MW per year

O&M expenses should be much higher and at least escalated by 5.72% on 2009-10 rate

4 Deration Suggested deration ranging from 0.6% to 1% per year. Industry experience is 0.4 to 0.5% per year for c-Si, 0.6% per year for CdTe and 0.8% to 1% per year for a-Si modules.

To consider deration in CSP plants.

5 CUF Various commentators have suggested CUF from 17% (AES Solar and BMD and Mr Yogesh Gupta); 19% (Torrent Power); JVVNL (25% for CSP and 22% for PV); Mr GL Sharma (22.7%)

To consider lowest value of DNI and conversion efficiency of 14% to work out CUF. Some suggested it should be 23% and 25%.

6 Separate Generic Tariffs for SPV & CSP technology

Separate generic tariff for c-Si and a-Si technologies as the CUF is 19.63% and 21.23% for c-Si and Thin film respectively. Some suggested separate generic tariffs for c-Si and a-Si technologies as there was a significant difference in the capital costs (instead of adopting an average benchmark capital cost)

Project with sterling engine technology to be considered at par with SPV for the purpose of tariff.

7 Depreciation To be 7% to cover debt service obligation in 10 years term loan

To be 7% to cover debt service obligation in 10 years term loan

8 Scope of Roof Top

To include all small grid connected solar systems and not just those on buildings listed in the order; rural farms and plantations in addition to urban buildings; agricultural pump sets

Not applicable

9 Auxiliary consumption

Be increased to 0.50%.Fix up norm for auxiliary consumption but advice the Discoms to have a ban on giving connections to project developers to avoid any malpractices

Be increased to 6-7%.Some have suggested to be 10%

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10 Interest rate for term loan & working capital

Interest Rate to be 12.75 % for calculation as per CERC, SBI PLR + 100 basis points instead of just SBI PLR for working capital. For long term loan consider interest rate of SBI PLR + 150 basis points instead of PLR + 100 basis points adopted now

SBI PLR +100 basis points for working capital.SBI PLR+150 basis point for long term loan

11 Cap Ex Risk in solar power plant may be accounted by considering increase of 5%-10% in capex for initial 2-3 years. Benchmark Cost to be revised as per CERC to Rs 16.9 Cr per MW. AES Solar suggested Rs 17 Cr/MW

Comparison of capital cost of standalone solar thermal with integrated solar combined cycle thermal project of Mathania is not equitable. Bench mark cost be raised to Rs 16.40 or Rs 15.30 Crore/MW as per CERC.

12 AD benefit Make the tariff net of AD benefit regardless of whether the developer avails the AD benefit or not

Make the tariff net of AD benefit regardless of whether the developer avails the AD benefit or not

13 Concessional customs duty

Concessions can be availed at 5% on imported items as per GoI order no 30/2010 dt 27/02/10. Such benefits be considered while fixing up tariff

Concessions can be availed at 5% on imported items as per GoI order no 30/2010 dt 27/02/10. Such benefits be considered while fixing up tariff

14 Sharing of CDM benefits

CDM benefits should not be passed on to the Discoms

CDM benefits should not be passed on to the Discoms

15 Power evacuation

RVPN should provide infrastructure required for evacuation of power from pooling station to nearest grid substation. OR Commission may determine transmission tariff for the same on case-to-case basis.

RVPN should provide infrastructure required for evacuation of power from pooling station to nearest grid substation. OR Commission may determine transmission tariff for the same on case-to-case basis.

27. The public hearing in the matter was held on 5th May,2010 wherein the persons participated is as per list at Annexure-I and submitted their view point.

NORMS AND FINANCIAL PARAMETERS FOR GENERIC TARIFF (as in draft order) 28. The Commission considers it appropriate to retain the financial norms, as

stipulated in part –III of RERC Tariff Regulations, 2009 i.e. debt : equity ratio, RoE, interest on loan, O&M escalation etc, as has been used for the tariff determination of other RE source like wind/bio-mass as under :

Table-6 S.No. Parameter Ref. of Tariff

Regulation Norms

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S.No. Parameter Ref. of Tariff Regulation

Norms

1. 2. 3. 4. 1. Debt : Equity 17 70 : 30 2. Return on equity 21 16% 3. Depreciation 23 5.28% (for 12 years then spread

over useful life) 4. Useful life 2(71) 25 years 5. O&M Expenses escalation 25 5.72% of O&M expenses p.a. 6. Sharing of CDM benefit 42 25% to Discom (not accounted

for in tariff) 7. Interest on working capital 28 PLR of SBI as on 31st Jan. of 2010

29. The Commission also considers it appropriate to adopt some specific norms as applied to generic tariff determination of wind power/bio-mass for solar power plant with suitable change in relevant date of SBI PLR and deration in capacity: (1) Working capital requirement shall comprise of:

(a) Operation and Maintenance Expenses for 1 month (b) Receivables equivalent to 1.5 months of electricity charges

calculated on the target CUF. (c) Maintenance Spares @ 15% of Operation and Maintenance

expenses (2) Interest on long term loan: 100 basis points above SBI PLR as on 31st

Jan. of 2010. (3) Deration in capacity – @ 0.25% per annum after 4 years of operation

(see note at the bottom of the para) (4) Interface metering for billing purpose shall be at power plant as per

CEA regulations. However, if the metering is agreed to be at the licensee’s premises on 33 kV then the tariff shall be calculated after considering 1% of energy sent out towards losses and wheeling.

(5) Levellised tariff shall be worked out for 20 years though PPA would be for the life of the project i.e. 25 years. Note: In the initial 3-4 years of operation there is no appreciable

deration to be accounted for as the same is more or less covered in the manufacturer’s guaranteed output of the Solar modules. Therefore, deration in output of 0.25% per annum after 4 years has been adopted in tariff determination.

30. The above norms mentioned in para 28 and 29 would be applicable for the MYT control period i.e. up to F.Y. 13-14 for both CSP as well as SPV projects subject to updation at subsequent tariff determination of base year for PLR of SBI.

Stakeholders Comments/Suggestions

31. Shri Shanti Prasad submitted that the Commission may consider financial principles specified by the CERC in respect of solar power projects so as to bring uniformity to the extent considered feasible and to promote development of ‘intra-state solar power projects’ in the state.

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Commission’s Ruling

32. The Commission has to follow the financial principles and the norms as specified for determination of tariff under the RERC Tariff Regulations, 2009 and the reasons for the consideration of norms has also been elaborated in the Statement of Objects and Reasons in the matter of RERC Tariff Regulations, 2009. The same has been considered while determining the tariff for solar power projects.

Debt Equity Ratio Stakeholders Comments/Suggestions

33. Acciona Energy Ltd has submitted that it is difficult to get a project financed at a debt equity ratio of 70:30 through the non-recourse financing route in view of risk perception by lenders for RE technologies being at nascent stage of development and hence, requested the Commission to consider lower debt: equity ratio.

Commission’s Ruling

34. The Regulation 17 of the RERC Tariff Regulations, 2009 provides for the consideration of debt equity ratio and the same has been considered by the Commission while determining the tariff for Solar Power Projects.

The Commission would further like to clarify that the Tariff Policy (TP) notified by the Government of India stipulates the debt equity ratio of 70:30 for financing all future projects. Clause 5.3 (b) of the Tariff Policy is reproduced below:

“b) Equity Norms

For financing of future capital cost of projects, a Debt: Equity ratio of 70:30 should be adopted. Promoters would be free to have higher quantum of equity investments. The equity in excess of this norm should be treated as loans advanced at the weighted average rate of interest and for a weighted average tenor of the long term debt component of the project after ascertaining the reasonableness of the interest rates and taking into account the effect of debt restructuring done, if any. In case of equity below the normative level, the actual equity would be used for determination of Return on Equity in tariff computations.”

The CERC RE Tariff Regulations also provide for normative debt-equity ratio in the proportion of 70:30. It has also been observed that Regulatory Commissions across different States have been following the same

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principle laid down in the Tariff Policy. In view of this, there is no need for any modification to this provision.

Depreciation Stakeholders Comments/Suggestions

35. The Stakeholders have submitted that a large number of projects under JNNSM will approach lenders, where CERC provides for 10 year repayment period, achieving financial closure for projects under RERC tariff will be difficult. Accordingly, the depreciation rate be considered as 7%, with the debt repayment period of 10 years.

Commission’s Ruling

36. The provision of depreciation rate has been made in accordance of Regulation 23 of RERC Tariff Regulations, 2009. The Appendix-I of the RERC Tariff Regulations, 2009 provides for the depreciation schedule and the same has been considered by the Commission while determining the tariff for Solar Power Projects. Further, it is clarified that the tariff rate and tariff structure has been so designed that debt service coverage ratio in a year is almost unity in the first year of operation which increases over the years and would enable meeting the debt service obligations.Also, the depreciation rate is same as being applied for other RE resources i.e. Wind & Bio-mass. Thus, the Commission observes that no revision in depreciation rate on this count is necessary.

Interest on working capital Stakeholders Comments/Suggestions

37. Torrent Power Ltd. has submitted that the interest on Working Capital may be considered in line with the norms specified by CERC i.e. SBI PLR + 100 basis points.

Commission’s Ruling

38. With regard to interest on Working Capital, the Commission has been guided by the Regulation 28 of the RERC Tariff Regulations, 2009. In view of this no modification is required.

39. The Commission considers it appropriate to adopt the same norm as applied to generic tariff determination of wind power/bio-mass for solar power plant with suitable change in relevant date of SBI PLR as far as interest on working capital is concerned.

Working Capital Norms Stakeholders Comments/Suggestions

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40. The Stakeholders have submitted that the receivables of two (2) months may be considered for computing the working capital requirement for Solar Projects.

Shri Shanti Prasad submitted that the maintenance spares @15% of O&M expenses has been considered for one year in tariff calculations. It will be appropriate to add words “for one year” after “@15% on O&M Expenses” to make it explicitly clear.

Shri GL Sharma has submitted that the receivables may be considered for 1 month, the O&M Expenses may be considered only for half month and maintenance spares should be 15% of O&M cost calculated on monthly basis, while determining the working cost requirement.

JVVNL has submitted that the maintenance spare may be considered as 5% of O&M Expense.

Commission’s Ruling

41. The Commission observes that the RERC Tariff Regulations, 2009 do not specify particular norms for working capital requirement in terms of receivable, O&M expense and maintenance spares etc. for solar projects. In the absence of specified norms under RERC Tariff Regulations, 2009, the working capital requirement for the solar power projects can be taken as similar to that for Wind power projects. The CERC has also specified similar working capital norms applicable to Wind as well as Solar Power Projects by specifying the quantum of O&M expenses to be considered for maintenance spares, which is in line with 15% of O&M expenses suggested by stakeholders. The Commission has, therefore, considered the working capital norms for solar projects while determining the tariff for solar power projects as under:

(a) Operation and Maintenance Expenses for 1 month (b) Receivables equivalent to 1.5 months of electricity charges

calculated on the target CUF (c) Maintenance Spares @ 15% of annual O&M expenses.

Rate of Interest on Long Term Loan Stakeholders Comments/Suggestions

42. Acciona Energy Ltd has submitted that the interest on long term loan should be considered as SBI PLR + 200 basis points.

Torrent Power Ltd has submitted that the Interest rate on long term loan should be considered as SBI PLR + 150 basis points in line with the norms specified by the CERC.

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Green Infra Ltd. has submitted that large number of projects under JNNSM will approach lenders, where CERC provides for interest rate of SBI prevalent during the previous year + 150 basis points. Accordingly, the rate of interest on long term loan should be considered as SBI PLR + 150 basis points.

Commission’s Ruling

43. The Commission under regulation 83 of the RERC Tariff Regulations, 2009 has specified the norms for generic tariff determination of new renewable energy generating stations getting commissioned during the Control Period. Further, the Commission has observed that high risk is associated with the renewable energy generation projects and accordingly has specified the normative rate of interest on long term loan as SBI PLR plus 100 basis points. The same has been considered while determining the draft tariff for solar power projects i.e. Interest on long term loan as 100 basis points above SBI PLR as on 31st Jan. of 2010 and the same is being retained in the final order.

Sharing of CDM Benefits Stakeholders Comments/Suggestions

44. The Stakeholders have submitted that the sharing of CDM benefits should not be allowed between the developer and the distribution company since entire risk towards getting the project registered under CDM activity is borne by the developer of the project.

Commission’s Ruling

45. As regards sharing of CDM benefits, the Commission has been guided by the provisions under Regulations 42 as specified in the RERC Tariff Regulations, 2009. The premise for specifying sharing of CDM benefits have been elaborated under para. 49 of the Statement of Reasons for RERC tariff regulations, 2009. The provision of sharing so specified is also in line with the provisions of Tariff Policy. In view of this no modification is required.

NORMS AND FINANCIAL PARAMETERS FOR GENERIC TARIFF (FINAL)

46. In the light of discussions in the preceding paras, the Commission considers it appropriate to retain the financial norms, as stipulated in part –III of RERC

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Tariff Regulations, 2009 i.e. debt: equity ratio, RoE, interest on loan, O&M escalation etc, as has been used for the tariff determination of other RE source like wind/bio-mass and adopted in draft tariff order of solar projects. No change, therefore, is required to be made in financial parameters proposed in the draft order as at para 28 above.

OTHER COMMON POINTS EMERGING FROM THE DRAFT ORDER

Tariff period and tenure of Power Purchase Agreement (PPA)

Stakeholders Comments/Suggestions

47. The Stakeholders have submitted that the Commission has proposed levellised tariff for 20 years but PPA term has been proposed as 25 years. Many stakeholders have suggested that the Commission may consider uniform tariff period and PPA tenure of 25 years.

Commission’s Ruling

48. The Commission would like to clarify that the draft Solar tariff Order specified the levellised tariff of 20 years for solar power projects in line with the principles adopted while specifying the tariff for other renewable energy sources. Though the lenders concern is fully addressed as the PPA term is longer than loan repayment term, however, the Commission observes that many stakeholders have sought to determine the tariff for solar projects over its useful life of 25 years and the draft MNRE guidelines in respect of small solar & roof top systems also envisage 25 years levellised tariff. Many stakeholders have highlighted the need to maintain uniformity in tariff period and PPA tenure so that projects can qualify for incentive under JNNSM.Accordingly, the Commission is of the view that clarity on the exact power purchase price for the entire useful life may be provided. In view of this and also considering the suggestions of the stakeholders in this regard, the Commission hereby specifies the levellised tariff for entire useful life i.e. 25 years for the solar power projects. The Commission would also like to clarify that the PPA term shall also be for the entire useful life of the project i.e. 25 years as per Regulations 2(71) of RERC Tariff Regulations, 2009.

Deration in Capacity Stakeholders Comments/Suggestions

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49. Acciona Energy Ltd. has submitted to consider deration in capacity for Solar Thermal Plants; whereas other objectors requested to increase rate of deration from 0.5% to 0.8% p.a. for solar photo voltaic power plants.

Commission’s Ruling

50. The Commission has given due consideration to comments and decides that the deration in output of 0.25% per annum after 4 years of operation as has been considered in draft tariff order for solar thermal power plants be retained, as such, whereas deration in capacity @ 0.5% per annum after two years of operation be considered for solar photovoltaic plants as against 0.25% per annum after 4 years in draft order for SPV plants.

Grouping of Solar technologies

Stakeholders Comments/Suggestions

51. Dalmia Solar Power Ltd., submitted that grouping of technologies between PV and thermal is not appropriate with specific reference to Dish sterling Engine technology. This technology is much closer to solar photo voltaic based power generation technologies and therefore, be grouped with solar photo voltaic technology on grounds of process similarity and having no commonality with solar thermal process.

Commission’s Ruling

52. The Commission observes that the development of solar power technologies in India is still at a nascent stage and considers it appropriate to broadly divide them in two categories, namely, CSP and SPV.Further, CSP technologies are based on the principle of concentrating the solar radiations as line focussing or point focussing. Dish Sterling Engine essentially employ the principle of point focus technology, therefore, has to be grouped under CSP plants. The Commission, therefore, considers it appropriate to retain the groupings for solar technologies, with Dish Sterling Engine based solar power plants covered under solar thermal category, as in draft order.

Evacuation system arrangement

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Stakeholders Comments/Suggestions

53. Rajasthan Renewable Energy Corporation Ltd., has requested Commission to clarify if the evacuation system in case of Solar Thermal Plant is to be arranged by power Producer or by State Transmission Utility.

Commission’s Ruling

54. The Commission under Regulation 89 of the RERC Tariff Regulations, 2009 has specified that capacity augmentation of a substation and backup transmission system for power evacuation from RE power station to the load centre shall be planned and carried out by the State Transmission Utility (STU). Further, the regulation mandates the STU to prepare a perspective plan for evacuation of power from RE power stations proposed to be set up over next 5 years with annual revision, if any, along with estimated costs thereof. These costs are to be borne by transmission utility and to be recovered as part of its aggregate revenue requirement.

In case of solar power projects, the charges of such grid connectivity for the first 50 MW capacity commissioned is ‘Nil’ as stipulated in the regulations. Looking to the facts that not much capacity has come on solar front till now and with the first phase of solar mission extends up to 31.03.2013 and with a view to avoid any uncertainty as to which solar plant development would become eligible for such free connectivity, the Commission decides that during the first phase of development of solar mission i.e. by 31.03.2013,there shall be no distinction about the levy of connectivity charges and all solar power plants getting connected to the grid for supplying power to Discoms during the period shall not be required to pay any connectivity charges.

55. Interface metering for billing purpose shall be at power plant as per

CEA regulations. However, if the metering is agreed to be at the licensee’s premises on 33 kV then the tariff shall be calculated after considering 1% of energy sent out towards losses and wheeling in line with the stipulation at note below Regulation 83(6)(b) of RERC Tariff Regulations. Depending upon the capacity i.e. upto10 MW of the solar power plant if the evacuation of solar power is agreed to be through 33 kV system, the power shall be injected into the nearest feasible EHV substation through the system to be laid down by home Discom and for lower voltage evacuation to the nearest 33 kV substation through the system to be laid down by the home Discom.This excludes exclusive LT rooftop solar power plants where the injection is at the consumer premises itself.However,if the quantum of pooled power is more than 10 MW and is agreed to be

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injected into RVPN grid and metered at EHV sub-station then the tariff shall be calculated after considering 4% of energy sent out towards losses and wheeling etc.,

Income Tax Stakeholders Comments/Suggestions

56. Torrent power Ltd., requested the Commission to determine the tariff based on expected long term tax regime as specified in the Direct Tax Code (DTC) rather than prevalent tax regime or alternatively to propose a mechanism that allows variation in income tax as a pass through in tariff. As on account of the fiscal deficit, the long term tax rates are expected to increase and the projects commissioned during this control period would receive tariff based on the tax rates prevalent today, but would pay taxes based on DTC from the second year till the final year of tariff period.

Commission’s Ruling

57. The Commission observes that as per Regulation 30 of RERC Tariff Regulations, 2009, the tax on Income of generating company (including renewable energy generating company) shall not be recovered from beneficiaries. Further, as per Regulation 21(4) of RERC Tariff Regulations, 2009 the regulated returns for renewable energy generating stations are specified on pre-tax basis by grossing up of stipulated return by MAT for first 10 years from COD and at normal rate for remaining years of project life, which has been considered by the Commission while specifying the tariff. The Commission has adopted the applicable Income-Tax rates in working out the generic tariff and therefore, no change is required.

Impact of Government and Institutional support Stakeholders Comments/Suggestions

58. Some of the stakeholders raised the issue that with the recent exemption in custom duty for solar plants by the Government and there being major imported parts in the solar plants the capital cost should be reduced. It was also submitted that the State Governments as well as the Govt of India are allowing certain subsidy in the capital cost and interest thereon for solar power plants which may be taken into account while finalizing the tariff of these plants. One of the stakeholders submitted that JNNSM promises a loan @ 5.5% for ten years whereas RERC model assumes it as 12.75%.

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Commission’s Ruling

59. No doubt that duty reduction would lead to cost being lower.However,as has been highlighted by some stakeholders, investors carry risk on account of variation in radiation data being adopted on long term average basis as actual radiation if lower than average in initial years would lead to financial loss and other risks are also involved in a project’s operation. Considering this, Commission is of the considered view that the cost indicated in draft order need not be reduced on account of recent exemptions in custom duty which in a way would cover the said risks.

Applicability of Tariff related to commissioning of solar power plants Stakeholders Comments/Suggestions

60. A majority of stakeholders have suggested that taking into consideration the long gestation period for development of Solar Thermal Power Plants, the CERC has specified that the generic tariff based on the norms for the year FY 2010-11 shall also apply for the year FY 2011-12 and FY 2012-13. Accordingly, the applicability of tariff determined should be extended up to 31st March, 2013. A majority of stakeholders have requested to extend the applicability of Tariff for Solar PV projects during FY 2011-12 instead of limiting it to FY 2010-11 as proposed under draft Order.

Commission’s Ruling

61. The Commission has carefully considered the views submitted by the various stakeholders with regard to the visibility of tariff and the request for extending the applicability of Tariff for solar PV projects to be commissioned up to March 31, 2012 and request for extension in Tariff in case of Solar thermal projects to be commissioned upto March 31, 2013. The Commission observes that the gestation period for solar PV projects is around 9-12 months whereas that for solar thermal power plants is around 24-28 months from the conception stage. Recently, the MNRE has proposed the draft guidelines for NVVNL bundling scheme under Jawaharlal Nehru National Solar Mission (JNNSM) wherein the gestation period for commissioning of the solar PV projects has been stated as 12 months whereas gestation period for solar thermal projects has been stated as 28 months from the signing of PPA. Thus, it is unlikely that any solar PV project would be commissioned within remaining period of 10.5 months available during FY 2010-11 (i.e. from mid-May 2010 up to March 31, 2011) and also unlikely that any solar thermal project would be commissioned within remaining period of 22.5 months available up to FY 2011-12 (i.e. from mid-May 2010 up to March 31, 2012) unless advance

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actions for project implementation are already initiated, which may be the case only in very few cases.

The Commission recognises that the regulatory certainty about tariff would be necessary to facilitate financial closure of the projects, particularly since there is hardly any precedence of solar power development in the country and the concerns of lenders/investors regarding tariff visibility needs to be addressed adequately.

In this context, the Commission also observes that Regulation 80(2)(a) of the RERC Tariff Regulations, 2009 empowers the Commission to determine the Tariff in case of supply of power by renewable energy generating plants to distribution licensees where such tariff is pursuant to power purchase agreement/arrangement entered into on a date subsequent to date of notification of regulations.

In view of above, as regards Applicability of Tariff for Solar PV, Solar thermal power projects and Rooftop PV power projects within Rajasthan, the Commission hereby rules as under:

a) the generic tariff determined for Solar PV projects and Rooftop PV projects based on the capital cost and other norms applicable for the projects commissioned in the year 2010-11 shall also apply for such projects commissioned during the year 2011-12; and

b) the generic tariff determined for Solar thermal projects based on the capital cost and other norms for the year 2010-11 shall also apply for such projects commissioned during the years 2011-12 and 2012-13,

provided that (i) the Power Purchase Agreements in respect of the Solar PV projects, Rooftop PV projects and Solar thermal projects as mentioned in this clause are signed on or before 31st March, 2011; and (ii) the capacity covered by the Power Purchase Agreements is commissioned on or before 31st March, 2012 in respect of Solar PV projects and Rooftop PV projects, and on or before 31st March, 2013 in respect of Solar thermal projects.

SOLAR TECHNOLOGY SPECIFIC NORMS

62. In addition to above, the following other norms/parameters specific to solar technology need to be finalised for determination of tariff: (1) Capital cost (2) Capacity Utilization factor (3) Auxiliary consumption (4) O&M expenses.

63. The position as emerges from analysis of the Commission for (A)

Concentrated Solar Power and; (B) Solar Photo Voltaic (SPV) and;

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(C) Roof Top Solar PV devices in respect of parameters mentioned in para 62 above, is being discussed in the following paragraphs.

(A) Concentrated Solar Power (CSP) Capacity Utilisation Factor (CUF) Capacity utilisation factor is dependent upon the solar insolation, conversion efficiency from solar to electricity and technology of a project. Solar Radiation Data (as in draft order)

(1) The energy yield from a solar power project depends on the solar insolation levels at the chosen location. Two of the projects are proposed in Jodhpur district while one in Bikaner district. The petitioners have taken different values of Direct Normal Irradiance (DNI) for estimation of power generation. In the initial submission by M/s. Entegra Ltd., the cumulative annual DNI at Jodhpur of 2173 kWh/m2 based on the Meteonorm data sets was considered. However, as per their additional submission, the annual DNI, based on the measurements by Indian Meteorology Department (IMD) at Jodhpur, was assumed as 2012 kWh/m2. This DNI has been derived from the Global Radiation data, for the year 2006, on horizontal surface and involves empirical relations to estimate the Diffused Radiation from Global Radiation and then uses the Global and Diffused radiation to estimate the DNI.

(2) The power generation estimation by ACME Tele Power Ltd. is based on annual DNI of 2285 kWh/m2. These DNI data are from the Solar Radiation Handbook which have DNI data estimated from the Global and Diffused radiation measurements from 1960 to 1978 at Jodhpur (Latitude 26.25E and longitude 73.05N) and are relevant for probable solar power sites as under :

Table-7

Months

Daily Total Avg GHI Based on Avg Hourly data (kWh/m2)

Daily Total Avg Diffused Radiation Based on Avg Hourly data (kWh/m2)

Daily Total Avg DNI Based on Avg Hourly data for GHI and Diffused Radiation (kWh/m2)

1. 2. 3. 4. Jan 4.715 1.138 7.238 Feb 5.565 1.362 7.42 Mar 6.549 1.771 7.354 Apr 7.233 2.336 6.725 May 7.545 2.683 6.324 Jun 7.068 3.058 4.985 Jul 5.979 3.385 3.298 Aug 5.544 3.208 3.126 Sep 6.101 1.878 6.02 Oct 5.827 1.218 7.604 Nov 4.903 0.908 7.719 Dec 4.432 0.931 7.448

Total annual 2285.3 Annual Average 6.2611

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(3) In absence of actual measurements of DNI, using a pyroheliometer, different methods for estimation of DNI have been adopted. The global solar radiation data published by the Solar Energy Centre provides the monthly average daily global and diffused radiation, while the data used by ACME Tele Power Ltd. as well as ENTEGRA Ltd. is on hourly basis, which is more accurate for conversion to DNI. However, the comparison of the same Global data for the period 1960-1978 and the recent data published by Solar Energy Centre shows a variation of about 6.8 %. The annual average global radiation as per 1960-1978 measurements, as published in the “Solar Radiation Handbook,” is 21.43 MJ/m2 while as per the recent data, published by the Solar Energy Centre, the annual average daily total global solar radiation is 19.97 MJ/m2 being lower than earlier data. A similar trend is observed when the 1960-1978 data is compared with the actual measured global radiation data for 2002-2007. The measured data for the said period is as under:

Table-8 Direct Normal Irradiance kWh/m2/day for Jodhpur 26.25E 73.05N

Month/Year 2002 2003 2004 2005 2006 2007 Avg 6 yrs

1. 2. 3. 4. 5. 6. 7. 8. January 6.193 6.168 6.183 5.831 6.296 5.946 6.103 February 6.241 6.147 6.742 5.672 6.281 5.783 6.144 March 5.663 5.325 6.185 5.81 5.492 5.55 5.671 April 6.242 6.3 6.345 5.77 6.191 6.533 6.230 May 6.761 6.837 6.103 6.64 7.006 6.722 6.678 June 6.7 6.06 6.227 6.373 6.236 5.805 6.234 July 5.44 3.833 5.736 5.123 3.836 4.457 4.738 August 4.411 4.04 4.062 4.819 3.084 4.038 4.076 September 6.546 5.937 5.724 4.978 5.622 5.53 5.723 October 6.956 7.096 6.426 6.885 7.004 7.006 6.896 November 5.927 6.545 6.382 6.746 6.639 6.848 6.515 December 6.541 6.771 5.979 6.767 6.045 6.313 6.403 Yearly Avg 6.14 5.92 6.01 5.95 5.81 5.88 5.951

(4) A reduction of 6.8% on DNI of 2285 kWh/m2 provides the DNI of 2130

kWh/m2 which is close to the daily average DNI of 2170 kWh/m2 based on hourly measurement IMD data as per NREL-SUNNY model. The IMD data are not only recent but quite reliable also and therefore, can be considered for working out CUF. Hence for the purpose of working out normative CUF, annual DNI of 2170 kWh/m2 based on IMD data can safely be adopted.

Stakeholders Comments/Suggestions (on solar irradiation)

(5) Acira Solar has submitted that the lowest value of Direct Normal Irradiation should be taken for estimating available solar irradiation.

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Commission’s Ruling

(6) The Commission observes that the information about direct normal irradiance (DNI) is of relevance and important for solar thermal power projects. Therefore, in absence of actual measurements of DNI for specific project sites under consideration, the estimation of DNI needs to be undertaken based on recent available information, as elaborated in draft Order. Further, the Commission is of the view that under generic feed-in tariff determination, the assumptions for parameters/norms should be representative rather than taking lowest value of DNI as proposed by the objector. For the purpose of deriving the DNI, the Commission has undertaken a detailed analysis of insolation data available from Indian Meteorological Dept (IMD), Solar Energy Centre and NREL-SUNNY model. In view of above, no modification in assumption of DNI on this count is necessary.

Conversion Efficiency (Solar Irradiance to Electricity)-as in draft order (7) Taking into consideration the gross efficiencies of the proposed projects

and the efficiencies of the projects under construction/operation globally, the Commission observes that there is steady improvement in efficiency and would like to support such improvement. Further, the Commission is also aware that projects in the State are at the planning stage and would benefit from the technological improvements and shall have better efficiencies than the projects under operation/construction. Thus, the Commission is of the view that the gross efficiency of 16.8%, which is close to16.6% as submitted by M/s. ACME Tele Power Ltd and 17% as projected by NREL, could be adopted for projects to be set up in the State.

Stakeholders Comments/Suggestions

(8) Acciona Energy Ltd has submitted that the conversion efficiency should be considered as 12% to 13% (without gas and without storage) Acira Solar has submitted that the conversion efficiency of operating projects worldwide ranges between 10.6% -14% and accordingly, the conversion efficiency of 14% may be considered while determining the tariff instead of 16.8% in draft order.

Commission’s Ruling

(9) While specifying the conversion efficiency, the Commission has taken into consideration the submissions of the petitioners and the international study conducted by NREL and other institutions. The Commission further observes that with advancement in technology, there is steady improvement in conversion efficiency and the Commission would like to support such improvements for projects which are still at the planning

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stage within the state. Accordingly, the conversion efficiency of 16.8% can be adopted for the projects to be set up in the State, which is close to submission of M/s Acme Telepower Ltd., of 16.6% as well as to projection of NREL study at 17%. In view of above, no modification to assumption of conversion efficiency on this count is necessary.

Capacity Utilisation factor (as in draft order) (10) The capacity utilization factor of 24% was proposed by ACME Tele Power

Ltd whereas ENTEGRA Ltd has proposed capacity utilization factor of 50.5% with 8 hours of thermal storage. GERC has considered CUF of 25% whereas CERC has considered CUF of 23%.

(11) The CUF being specified in this order is based on the DNI data and the gross solar irradiance conversion efficiency. Considering the annual total DNI of 2170 kWh/m2 and the gross efficiency of 16.8%, the annual generation from a 10 MW plant with 55346 m2 collector area works out to be 20.18 million units with the resultant CUF of 23.03%.

(12) Accordingly, normative Capacity Utilisation Factor (CUF) for determination of generic tariff for solar thermal power projects in the State has been considered as 23.0%, which is same as adopted by CERC.

Stakeholders Comments/Suggestions

(13) Acciona Energy has submitted that a CUF of 23% (without storage) is appropriate for solar trough technology. Further, many stakeholders submitted that thermal storage facilities should be permitted in order to optimise the operational performance of the solar thermal power plants. JVVNL has submitted that a minimum of CUF of 25% may be considered while determining the tariff as Rajasthan has better solar insolation than Gujarat.

Commission’s Ruling

(14) The Commission agrees with the views expressed by many stakeholders that some amount of thermal storage would benefit the solar thermal power system to improve the operational performance in terms of capacity utilisation factor and overall project economics. Further, it would also improve operational flexibility from the point of view of power system operations. To encourage thermal storage, Commission has decided to increase capital cost from the level indicated in the draft order, as discussed later. Along with capital cost enhancement, the Commission also considers it appropriate to take higher value of CUF as projects with thermal storage having higher CUF, could also come up. This would not affect non-storage thermal projects as the impact of higher CUF would more or less balance out with the increased value of capital cost as far as tariff is concerned.

Auxiliary Consumption (as in draft order) (15) The auxiliary consumption for the solar thermal power plant mainly

comprise of pumping, cooling and lighting and would be much lower

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than the auxiliary consumption of coal based power projects, which have additional power consumption for coal handling plant, coal crusher, ash handling, etc. M/s. Entegra has considered auxiliary consumption as 1.5% whereas 10% has been indicated by M/s. ACME. In absence of detailed breakup & justification, the 10% consumption envisaged by M/s. ACME seems unacceptable. The Commission is of the opinion that 3% auxiliary consumption, applicable for combined cycle gas based power projects could be specified for Solar Thermal projects also.

Stakeholders Comments/Suggestions

(16) The Stakeholders have submitted that the auxiliary consumption should be considered as 7% to10% as against 3% considered by the Commission under the draft Order. The stakeholders have argued that the auxiliary consumption factor for solar thermal projects with daily start/stop features and with solar field spread over vast area is not comparable to the auxiliary consumption factors of 3% as applicable for combined cycle gas turbine power plants.

Commission’s Ruling

(17) The Commission has noted the submissions made by various stakeholders as regards auxiliary consumption factor. Further, the Commission observes that the solar thermal plant requires daily start - stop operation which may lead to a higher amount of auxiliary consumption, since equipment in the plant will have to be brought up to operating temperature on daily basis while the solar plants are not required to handle the large mass of gas and exhaust as in gas turbine. Accordingly, the Commission has reviewed the auxiliary consumption norm and has considered auxiliary consumption as 6.50% while determining the levellised tariff for CSP Plants.

Project Cost (as in draft)

(18) There is very limited experience in the field of electricity generation utilising Solar Thermal Power technology. Since comparable projects have not yet been set up in the State or elsewhere in the country and benchmark data of capital cost is not available, reliance is being made on the expert opinion and details available from the various manufacturers through these petitions, other available literature, comments of the stakeholders, etc. The capital cost and other norms specified by CERC, Solar tariff order of GERC, details contained in the petitions and manufacturers report – stakeholders comments, Mathania project details, NREL published data etc. have also been given due consideration.

(19) The Solar Thermal project could be based on parabolic trough technology with storage for certain hours or without storage or solar tower technology or solar dish technology. The capital cost varies from one technology to another. The capital cost of a typical solar thermal power

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plant comprises of plant and machinery, civil and structural works, erection and commissioning and evacuation facilities, etc. For the purpose of specifying normative parameters, the parabolic solar trough technology is being taken as benchmark. Costlier technology would be accompanied by improved efficiency also resulting in higher CUF. Such higher cost is, thus assumed to be more or less balance out with higher CUF as far as incidence on tariff is concerned. Further, the capital breakup available is based on international experience whereas in Indian conditions, the cost of balance of system, power blocks, evacuation cost has to be lower. The land is also being made available by RREC at reduced rate as per GoR policy.

(20) The Commission notes that, there exists significant scope for indigenisation in solar thermal technology particularly in power block and other balance of plant/system components albeit feasibility for extent of indigenisation for initial few projects could be limited.

(21) For arriving at capital cost for solar thermal power plants in the Indian context, the Commission has also examined the breakup of capital cost components furnished by petitioner(s) viz. M/s Acme Tele Power Ltd (based on Solar tower technology – point focus) and M/s Entegra Ltd (based on Solar parabolic trough technology – line focus) and compared that with the capital cost component of solar block forming part of the Integrated Solar Thermal Power Plant planned at Mathania, Rajasthan. The project was a solar parabolic trough field combined with a gas fired combined cycle power plant (Integrated Solar Combined Cycle – ISCC) for the generation of electrical energy with a capacity totalling 140 MW, of which 35 MW was planned to be generated utilising Solar Trough Technology.

(22) The Commission further observes that the cost estimates of integrated solar combined cycle plant, which was proposed at Mathania in Jodhpur District, have been approved by the MNRE, KfW, GEF and the State Government. The Central Electricity Authority has also approved its total project cost, including IDC, O&M Expenses for the first two years and mandatory spares. Based on the project cost thus approved, the normative tariff was accepted and ‘in-principle’ PPA was signed. These approvals place high credibility on cost estimates of Mathania Project.

(23) The comparative analysis of the Capital Cost requirement as submitted by the petitioners namely, Acme Tele Power Ltd. and Entegra Ltd., with the capital cost requirement of ISCC Mathania project has been given in the table below:

Table-11 Plant Details Mathania Acme Entegra *

Technology Options Trough Tower Trough COST ITEMS Rs L/MW Rs L/MW Rs L/MW

1. 2. 3. 4. Civil and Structural 94 64 129 Solar Field 588 976 2198 Thermal Storage System(cost to be reconfirmed) 413 HTF System Incl.Solar Heat Exchangers 31 163

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Plant Details Mathania Acme Entegra *

Technology Options Trough Tower Trough COST ITEMS Rs L/MW Rs L/MW Rs L/MW

1. 2. 3. 4. Power Block/BoP Mechanical System 170 255 309 Power Block/BoP I&C and electrical system 56 76 35 Total Equipment Cost 939 1371 3570 Contractors (interface) engineering 66 4 5 EPC Contract 1005 1375 3575 Owners/operators cost 100 14 29 Contigencies 151 27 IDC 78 322 Total Project Cost 1256 1494 3926 Capacity Utilisation Factor (CUF)%

23% 24% 50.5%

* With solar thermal storage of 8 hours operation Note: The estimate of Mathania project pertains to year 2003. The exchange

rate at that time was around Rs. 46.58 per $.

(24) M/s.ACME in its proposal to RREC has indicated the capital cost of Rs.12.0 crores/MW and a tariff of Rs.10.80/kWh corresponding to parabolic trough technology without thermal storage. The cost estimates of Mathania project, which were approved by various agencies as discussed earlier, appear to be quite relevant even in today’s context due to the following reasons: (i) The exchange rate remains almost the same as was in year 2003; (ii) Estimates of Mathania Project also include cost of spares for 5 years

and O&M for 2 years. (iii) The cost escalation over the years in Power Block and other items

would get balanced out with reduction in cost of solar field to a significant extent; more-so when thermal storage of 200 MWh was built in Mathania project whereas the benchmark solar thermal project cost is being specified in this order for projects without storage.

(25) Gujarat Electricity Regulatory Commission vide its order dated 29-01-2010 has specified Rs.13 Cr./MW as the capital cost for solar thermal projects.

(26) Keeping the above facts into consideration, the Commission had considered normative capital cost for Solar Thermal Power Projects as Rs13 Cr/MW, which is close to estimates of Mathania project.

Stakeholders Comments/Suggestions

(27) (i) Shri Shanti Prasad submitted that capital cost comparison with Mathania combined cycle power plant is not appropriate. (ii) Acciona Energy ltd. submitted that the capital cost may be

considered as Rs16.4 Cr per MW. (iii) Acira Solar Pvt Ltd. submitted that the capital cost of the project shall

also include the cost towards evacuation of power and cost

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associated with the requirement of large quantity of water for power generation.

(iv) Acme Tele Power Ltd., Torrent Power Ltd. and Shri Shanti Prasad have submitted that the CERC has specified a benchmark capital cost for CSP plants as Rs15.30Cr/MW.

(v) Green Infra Ltd. submitted that the estimation of capital cost based on the cost structure of Mathania project is not appropriate. The RERC may adopt the approach followed by CERC in determining the capital cost of the project.

(vi) Kalpataru Power Transmission Ltd. submitted that the capital cost norms are not representative of all types of solar thermal technologies especially dish sterling technology.

(vii) Rudraksh Energy has suggested that the capital cost may be considered on the higher side on a realistic basis.

(viii) SKYSS has suggested that the project cost should be considered as Rs14Cr/MW.

(ix) Shri GL Sharma has submitted that the provision of subsidy provided by the State Government and Government of India should be included in the Capital cost.

Commission’s Ruling

(28) The Commission observes that till date there is hardly any experience in the field of electricity generation utilising Solar Thermal Power technology in the country. Further, Solar thermal projects of comparable size are at development phase and the benchmark data of capital cost is not readily available. The Commission while specifying the Capital Cost norms for Solar Thermal Power Projects has relied on the expert opinion and details available from the various manufacturers through the petitions, other available literature, comments of the stakeholders, etc. The Commission is of the view that there is ample scope for optimisation of costs in case of solar thermal technology through indigenisation initiatives, particularly in power block and other balance of plant/system components, although extent of indiginisation during initial stages may be limited. The benchmark capital cost of Rs 13 Cr/MW as considered under draft Order was based on solar thermal power plant configuration without any thermal storage. However, as highlighted earlier, the Commission recognises the need to have limited thermal storage to improve operational performance and flexibility. This would lead to additional requirement of solar field and associated costs of thermal storage etc.

Accordingly, the Commission has given due consideration to the submissions made by the various stakeholders and reviewed the capital cost requirement for solar thermal power plants as Rs14Cr/MW. The same has been considered while determining the tariff for solar thermal power projects.

O&M Expenses (as in draft order) (29) The Commission observes that there is no operating experience of MW

scale solar thermal power plant till date in India. It is observed that none of

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the State Electricity Regulatory Commission has specified break up of operating expenses which comprises of employee expenses, A&G expenses, and maintenance expenses. The information available about few projects and assumptions contained in the Orders in few States indicate that O&M cost for solar thermal installations varies in the range of 0.75% to 1.5% of capital cost.

(30) Considering the said position, the Commission considers it appropriate to adopt normative O&M Expenses of Rs. 15.00 lakh/MW for base year F.Y. 10-11 to be escalated at a rate of 5.72% per annum over tariff period. In addition, insurance @0.50% of the capital cost shall be applicable from the CoD of plant.

Stakeholders Comments/Suggestions

(31) JVVNL submitted that O&M expenses considered as Rs 15 Lakh/MW are higher as compared to Rs 13 Lakh/MW taken by CERC.Acciona Energy expressed that as per their experience cost f O&M expenses of 100 MW plant is around Rs 2300 Lakhs.Shri Yogesh Gupta submitted that escalation in O&M expenses be considered as 10%.He further, requested to consider reducing insurance charges based on depreciated capital cost.

Commission’s ruling (32) In consideration of the suggestion in respect of O&M expenses and

insurance charges, the Commission is of the view that O&M data for solar thermal power plant is not available and this technology by its nature is likely to result in higher operational costs. Further, the insurance charges needs to be considered at higher level.Therefore,the Commission considers it appropriate to retain the O&M expenses as Rs 15 Lakh/MW ,whereas insurance charges be increased from 0.25% to 0.30% with calculation for each year to be based on depreciated capital cost in that year.

Summary of Normative Parameters (FINAL) (33) Summary of the above discussed parameters adopted by the

Commission for the purpose of generic tariff determination for CSP power plants is as below:

i. Capital Cost: Rs.14.0 cr/MW ii. Capacity Utilisation Factor: 24% with deration of 0.25% every year after

4 years. iii. Auxiliary consumption: 6.5% iv. O&M expenses : Rs.15.00 lac per MW for base year F.Y. 10-11, escalated

@5.72% pa + 0.30% of depreciated project cost in each year towards Insurance.

(34) The norms indicated in sub-para 33 for CSP power plants would be applicable for the thermal projects getting commissioned in next three years i.e. by 31st March, 2013 subject to PPA getting signed in year 2010-11.

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Applicable Tariff (FINAL) (35) Considering the parameters discussed above and submissions made by

the various stakeholders, the feed-in-tariff for the solar thermal power plants under Generic Tariff dispensation is being determined as Rs12.58/kWh, as per calculation sheet placed at Annexure-VI. This tariff is levellised tariff for 25 years and applicable for plants commissioned without availing benefit of Accelerated Depreciation. This tariff would be applicable for solar thermal plants getting commissioned upto 31st March, 2013 i.e. by F.Y. 12-13 provided power purchase agreements with distribution companies are signed by March, 2011. CDM benefits, if any, availed by a developer would be shared in the ratio of 75:25 as stipulated in Regulation 42 of RERC Tariff Regulation, 2009.

(B) Solar Photo Voltaic Solar Radiation Data (as in draft order) (1) As mentioned earlier, the energy yield from a solar power project or the

Capacity Utilisation Factor (CUF) depends on the solar insolation levels at the chosen location and technology. Most of the SPV projects are proposed in Jodhpur district with one project in Nagaur and one project in Barmer district. In view of the proximity of the project locations and similarity in the solar insolation levels in the proposed locations in Rajasthan, Jodhpur district has been considered as the benchmark for solar insolation data. The petitioners have taken solar radiation data from NASA’s Surface Meteorology and Solar Energy (SSE) datasets which are based on 22 year weather data from NASA’s remote sensing satellites or Meteonorm 6.1 online weather data. Though NASA is highly reputed and the SSE datasets are commonly used worldwide for design of solar power systems, it is evident from the methodology of SSE published by NASA that their satellite data is not correlated with ground weather data as NASA does not have ground weather stations in India or it is not known if Indian Meteorological Department (IMD) shares their data with NASA. The data from Meteonorm is also unlikely to have been correlated with any ground weather data from Rajasthan.

(2) In the Public Hearing on the 23rd Sep. ‘09 limitations of available data and data sources on solar radiations were explained to the petitioners and they were advised to gather spot specific data at their own level.

(3) Since NASA and Meteonorm Models do not correlate the satellite data with the actual measurements from ground weather stations in India (unlike in USA and Europe where the models correlate the satellite data with measurements from several ground weather stations) and as such their data for India may be overstated or understated leading to inaccurate estimates for the calculations of energy generated from the proposed solar power plants.

(4) One of the petitioners has contested that it is the normal practice worldwide to use NASA or Meteonorm data and that the IPPs do not carry out any resource assessment studies. We acknowledge that this is indeed the case in USA, Europe and Australia because hourly solar radiation is available in public domain and there are several ground weather stations in those

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countries which are regularly sharing data with NASA and others which therefore obviates the need for carrying out solar resource assessment studies. It is a well know fact that when a large solar thermal project was planned in Mathania jointly by India and the USA, National Renewable Energy Laboratory (NREL) and the then Rajasthan Energy Development Agency have carried out solar resource assessment studies instead of adopting the data of sources discussed above. Even subsequently, as a part of US – India Energy dialogue solar resource assessment studies have been carried out for six years from 2002-07 and this data has been made available by NREL to RERC. A detailed study of all available data sources has led to the conclusion that NREL SUNY Model is the best available data source for solar radiation data for Rajasthan.

(5) One of the petitioners has also confirmed during their presentation that they were already in the process of installing a Weather Station at the project site as the same was insisted upon by their technology provider in order to provide performance warranties. This underlies the importance of solar radiation data from ground weather stations rather than models that predict the ground radiation data purely from satellite data. In the absence of exact project location specific solar insolation data project specific tariff will be some-what misleading and this also goes in favour of determining generic tariff till the operational data is firmed-up.

(6) Simulation of energy generated from solar power projects has been carried out using the NREL SUNY Model data averaged over 2002-07 for Jodhpur, as has been discussed in the following sub-para (7), based on the six years average Global Horizontal Irradiance of 5.821 kWh/m2/day given below and average Direct Normal Irradiance of 5.951 kWh/m2/day for six years given at table 8 [para 63 A(3)] of this order :

Table-12 Global Horizontal Irradiance kWh/m2/day for Jodhpur 26.25E 73.05N

Month/Year 2002 2003 2004 2005 2006 2007 Avg 6 yrs 1. 2. 3. 4. 5. 6. 7. 8.

January 4.373 4.363 4.427 4.274 4.475 4.355 4.378 February 5.271 5.096 5.442 5.121 5.304 4.988 5.204 March 6.187 6.048 6.387 6.24 5.992 6.09 6.157 April 7.103 7.119 7.152 6.742 7.075 7.179 7.062 May 7.585 7.604 7.257 7.478 7.656 7.524 7.517 June 7.284 6.882 7.15 7.171 7.068 6.823 7.063 July 6.713 5.637 6.816 6.515 5.75 5.975 6.234 August 5.867 5.591 5.644 6.056 4.917 5.651 5.621 September 6.397 6.173 6.007 5.586 5.928 5.976 6.011 October 5.73 5.771 5.49 5.697 5.741 5.745 5.696 November 4.541 4.761 4.697 4.791 4.77 4.832 4.732 December 4.239 4.302 4.064 4.311 4.095 4.085 4.183 Yearly Avg 5.941 5.779 5.878 5.832 5.731 5.769 5.821

(7) The simulation of energy generated was carried out for C-Si, CdTe, a-Si

technologies with fixed tilt angle and with single axis tracking for the solar

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arrays. The results of the simulation with PVSYST software (the same software that has been used by all the petitioners for their calculations too) are tabulated below:

Table-13 Comparison of Generation with Fixed and Tracking Systems at Jodhpur using

PVSYST Software Sl

No Module -

Make and Model

Inverter Model

Fixed/ Tracking

Global Incident

Radiation on Collection Plane (Yr)

Useful Energy

Produced (Inverter

Output) (Yf)

Incremental generation

with tracking

Capacity Utilization

Factor

Performance Ratio Yf/Yr

kWh/m2/year MWh/Year % % % 1. 2. 3. 4. 5. 6. 7. 8. 9.

1 C-si Sharp ND-216U2 Polysilicon modules

Sunny central 1000MV

Single Axis Tracking

2739 2103 22.27 24.01 76.8%

2 C-si Sharp ND-216U2 Polysilicon modules

Sunny central 1000MV

Fixed 24 deg tilt angle

2318 1720 19.63 74.2%

3 CdTe First Solar FS-275

Sunny central 1000MV

Single Axis Tracking

2739 2198 21.84 25.09 80.2%

4 CdTe First Solar FS-275

Sunny central 1000MV

Fixed 24 deg tilt angle

2318 1804 20.59 77.8%

5 a-si Unisolar PVL-144

Sunny central 1000MV

Single Axis Tracking

2739 2247 20.81 25.65 82.0%

6 a-si Unisolar PVL-144

Sunny central 1000MV

Fixed 24 deg tilt angle

2318 1860 21.23 80.2%

Stakeholders Comments/Suggestions (8) Shri Shanti Prasad in his written submission has expressed his concern that

there is a wide variation in solar radiation data and tariff based on mean value, there is a risk of low revenue stream during initial years of operation (if insolation happens to be on lower side).Acira Solar suggested that considering the high risk of the project, especially for the first several projects, lowest value of Direct Normal Irradiation (DNI) be taken for estimating the available solar irradiation.

Commission’s Ruling (9) The Commission is of the opinion that there is no need to modify the

approach of tariff determination based on mean value of radiation. The reason being that the risk to a developer on account of lower insolation gets appropriately covered as discussed in para 59 and also on account of increase in deration in the final order over and above what was adopted in

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draft tariff order which amounts to effective CUF after 2 years in a way being lower than that of draft tariff order.

Capacity Utilisation Factor (CUF)-(as in draft order) (10) CERC has specified CUF as 19% which seems to be a benchmark for any

location in India with reasonable solar insolation that would justify setting up of a MW scale solar power project. In the context of Rajasthan, the Commission has referred to the simulation models worked out by its consultant for the potential sites with NREL-IMD-SEC datasets for 2002-2007 using PVSYST software and is of the opinion that for the present a uniform CUF of 20.50% may be adopted for solar power plants to be established in Rajasthan in the light of range of CUF of 19.63 to 21.23% for fixed tilt systems given in the table-13 in the preceding sub-para (7).

Stakeholders Comments/Suggestions (11) Accoina Energy submitted that capacity utilisation factor be taken as

19.36% or have two CUF values of 19.63% for c-Si based plants and 21.23% for TF plants.BMD and AES solar indicated maximum CUF as 17%.Torrent requested to consider CUF as 19% in line with CERC. Shri G.L.Sharma submitted that CUF may be taken on average at 22.7%.

Commission’s Ruling (12) The Commission observes that India is a big country with varied geography

and climatic conditions and it is difficult to expect the same CUF for different locations in the country.Also, CUF of 19% in case of CERC norm is applicable for the entire period without any deration, whereas, deration has been provided in the draft order under consideration. Each country in Europe has a different tariff based on the solar insolation in that country and in USA also each state determines tax rebates and incentives based on the solar insolation and the project economics. Rajasthan is endowed with the best solar radiation in the country and deration after 2 years is also being provided. It is, therefore, justifiable to adopt a CUF that is higher than the CUF adopted by CERC for the entire country. Single axis tracking for C-Si technology may be economically viable whereas the cost of trackers for Cd-Te and a-Si technologies may outweigh the potential additional generation with single axis tracking. Therefore, the comment of one of the respondents and other public stakeholders about average over the range of CUFs including single axis tracking systems has not been accepted. Further, it must be noted that the cost of single axis tracking systems has not been accounted for in the benchmark capital costs. The Commission after consideration of the comments decides to continue with the proposed norm of 20.50% and no change is required.

Auxiliary Consumption (as in draft order) (13) None of the petitioners, except Videocon, has included auxiliary

consumption in tariff calculation. M/s, Videocon has considered auxiliary

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consumption of 0.25% of gross generation. The Commission considers 0.25% as reasonable auxiliary consumption for solar PV projects.

Stakeholders Comments/Suggestions (14) Acciona Energy submitted that OPEX depends on plant configuration and

technology choice.0.25% can be acceptable for fix frame (static) structures, but it would be in the range of 0.60% to 0.80% for plants using tracking technology and the figure of 0.25% be reviewed and ,at least, a median value should be adopted. Shri G.L. Sharma submitted that only Videocon has considered auxiliary consumption in their tariff calculations other petitioner indicated to take separate connection from utility to meet auxiliary consumption.Discoms should not release connections to solar power producers to avoid foul play. Shri Yogesh Gupta requested to consider auxiliary consumption as 0.50%.

Commission’s Ruling (15) Looking to the limited availability of data and with a view to promote these

technologies, the Commission considers it appropriate to continue with proposed norm of 0.25% and no change is required.

Project Cost (as in draft order) (16) MNRE has not specified project cost in their Guidelines issued in January,

2008. Further, there has been significant decline in the prices of solar modules since then. GERC in their order has fixed the benchmark project cost as Rs 16.50 Crores per MW for all solar photovoltaic technologies. Similarly, CERC in their RE Tariff Regulations issued on 17/09/2009 have specified the project cost as Rs. 17 Crores per MW without making any distinction between thin film solar, crystalline solar or concentrated PV technologies.

(17) Orissa Electricity Regulatory Commission in its order determining tariff of Rs. 15/kWh for 12 years and Rs. 7.50/kWh for remaining 13 years for solar power projects has referred to tariff and capital cost indicated by three petitioners as under:

Table-14

S.No. Petitioner Capital Cost Tariff 1. 2. 3. 4.

(I) Lanco Solar Pvt. Ltd. Rs.14.42 cr/MW Rs.12.50/kWh for 20 years and Rs.4.00/kWh for 5 yrs.

(II) Sahara India Rs.16.80 cr/MW Rs.15/kWh for 10 years (III) New Era Power Corp. Rs.16.80 cr/MW Rs.15/kWh for 10 years

(18) A detailed analysis of the project cost components for Thin Film (CdTe and a-Si) and C-Si technologies was carried out by the Commission based on the DPRs submitted by the petitioners. In addition to this, references have been made to solar portals such as www.solarbuzz.com for prices of key components of the solar system and the quotations for certain items like

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modules, inverters and transformers were reviewed. The long term price trends of polysilicon prices, supply – demand gaps, fluctuation in the Rupee – Dollar exchange rates and their impact on the prices of solar modules were also considered.

(19) For Module cost, the Commission has used the best competitive cost, being the lowest in petitions as given at Annexure-IV, as the benchmark in the case of thin film solar projects. In the case of crystalline solar projects, the module cost assumed by both the petitioners are way above the prevailing prices and the petitioners have neither adjusted the prices nor modified their tariff calculations despite the steep fall in C-Si modules which has been pointed out by Mr Gopal Somani, one of the stakeholder who gave comments on the petitions, as mentioned in Annexure-III. The future trend of polysilicon prices indicates that in 2010 the prices are expected to come down further. The Commission agrees with the contention of petitioners during the hearing that the impact of the decline of polysilicon prices on thin film solar prices is less significant due to the low silicon content in these modules. However, the same is not true in the case of crystalline silicon. Further, the argument advanced during the hearing that only spot prices of polysilicon have come down whereas majority of the sales are based on long term contracts cannot hold because some reputed domestic manufacturers on enquiry have quoted much lower prices at US$ 2.34 per Wp. Based on the capital cost break-up obtained from the petitioners and feedback of market trend from various sources, a comparative statement has been prepared indicating the benchmark price and the same is at Annexure- IV for thin film and Annexure- V for crystalline silicon solar power plants respectively. Benchmark price for C-Si modules has been arrived at as Rs 112 per Wp and for thin film solar modules as Rs 81 per Wp, as could be seen in the said Annexures.

(20) Inverter benchmark cost has been reckoned at Rs 18 per Wp based on comparison of the prices considered by various petitioners in their DPRs which has been further corroborated with the list price of a large distributor based in Spain for the same make and model of inverters.

(21) The benchmark cost of Rs. 15/Wp for mounting structure has been considered based on the lowest price emerging in the comparison of the DPRs corroborated with the price list for fixed tilt mounting structures in Europe. The Commission has also considered that thin film solar projects will incur additional costs for mounting structure on account of the larger area of the modules.

(22) Benchmark costs for Cables, junction boxes etc., has been determined taking the median of the prices as Rs.7.38 /Wp assumed by the petitioners in the DPRs and considering that the cost of cables for thin film solar will be higher than crystalline solar in view of the fact that cable runs over a larger solar field area.

(23) The Benchmark project cost also includes project insurance, foreign exchange fluctuation risk and contingencies, which have not been taken into account in the DPRs of some of the petitioners. Similarly, finance charges at 1.5% of the loan contracted and interest during construction period for 6 months on 67% of the loan amount have been considered in the benchmark project cost for the sake of uniformity even though some of the petitions have not assumed these costs.

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(24) Based on the above analysis, the benchmark project cost for solar PV power projects works out to Rs. 16.13 crore per MW, which is the average of Rs 15.32 crores per MW of thin film and Rs 16.95 crores per MW of crystalline solar power projects. Considering this and the trend of declining prices, Commission decides to adopt capital cost of Rs. 16.00 Cr./MW, more so as the benchmark cost would be applicable for the projects of year 10-11.

Stakeholders Comments/Suggestions (25) BMD Pvt. Ltd., submitted that considering there is an insignificant

development of Solar PV,the project cost may be considered as Rs 19.00 crores/MW.Shri Shanti Prasad expressed that risk in solar power plant may be accounted by considering an increase of 5%-10% in capex for initial 2-3 years.AES solar requested to consider project cost as Rs 17 crore/MW.

Commission’s Ruling (26) The Commission would not like to revise the proposed capital cost at this

stage and considers it appropriate to continue with the existing norm of Rs 16 crore/MW.The suggestion of stakeholders to consider increase of 5 to 10% in initial 2-3 years of solar development on account of various risk factors has already been discussed earlier in para 58 wherein the suggestion to reduce cost on account of duty reduction has been dealt with and more so in the light of downward trend in prices.

O&M Expenses (as in draft order) (27) O&M expenses benchmarked at 6.5% of the project cost for biomass

projects, 1% for small hydro projects and 1.25% for wind power projects cannot be applied to solar project due to the inherently different nature of the technology. After considering objections, justification provided by some of the Petitioners with the breakup of salaries, spares, insurance and overhead costs etc., the Commission is of the opinion that O&M expenses of Rs 9 lakhs per MW equal to amount provided in CERC RE Tariff Regulations 2009, be considered and in addition insurance cost will be allowed at 0.25% of the project cost.

Stakeholders Comments/Suggestions (28) Torrent Power submitted that capital cost be considered as Rs 9.51 lakhs/MW

for 2010-11 considering escalation at the rate of 5.72% on 2009-10 level of Rs 9 lakh/MW.AES Solar requested to consider O&M expenses as Rs 15 lakh/MW. Shri Vaibhav Gupta requested to consider O&M expenses as Rs 10 lakh/MW to be escalated @3.5%.Shri Yogesh Gupta requested to consider insurance charges reducing every year based on depreciable capital cost.

Commission’s Ruling (29) CERC has already revised the O&M expenses and this value already stands

revised to Rs 9.51 lakhs per MW for FY 10-11.The Commission, therefore, considers the same figure. In addition to this, insurance cost be allowed at

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0.30% of the project cost on the depreciated value of the asset for each year (as suggested by the stakeholder).

Summary of Normative Parameters (FINAL) (30) Summary of the above discussed parameters adopted by the Commission

for solar photo voltaic power plants is as below: i. Capital cost – Rs.16.00 cr./MW ii. Capacity utilisation factor – 20.50% with deration of 0.50% every

year after the first two years of operations. iii. O&M expenses – Rs.9.5 lac per MW for base year F.Y. 10-11 then

escalated @ 5.72% p.a.+ 0.30% project cost towards insurance on the depreciated value of the asset.

iv. Auxiliary consumption of 0.25% (31) The Norms indicated in sub-para 30 for solar PV plants would be applicable

for the solar PV projects getting commissioned upto 31st March, 2012.

Applicable Tariff (FINAL) (32) Considering the parameters discussed above and submissions made by the

various stakeholders, the feed-in-tariff for the solar PV plants under Generic Tariff dispensation is being determined as Rs 15.32/kWh, as per calculation sheet placed at Annexure-VII. This tariff is levellised tariff for 25 years and applicable for plants commissioned without availing benefit of Accelerated Depreciation. This tariff would be applicable for solar PV plants getting commissioned during the F.Y. 10-11 and FY 11-12 subject to PPA getting signed by 31st March, 2011. CDM benefits, if any, availed by a developer would be shared in the ratio of 75:25 as stipulated in Regulation.

(C) Roof top SPV installation: Tariff and Terms & Conditions:

64. (1) Commission is of the considered view that roof top solar PV devices need to be promoted and encouraged for the reasons discussed below and there is need to specify feed-in-tariff along with purchase obligation for solar energy from roof top devices:

(i) As per the roadmap proposed in the Solar Mission document, the target for the utility grid power including roof top to be deployed is 1,000 MW-2,000 MW for Phase I (2010-13).The Mission document seeks to encourage rooftop solar PV and other small solar power plants, connected to LT/11 kV grid, to replace conventional power and diesel based generators.

(ii) Harnessing the power of the sun can be done by using solar roof top photovoltaic (PV) panels to convert its light into electricity. Once the panel is installed, it requires little maintenance, emits almost no sound and should last for years. Against the rising costs of fuels, solar power is a cheaper energy option in the long run, as well as far more environmental friendly with other inherent advantages as well. For setting up of roof top solar panels creation of new infrastructure altogether may not be required. They do not require separate infrastructure like land, water facilities, land

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development, roads, security, illumination, civil structures, initial supply lines etc. which results in lower costs in upfront investment. Commission also feels that if the roof top modules get popularized, it would give tremendous boost to solar power generation.

(iii) Photo voltaic modules can be installed on the public buildings such as office complexes, production houses, shopping centers or schools, and on private buildings such as indoor gardens or terraced houses. Modules can protect against the weather giving shade from the sun.

(2) In the light of the position discussed above, roof top solar devices need be promoted and supported. To encourage setting up of roof top solar power systems in the State, the Commission proposes the terms and conditions, including preferential tariff, for setting up of roof top solar PV to be connected to 11 kV grid, as discussed in the following sub-paras.

Eligibility/Applicability (as in draft order) (3) The feed-in-tariff and the terms and conditions for roof top solar device

would be applicable for systems of capacity to be prescribed by Govt. of India for incentive under Solar Mission, installed at roof top of house/building/building complex, including solar PV devices installed on land in premises of such buildings. Further, the tariff would be applicable only for systems covered under the incentive scheme of Govt. of India. Solar PV system operator may be a consumer or a group of consumer or any other person/agency having right to use the space for installation, operation and maintenance of the solar system.

Applicable Tariff (as in draft order) (4) As regards capital cost benchmarking of roof top power plants, the

Commission is of the view that MW scale green field power plants require a large number of preliminary works in the form of land acquisition and development etc whereas for roof top such expenses would not be of same magnitude. It may be mentioned that the cost component of around 15-17% for a MW grid connected solar power plant is towards land, civil and general works, preliminary and pre-operative expenses. Expenditure on these items would obviously be lower for roof top devices. However, the CUF of roof top systems would also be lower since locations of most of the roof top systems would be in areas other than high solar radiation areas of western Rajasthan and also due to shading. In consideration of this and for promoting roof top systems on account of advantages of such devices; the Commission is of the considered view that the tariff as applicable for MW scale solar PV plants be extended to roof top devices also.

(5) Accordingly, the tariff of Rs.15.27/kWh is also being determined for roof top solar PV devices getting commissioned in F.Y. 10-11. The tariff would be the total amount payable to system operator and the incentive available from Govt. of India as announced in National Solar Mission

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would be available to distribution entity. Terms and conditions of incentive scheme of GoI would also be applicable.

Stakeholders Comments/Suggestions

(6) Since MNRE has now come out with the draft policy to incentivise rooftop by extending its coverage to all small power installations of capacity 1 to 3 MW injecting power on 11 kV or 33 kV and other plants of still smaller capacity less than 1 MW for injecting power on LT system. There was also a suggestion about promoting small capacity solar power plants in rural area where agriculture feeders can be connected which would reduce distribution losses too.

Commission’s Ruling

(7) The Commission agrees with the observation of a stakeholder that solar modules on the terrace can also help in cutting the radiation absorbed by the roof. In addition, based on the comments of one of the respondents and the public stakeholders, the Commission has decided to expand the scope of roof top PV systems to cover small solar systems of 1 to 3 MW capacity connected at 33 kV or 11 kV i.e.HT system, and also the small systems below 1 MW capacity to be connected to LT system in line with what is envisaged in draft GoI guidelines. However, in case there is any change in the final guidelines of GoI, the same would be applicable.

Guidelines for Metering, Billing and other Requirements (same as in draft order) (8) The Commission is of the view that for promoting roof top solar power

development in smooth and harmonious manner some guidelines are necessary to be laid down. These guidelines shall be followed by the developer and purchasing entity and suitably incorporated in PPA. The guidelines comprise of (i) Metering and Billing arrangement, (ii) Technical requirements; and (iii) General Terms and Conditions. The terms and conditions, as proposed in draft order, are being retained, as such, in final order.

Metering and Billing Arrangement: (9) (i) There are two basic philosophies of metering when utility grid is

connected with solar generating source and feed the load i.e. (i) Market rate net metering and; (ii) Feed in tariff metering.

(ii) As there is asymmetry in prices between the energy drawn from the grid and energy supplied by the solar system to the grid, the user would pay retail rate for the electricity used, and the utility will purchase the solar energy at Feed-in-tariff rate. System operators need to get paid for the electricity they generate from solar PV on their premises in the feed-in-tariff metering proposed to be adopted by the Commission. This would be in tune with what has been envisaged in

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National Solar Mission, wherein solar PV device operator is envisaged to be paid for the entire generated solar energy. In such a metering system the actual electricity being generated, net of auxiliary consumption to generate that energy, has to get counted on a separate meter, not just the surplus they feed to the grid.

(iii) Considering that Generation Based Incentive (GBI) would be based on entire solar generation, metering arrangement has been evolved by the Commission for payment for the entire solar energy fed into the grid. Total payment to system operator, being at the feed-in-tariff rate.

(iv) The CEA has brought out various schemes for the roof top solar power plants and its metering philosophies, which has been used as a guiding document. The Metering is required to measure the solar gross generation, consumer load consumption, export of energy to the grid and import of energy from the grid besides measurement of AC system voltages and currents, frequency etc. The proposed solar PV installation and metering scheme is available at Annexure-VIII.

(v) In the said scheme, when the grid is available, the consumer(s) load will be fed from grid side and solar system connected to grid through its inverter shall continuously feed the grid. In this arrangement battery and inverter cum charger (which may be available in the consumer’s house) is also shown. The DC generated form solar is first converted to AC and then it is connected to other equipments/grid. The whole of solar energy produced is being recorded in solar meter (SM) which is net solar energy produced and fed in the grid. The PV developer shall be paid on the basis of units recorded in SM and GBI to entity would be payable accordingly.

(10) Necessary changes in the proposed metering scheme to accommodate for required DG sets and/or battery inverter etc., as per need of solar PV developer may be adopted without affecting the security and sealing of complete metering system besides all cabling and switchgear from solar panel to the solar meter(SM).

(11) The Grid Meter (GM) and Solar Meter (SM) shall be interface type as envisaged in the metering regulations. These meters may also comply the Time of Day (ToD) requirements so as to accommodate this type of metering in future course of time. Also the SM would record net solar energy export reading indicated as SE(N) in the configuration given at Annexure-VIII.

(12) The developer of solar power shall follow in general the Metering requirements as stipulated in RERC/CEA Metering Regulations for all other purposes not discussed above.

Technical requirements (13) The technical requirements for roof top solar systems would be as under:

(i) In general the requirements specified by CEA in the CEA(Technical Standards for Connectivity to the Grid)Regulations,2007 would be observed.

(ii) The ripple content on the DC side of an inverter must not exceed 3% based on product’s literature.

(iii) The limits for Harmonics on AC side would be as under: • Total Voltage Harmonic Distortion………….. 5%

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• Individual Voltage Harmonics Distortion……3% • Total Current Harmonic Distortion……..……..8%

(iv) The voltage unbalance at HV side shall not exceed 3.0%. The permissible limit of voltage fluctuation for step changes which may occur repetitively is 1.5%.For occasional fluctuations other than step changes the maximum permissible limits is 3%.

(v) In addition to disconnection from the grid on no supply, under and over voltage conditions, PV systems shall be provided with adequate rating fuses, fuses on inverter input side (DC) as well as output side (AC) for overload and short circuit protection and disconnecting switches to isolate the DC and AC system for maintenance.

(vi) Fuses of adequate rating shall also be provided in each solar array module to protect them against short circuit.

(vii) Manual Disconnection Switch: In order to avoid possibility of malfunctioning with the automatic disconnection system of the inverter, manual disconnection switch besides automatic disconnection to grid, would also be provided to isolate the grid connection by discom personnel and to carry out any maintenance. This switch shall be locked by the discom personnel during the planned shutdown of the discom’s feeder. Locking of the switch may be required only under shutdown.

General Terms and Conditions: (14) The general terms and conditions are envisaged as below:

(i) The aggregate roof top PV capacity envisaged in the State in the remaining period of Solar Mission Phase-1 i.e. F.Y. 11 to F.Y. 13, would be as could be availed by distribution entities/developers under GoI scheme.

(ii) The capacity of roof top solar PV system shall be as envisaged in GoI scheme.

(iii) The 3-phase AC output from inverter of the solar power plant shall be stepped upto 11 kV, as the case may be, for connection to consumer bus. The surplus AC output shall get injected to the grid on 11 kV.

(iv) The GBI shall be payable on Net export of energy generated from the solar plant and fed into consumer bus.

(v) The operator shall execute the PPA with the concerned discom prior to taking up the execution of installation of the project.

(vi) The solar PV system proposed to be installed would be inspected and approved by the discom authorities prior to its operation in parallel with the grid to ensure compliance with applicable grid connectivity and technical standards of grid connectivity as specified by CEA and Metering requirements as stipulated in RERC/CEA Metering Regulations.

(vii) The power plant developer/operator would be responsible for protecting the solar PV equipment, inverters, protective devices, and other system components from damage from the normal and abnormal conditions and operations that occur on the discom system in delivering and restoring power; and is also responsible for ensuring that solar PV equipment is inspected, maintained, and tested in

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accordance with the manufacturer’s instructions to ensure that it is operating correctly and safely.

(viii) Meter readings shall be taken monthly on the same cycle as required under the prevalent RERC metering regulations.

(ix) Communication interface and Data Acquisition system: (a) The communication must be able to support Real time data

logging, Event logging, Supervisory control, Operational modes and Set point editing. The parameters to be measured and displayed continuously include Solar system temperature, Ambient temperature, Solar irradiation/insolation,DC current and Voltages, AC injection into the grid (one time measurement at the time of installation),Efficiency of the inverter, Solar system efficiency, Display of I-V curve of the solar system, Any other parameter considered necessary by supplier of the solar PV system based on prudent practice. Data logger system must record these parameters for study of effect of various environmental & grid parameters on energy generated by the solar system and various analysis would be required to be provided through bar charts, curves, tables, which shall be finalized during approval of drawings.

(b) The communication interface shall be an integral part of inverter and shall be suitable to be connected to local computer and also remotely via the Web using either a standard modem or a GSM / WiFi modem. The PV developer must install all the required hardware to have this web based Supervisory Control and Data Acquisition (SCADA) operational such that the system can be monitored via the web from distribution company office. Also full fledged SCADA is required to be installed by the developer.

Accelerated Depreciation & Differential Tariff (as in draft order) 65. The tariff for both the technologies i.e. CSP and SPV is being specified for

two situations viz., one for plants availing Accelerated Depreciation benefit under Income-Tax; and the other for the plants not availing such benefit for reasons given below:

(1) CERC orders visualise differential tariff for projects availing Accelerated Depreciation (AD) benefit in Income-Tax and for those not availing AD benefit for ensuring that in both the situation i.e. with AD benefit or without AD benefit, projects get commissioned.

(2) Govt. of India has recently launched a Solar Mission, which envisions capacity of 20,000 MW of solar power in India by 2022 and action has already started to put on ground Phase-1 of the Mission aiming at a capacity creation of about 1100 MW in the country.

(3) Solar technology is still at a nascent stage and not even a single grid connected project of 1 MW or above, has yet been commissioned in the State, as against 893 MW of wind and 74.3 MW of bio-mass projects commissioned in the State as on 28.2.2010.

(4) Considering the said position and the Government’s policy of giving big push to solar generation as well as the above discussed methodology adopted by CERC; the Commission is of the view that generic tariff being determined through this order should facilitate investment in both the

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situations i.e. with AD benefit or without that. This would imply differential tariff for the two situations, i.e. with or without adjusting AD benefit.

66. Accordingly, two rates are being given in this order, one for the projects availing AD benefit and other without AD benefit. For plants claiming Accelerated Depreciation, the tariff has been worked out to be lower by Rs.1.56/kWh for Solar Thermal and Rs.2.10/kWh for Solar PV, as could be seen at Annexure VI and VII. Since tariff of roof top solar device is being taken as same as that of solar PV projects, the reduction on account of AD for solar roof top device would also be Rs.2.10/kWh i.e. the same as that of solar PV projects.

67. A generator claiming the higher tariff worked out for projects without AD benefit would have to furnish an undertaking in advance to the buyer regarding AD benefit not being availed and this would have to be followed for each financial year by a certificate of the Chief Executive or the person responsible for filing Income Tax return of the generating unit to the effect that AD benefit has not been claimed/availed in that financial year.

Stakeholders Comments/Suggestions 68. JVVNL requested that tariff be determined net of AD benefit to avoid

differential tariff irrespective of the fact that whether developer takes the benefit or not. Shri G.L.Sharma requested that tariff be determined with AD benefit.

Commission’s Ruling 69. The Commission would like to retain the proposed differential tariff for two

situations one for the projects availing AD benefit and other without AD benefit.However, the figures for AD benefit shall change on account of changed parameters spelt out in this order and these values stand revised to that extent. For plants claiming Accelerated Depreciation, the tariff has been worked out to be lower by Rs.1.59/kWh for Solar Thermal and Rs.2.13/kWh for Solar PV, as could be seen at Annexure VI and VII. Since tariff of roof top solar device and small solar systems upto 3 MW covered under GoI’s subsidy scheme is being taken as same as that of solar PV projects, the reduction on account of AD for such solar devices would also be Rs.2.13/kWh i.e. the same as that of solar PV projects.

Conclusion (FINAL)

70. The generic tariff levellised for 25 years for two different technologies (SPV & Solar thermal) and for Roof Top and small Solar PV Installations is being determined as under:

Table-15

S.No. Particulars Tariff (Rs./kWh) 1. 2. 3. 1. Solar Thermal Power Plants commissioned by

31.3.2013 12.58

2. Solar Photo Voltaic (PV) Power Plants 15.32

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commissioned by 31.3.2012 3. Roof Top Solar PV Installations and other small

solar power generation plants covered in GoI’s subsidy scheme commissioned by 31.3.2012

15.32

71. The above tariff is levellised for 25 years. The PPA shall be executed

for 25 years. The tariff for roof top solar PV installation and small solar systems is inclusive of the incentive/subsidy component to be received by the purchasing utility/distribution licensee from Govt. of India. For plants availing benefits of accelerated depreciation, the above tariff shall be reduced by Rs.1.59/kWh for serial No.1 and Rs 2.13/kWh for serial No. 2&3 given in para 70 above in the light of implication of AD worked out as given in calculation sheet at Annexures-VI and VII.

72. The Commission has also come to the conclusion that the determined generic tariff would be applicable for petitioners because project specific long term tariff can’t be determined as necessary prudent check by the Commission in absence of site specific data is not practically possible. However, in case any petitioner still wishes to get determined project specific tariff, a separate petition would need to be filed for annual tariff determination along with information as may be required by the Commission.

73. The tariff given in para 70 read with para 71 above would be applicable for purchase of power by distribution licensees of the State from solar power plants commissioned in the State. The Discoms shall enter into the PPA by the year 2010-11 at the determined rate with solar power developer for the solar plants to be commissioned by 31st March, 2012 (SPV) & 31st March, 2013 (CSP) and for the roof top and small solar power systems under GOI policy for the plant becoming operational by March 2012.The tariff is levellised for 25 years and PPA would also be signed for 25. The purchase of solar power by distribution licensee shall be counted towards fulfilment of solar power purchase obligation. The Commission vide its earlier order dated 2.4.2008 has prescribed an obligation on the distribution licensees to buy 50 MW of solar power. This is over and above the 10 MW capacity envisaged to get installed under GBI scheme of Govt. of India, which visualises subsidy of Rs.12.00/unit to distribution licensees. Since roof top and smaller solar devices would also be eligible for generation incentive from Govt. of India as per National Solar Mission, purchase of power from such roof top and small solar power devices envisaged in this order would be over and above the obligation of aforementioned capacity of 50 MW.

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74. The said obligation of 50 MW capacity was envisaged vide order issued two years ago in April, 2008. The National Solar Mission has been launched a few months ago with the objective of enhancing solar capacity in the country, both for energy security as well as ecological security. The solar power purchase obligation in pursuant to National Solar Mission would be higher in the coming years. In addition, CSP projects would take 18-24 months to get commissioned and some of the projects in both SPV and solar thermal category may not fructify even after PPA.In consideration of above discussed position, the Commission is of the view that the distribution licensees need to enter into PPA of double the specified capacity of 50 MW i.e. 100 MW besides the capacity under incentive scheme of GoI. This is to clarify that even if actual capacity out of the said 100 MW exceeds 50 MW, that would get covered in the RPO of the relevant year as mentioned earlier or otherwise would be construed as part of RPO enhanced to that extent. It would be for the distribution licensees to work out as to how much capacity would they be getting and buying through NVVN under Solar Mission and how much directly from the plants proposed to be set up in the State.

75. The Commission after careful consideration has also come to conclusion that injection of solar power at 11 kV agricultural feeders offers additional advantages. Agricultural feeders have been separated in the state under Feeder Renovation Programme (FRP) and injection of solar power up to 1 MW on such 11 kV feeders seems feasible. Such injection would entail much lower losses, as otherwise happens in the transmission and distribution network. In addition, the farmers would also have advantage of getting power during day time. Such feeders may not be subjected to power-cut during power shortage in day time on account of availability of solar energy. Agriculture load also has the flexibility of shifting of load to day time to synchronise with increasing solar power, as is likely to happen in years to come.

76. In view of the above discussed advantages, Commission suggests that the distribution companies should consider earmarking 10 MW out of 100 MW visualised in this order for signing of PPA (for capacity other than under subsidy scheme of GoI) for projects of 1 MW each for power injection to 11 kV agricultural feeders. While selecting feeders preference could be given to such feeders which are complete in all respect under FRP.

77. The benefit availed by the Solar Power developer under the clean development mechanism shall be shared between the power producer and the power purchaser in the ratio of 75:25 as provided under the regulation 42 of RERC Tariff Regulation 2009.

78. This is also to clarify that the project developer to the extent of capacity contracted by signing PPA with distribution licensee for

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feed-in-tariff would not be availing benefit of REC as and when REC mechanism gets introduced in the country and such an undertaking would be incorporated in PPA.

79. Rajasthan Renewable Energy Corporation, being the nodal agency for development of the renewable energy as well as for achieving energy efficiency, is expected to ensure that the appropriate energy efficient solar technology is also promoted while providing land at concessional rate and other support to Solar Power projects.

80. For all solar power plants connected to the grid during the first phase of solar mission i.e. up to 31.03.2013, there shall be no grid connectivity charges.

81. The metering shall be at the generator premises as provided in CEA metering regulations.However, in case where the injection of power to the grid is agreed to be at the premises/ (substation) of the licensee, then tariff shall be calculated after considering 1% of energy sent out towards losses and wheeling charges in line with Regulation 83(6)(b) of RERC Tariff Regulations,2009.

82. With the issuance of this order, the petitions filed for the project specific tariff determination also stands disposed off in light of the observation at para 72 of this order.

83. Copy of this order be sent to all petitioners, respondents, State Govt., Central Electricity Authority (CEA), MNRE, RREC, stakeholders.

(S.K.Mittal)

Member

(K.L.Vyas)

Member

(D.C. Samant)

Chairman

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Annexure-I

List of Participants 1. Sh. M. M. Vijayvergiya, Executive Director, RREC (23.9.09) (24.9.09)(30.9.09) 2. Sh. Anil Kr. Patni, Project Manager (P), RREC (24.9.09) (30.9.09) 3. Sh.N.M.Sareen, CE (Comml), JVVNL (30.9.09) (14.10.09) 4. Sh. P.K. Bogawat, CE (O&M), AVVNL, (24.9.09) 5. Sh.A.K.Sharma, SE (NPP&R), RVPNL (24.9.09) 6. Sh.V.S.Rathore, SE (Comml), JVVNL (23.9.09) (24.9.09) 7. Sh.G.R.Choudhary, SE (RDPPC), AVVNL (23.9.09) (24.9.09) (30.9.09) 8. Sh.D.C.Bhurat SE (RDPPC), JdVVNL (23.9.09) (24.9.09) (30.9.09) 9. Sh. D.L.Jakhar, XEN, JdVVNL, (14.10.09) 10. Sh.Manoj Dwivedi, Tech. Manager, RREC, (14.10.09) 11. Sh.H.M.Gupta, Addl.XEN (NPP-R), RVPNL (24.9.09) (14.10.09) 12. Sh.Mukesh Vyas, TM, RREC (24.9.09) (30.9.09) 13. Sh. Subodh Kr.Bhatnagar, Tariff Consultant, Videocon (23.9.09) (24.9.09) (30.9.09) (14.10.09) 14. Sh.D.R.Mathur, Consultant, JVVNL (23.9.09) (24.9.09) (14.10.09) 15. Sh.D.S.Agarwal, Consultant, Rudraksh Energy (23.9.09) (24.9.09) (30.9.09) (14.10.09) 16. Sh.Shanti Prasad, Ex-Chairman, RERC (23.9.09) (24.9.09) 17. Sh.V.K.Gupta, Consultant, Rudraksh Energy, OPG, Swiss Park & Entegra (23.9.09) (24.9.09) 18. Sh.S.K.Agarwal, GM, Videocon (24.9.09) 19. Sh.Pankaj Alawadhi, Engineer, Videocon (24.9.09) 20. Sh.D.V.Satya Kumar, MD, Shri Shakti (23.9.09) (24.9.09) (14.10.09) 21. Sh.Parthav S.Mehta, Director, Shri Shakti (23.9.09) (24.9.09) 22. Sh.Arun Mehta, Vice President Refex (24.9.09) (14.10.09) 23. Sh.Anil Jain, MD, Refex (24.9.09) 24. Sh. R.Vyas, Consultant, RITI Energy (24.9.09), (14.10.09) 25. Sh.G.L.Somani, Retd. CE , RVUN (24.9.09) )(30.9.09) 26. Sh.Anlem, Sr.Manager, DCPL (24.9.09) 27. Sh.Gagan Vermani, Business Head, Systems MBPV (23.9.09) (14.10.09) 28. Sh.Avneet Vohra, Vice President, Astonfield (23.9.09) (14.10.09) 29. Sh.Ashish Calla, Engineer-B, Astonfield (14.10.09) 30. Sh.N.Sriniwas, MD, AES Solar, (23.9.09) (14.10.09) 31. Sh.Shailesh Jalan, Sr. Exe., OPG Energy (14.10.09) 32. Sh.Vimal Kumar, Sr.VP, Entegra, (30.9.09) (14.10.09) 33. Sh.Rohan Jhawar, GM, Videocon (14.10.09) 34. Sh.Prateek Ajmera, Sr.Executive, Videocon, (14.10.09) 35. Sh.Anil Bhatnagar, XEN (NPP), RVPN, (14.10.09) 36. Sh. R B Mishra, Acme Tele Power Limited , (30.9.09) 37. Sh.T.C.Arora, Sr.Vice President, Astonfield (23.9.09) 38. Sh.Yogesh Dabhade, (23.9.09) 39. Sh.R.K.Narayan, Director, ACME (30.9.09) 40. Sh.A.S.Kapoor, Advisor, ACME (30.9.09) 41. Sh.Ankur Kumar, Sr.Manager, ACME (30.9.09) 42. Sh.Vishnu Gupta, GM-Incharge, BHEL (30.9.09)

Order – Solar Tariff

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43. Sh.Sandro Scent, Commercial, Techint (30.9.09) 44. Sh.D.Prischicn, Consultant, Techint (30.9.09) 45. Sh.Dennis Quinn, Consultant, Techint (30.9.09) 46. Sh.Sudhir Kumar, Jt.Director, DCPL (30.9.09) 47. Sh.George Kellogg, Sr.Vice President, Broad Lands (30.9.09) 48. Sh.A.H.Pandit, Director, ABPS (30.9.09) 49. Sh.Sunil Jalan, Director, Swiss Park (23.9.09) 50. Sh.V.N. Vohra, Advocate (23.9.09) 51. Sh.Manish Narula, Sr.Manager, Moser Baer (23.9.09) 52. Sh.G.L.Sharma ,Individual (05.05.2010) 53. Sh.S.P.Pareek,Administrative Officer,SKYSS,Jaipur (05.05.2010) 54. Sh.D.L.Jakhar,SE(RDPCC),JdVVNL (05.05.2010) 55. Prof. Yogesh Gupta,CMD,SKYSS (05.05.2010) 56. Sh.D.S.Agarwal,ED(RSEB)retd. ,Rudraks Rnergy,RCCI(05.05.2010) 57. Sh.V.K.Gupta,Dy. CE(Comml.),RVPN retd. , RCCI(05.05.2010) 58. Sh.Subodh Bhatnagar,Individual, (05.05.2010) 59. Sh.Satyen Kanabar,AGM,Torrent Power (05.05.2010) 60. Sh. Vikas Saksena,VP(Engg.),ACME Telepower Ltd,Gurgaon (05.05.2010) 61. Sh.Ankur Kumar,Sr. Manager, ACME Telepower,Gurgaon (05.05.2010) 62. Lavleen Singal,President,ACIRA SOLAR (05.05.2010) 63. R.Vyas,MD,Riti Contructions Pvt. Ltd., (05.05.2010) 64. Sh.F.S.Meena, Dy. CE(Comml.),JVVNL (05.05.2010) 65. Sh.D.R.Mathur,Consultant,JVVNL (05.05.2010) 66. Sh.Gauharhakim,ASM,SSAEL (05.05.2010) 67. Sh.S.C.Bapna,Representative,Vivek Pharma (05.05.2010) 68. Sh.Sumit Kumar,Student,IIMB, (05.05.2010) 69. Sh.Deepak Jindal,Manager,Goodyield (05.05.2010) 70. Sh.Ravi Kumar Meena,Engineer,Dalmia Solar Powr (05.05.2010) 71. Sh.T.C.Arora,SVP,Astonfield (05.05.2010) 72. Sh.G.R.Chaudhary, SE(RDPPC),AVVNL (05.05.2010) 73. Sh.Asheesh Calla,Sr. Associate (05.05.2010) 74. Sh.Anil Patni,Project Manager, RREC (05.05.2010) 75. Sh.Rajsekhar Budhavarapu,Director,Acciona Energy (05.05.2010) 76. Sh.N.Shrinivas,MD,AES Solar (05.05.2010) 77. Sh.M.M.Vijayvergia,ED,RREC (05.05.2010) 78. Sh.G.L.Somani,President,ERA (05.05.2010) 79. Sh.S.S.Dakhera,FC,ERA (05.05.2010) 80 Tushar Sood,KPMG/Kalpataru (05.05.2010) 81 Sheetal,Good yield (05.05.2010)

Annexure-I…contd…

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Summary of Comments/Observations of Individuals/ Stakeholders on CSP Petitions

(1) Sh. Shanti Prasad, Ex -Chairman, RERC

The petitioner, Acme Tele Power Ltd, may clarify:

(i) that countries like France, Germany and Spain are located at higher latitude and the solar insolation as well as clear sunny days in those countries are lower as compared to the proposed project site, yet they have comparatively low cost of generation for solar power.

(ii) The 15.5 percent return on equity, considered for tariff computation is not in line with RERC tariff regulations.

(iii) Escalation of O&M expenses has been kept as 3% against 5.72% specified in the RERC tariff regulations, 2009 for tariff computation.

(iv) Transfer of hundred percent CDM benefits to DISCOM have been proposed while computing the tariff, instead of sharing on 75:25 basis specified in the RERC tariff regulations, 2009.

(v) For computation of tariff depreciation rate as 3.6% per annum has been considered alongwith advance against depreciation, instead of depreciation rate as 5.28% p.a. for first 12 years and thereafter 2.05% p.a. for the remaining life as per the regulations.

(vi) Interest on loan as per repayment schedule has been considered as against the norm of considering it on notional basis as equal to depreciation charges specified in RERC Tariff Regulations, 2009.

(vii) The income tax considered for determination of tariff is different and is varying from one year to another.

(2) Rudraksh Energy (i) The norm for return on equity as 15.5% has been considered by

Acme Tele Power Ltd, for tariff computation which is not in line with RERC tariff regulations.

(ii) With regards to depreciation rate in the case of Acme Tele Power Ltd, the depreciation rate as 5.28% p.a. for first 12 years as per regulations should be considered for computation of tariff.

(iii) The thermal storage facility, preferably for 4 to 6 hrs could be provided by Acme Tele Power Ltd, to generate power during peak demand, consequently, this would have increased the capital cost.

(3) Sh.G.L.Somani, Ex CE,RVUN

(i) The petitioner, Entegra Ltd, should provide detail calculations and assumptions made for capital cost breakup for solar block component.

(ii) To reduce the capital cost (solar block) the commissioning of the 2nd unit of 5MW could be phased out, by Entegra Ltd., after the

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implementation of the first unit. It should be noted that the capital cost of the proposed project is comparable with the Andasol 1 Solar Thermal Project.

(iii) Proposed levellised tariff (Rs.15.88/kWh), by Entegra Ltd., is on the higher side and can be reduced significantly.

(iv) Considerations of Plant Load Factor along with Solar irradiation to electric efficiency, by Entegra Ltd., is quite high in comparison to existing and recently commissioned projects and large solar field has been considered for high temperature steam parameter and higher turbine efficiency leading to high solar block cost. Therefore solar field sizing calculations should be investigated thoroughly for cost economic optimisation.

(v) In case of Entegra, the thermal energy storage capacity is difficult to incorporate with the troughs technology and Molten salt as heat transfer fluid for heat collecting elements in Parabolic Trough has not yet been used, therefore the usage of the molten salt also needs to be reviewed because if the system is faced with the continuous cloudy days or non solar days heat storage capability of the molten salt is very unreliable.

(vi) In case of Entegra, the irradiation data should be checked for its reliability and it shall be ensured that IMD and Meteonorm data are station specific and not site specific.

(vii) In case of Entegra, the optimum efficiencies of the technology (Mirror reflectivity, HCE absorption, Solar field optical efficiency and availability, Incidence angle, piping loss, thermal storage loss heat) should be evaluated in the field as well as under test conditions and taken into consideration.

(viii) Degradation and efficiency drops drastically after 6 years and therefore it should be taken into consideration by Entegra Ltd.

(ix) High risk factors like dust and sand storm should be considered, by Entegra Ltd., since they affect mirror reflectivity index, collector absorbance and other parameters. Lack of reliable irradiation data would be the hindrance to the project and site specific irradiation data should be established.

(4) Sh. P.N.Mandola (i) In the case of Entegra Ltd., the proposed levellised tariff

(Rs.15.88/kWh) is on the higher side and can be reduced significantly. (5) Discoms :

(a) During the Public Hearing held on 30th Sep, 2009, the Respondent Jaipur Discom have raised objections on the petitions as per the details given below.

(I) Requested to determine Tariff for solar thermal power projects on Generic basis, as number of technologies are proposed for installation by various Petitioners such as parabolic trough, tower and dish technology.

(II) In case, project specific tariff is pursued, detailed scrutiny of

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capital cost components may need to be undertaken so that spurious cost elements can be curtailed. For example, cost of imported heat exchanger is unwarranted when indigenously heat exchangers can be manufactured.

(III) Installation of meters should be undertaken at distribution licensee’s grid substations.

(b) Ajmer Discom and Jodhpur Discom endorsed the views of Jaipur Discom.

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Annexure -II (A)

Summary of comments/objections received from stakeholders in respect of Solar Thermal Plants (The name of objectors are given in brackets)

S.No. Particulars Comments/objections 1. Capital Cost Consider Rs.15.30 crores per MW as per CERC instead of Rs.13.00 crores

per MW as per draft order, since CSP at a nascent stage and no MW scale plant have been commissioned yet (Torrent Power). Consider 14.00 crores per MW (Sh.Yogesh Gupta). The capital cost norms is not representative of all the available solar thermal technologies, dish sterling technology cost more than 20.00 crores per MW (Kalpataru Power). Capital cost be considered on realistic basis. The CERC has also revised capital cost from 14.2 crores per MW to 15.3 per MW after some deliberations (Sh.D.S.Agarwal). Consider 15.3 crores per MW as per CERC (ACME Power). Comparison of capital cost of stand-alone solar thermal with integrated solar combined cycle thermal project is not equitable (Sh.Shanti Prasad).

2. Auxiliary Consumption

Consider 10% as per CERC instead of 3% specified in draft order. Suggested 6% (Sh.Yogesh Gupta). Consider 10% (Kalpataru Power & PEC).Consider 7% as per CERC (Sh.D.S.Agarwal), Consider 10% since in 5 MW plant estimated auxiliary consumption during operational/non-operational hours, is around 675 KW (ACME Power). Auxiliary consumption for solar thermal project is comparable with steam cycle CC –GTPS and may not be less than 7% (Sh.Shanti Prasad). Consider 15% due to high project risk (Acira Solar). Consider 10% as per CERC (Green Infra, Acciona Energy).

3. Depreciation

On account of higher risk involved in solar power project, rate of depreciation should be 7% i.e. higher than conventional power plant (Sh.Shanti Prasad), Depreciation is linked to loan repayment period. Solar technologies are new with high risk and banks are reluctant to finance therefore achieving financial closure for projects under RERC tariff would be difficult. Rate be changed to 7% (Green Infra Ltd.). Tariff be determined with AD benefit to avoid differential tariff irrespective of the fact whether developer takes the benefit or not (JVVNL).

4. Size of a CSP Plant

For solar trough sterling technology , the minimum viable size will be 30 MW (Acciona Energy)

5. Tenure of PPA

Should be 25 years instead of 20 years as practiced internationally (Acciona Energy)

6. Levellised tariff

Should be for project life of 25 years against proposed 20 years (Acciona Energy, Sh.Shanti Prasad, Sh. Yogesh Gupta, Sh.D.S.Agarwal)

7. Debt Equity Ratio

70 : 30 debt equity ratio is very difficult for non-recourse finance route (Acciona Energy)

8. CDM Benefits CDM registration is very lengthy and involve lot of time and cost to developer and Discom does not share any risk of developer ,therefore, CDM benefit should not be shared by Discoms (Green Infra Ltd.)

9. Working capital

Consider 2 months receivables instead of 1.5 months (Torrent Power, Acciona Energy), Consider one month receivables instead of 1.5 months as specified, consider O&M expenses only for ½ months against one month as specified (Sh.G.L.Sharma), Consider maintenance spares @ 5% of O&M expenses (JVVNL).

10. Interest on Term Loans

Consider interest rate of SBI PLR +150 bps as there is high risk associated with solar power plant (Torrent Power, Green Infra), Consider interest

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rate at SBI PLR + 200 bps as per their experience (Acciona Energy) 11. Interface

Metering The responsibility for development of evacuation system from pooling station should be clearly specified. CERC and GERC have specified capital cost inclusive of evacuation infrastructure upto interconnection point (RREC). As per NVVN transmission charges, losses, SLDC charges etc., upto joint delivery point are borne by utility. Interconnection point for supply is HV side of generator transformer applicability of development fee of Rs.2.00 lacs per MW needs to be clarified.Charges ,if any ,for network augmentation if any to be clarified. (Acciona Energy).

12. Applicability of tariff

As per order, tariff is applicable for project commissioned upto 2011-12 needs to be extended suitably (Acciona Energy). Applicability be made upto 31.3.2013 (Torrent Power & Sh.D.S.Agarwal). The period should be upto March,2014 because of present practice and delay in Government formalities/other activities such as loan etc. (Sh.Yogesh Gupta).

13. Solar Radiation

There is a wide variation in solar insolation data, therefore tariff calculation made at average value will have risk of revenue return during initial years of operation (Sh.Shanti Prasad). Lowest value of DNI should be taken for estimating available solar irradiation (Acira Solar)

14. Conversion efficiency

Suggested conversion efficiency of 14%, since the conversion efficiency of operating project world wide ranges from 10.6% to 14% (ACIRA Solar). Suggested efficiency around 12% -13% without gas and storage (Acciona Energy).

15. CUF CUF should be 25% as considered by GERC instead of 23% (JVVNL). CUF of 23% be considered for solar trough (Acciona Energy)

16. O&M Expenses

O&M expenses considered as Rs.15 lacs are higher as compared to Rs.13.00 lacs per MW taken by CERC (JVVNL). Labour is major component of O&M expenses therefore escalation should be 10% (Sh.Yogesh Gupta). As per their experience cost of O&M expenses of 100 MW plant is around Rs.2300 lacs (Acciona Solar)

17. Income Tax Rates

Variations in Income Tax rates be allowed as a pass through in tariff (Torrent Power). MAT rates considered as 19.93% for first year and 18.54% from second to tenth year whereas MAT would be applicable @19.93% throughout the initial 10 years as profit of 100 MW plant will be above 1.00 crore (ACME Power). MAT considered @19.93% for 1st year only( Sh.Shanti Prasad).

18. Reduction in Custom Duty

The exemption is provided in custom duty on machinery required for setting-up solar power plant similarly subsidy provided by the State Govt., in capital cost and interest. Consideration be given to these aspects in finalizing the tariff (Sh.G.L.Sharma).

19. REC Coverage

Developer getting feed in tariff can not avail REC coverage when introduced. Therefore utility after meeting RPO be allowed to have supplementary PPA with developer at pooled cost of power enabling the developer to be eligible for REC (Sh.Shanti Prasad).

20. Forex Forex variation would reflect on capital cost, thus any rise will be to developer account (Sh.Shanti Prasad).

21. Grouping of Technology

The developer should be free to choose any technology. It will help in development of most suited and efficient technology. Further dish sterling technology be grouped with solar PV technology, because of the process similarity (Dalmia Solar).

22. Capacity (In MW) for which PPA to

Through draft order, the Discoms have been directed to enter PPA upto 100 MW capacity besides capacity under GBI scheme. It is not clear how additional financial implication would be met in case actual

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be executed capacity exceeds 50 MW. Since existing regulations specify RPO to the extent of 50 MW only.

23. Insurance Consider fixed for 20 years but it should be reducing every year as per depreciated capital cost (Sh.Yogesh Gupta).

Summary of Comments/Observations of Individuals/ Stakeholders on SPV Petitions

(1) Sh. D. S. Agarwal, Executive Director (RSEB)-Retired

(i) That in the case of Refex Refrigeration, salvage value considered should be 10% instead of 5%

(ii) interest on working capital has not been considered (iii) O&M costs at 1.5% are on the higher side. (iv) That the capital cost at Rs 21.4 crore /MW is very high (v) The levelized tariff calculated is very high. (vi) For the selected project site the insolation of 5.58kWh/sqm/year is very low. (vii) That the petitioner AES solar should clarify and confirm the discrepancy in the

net annual generation. (viii) That useful life assumed is 20 years against the norm of 25 years. (ix) That Petitioner may clarify the applicability of MAT whether for 10 years or 15

years. (x) That O&M costs were calculated at 1% in the tariff calculations whereas the

same was mentioned as 1.5% in the public notice. (xi) That the levelized tariff proposed in the petition is Rs 18.88 per unit while it was

mentioned as Rs 19.75 per unit in the public notice. (2) Sh.Shanti Prasad,EX Chairman,RERC

(i) In the case of Refex, the salvage value considered is 5% as against 10%. Whether tariff will be adjusted for impact of exchange rate. That the solar insolation data considered by Refex is low and that working capital is not considered and (levelized tariff calculated is not equal to what is stated in the DPR). Cooling employed and accounting for losses due to temperature and net output may be indicated.

(ii) That in the case of AES Solar, petitioner should not employ radioactive isotopes and ensure the same in the supply. That civil costs at Rs 5.35 crore/ MW is quite high and that foundation design to be as per soil testing and indigenously available construction materials. That tariff calculations be revised in view of revised MAT rates as per new Finance Bill 2009. That insurance charges at 0.5% appears to be high and that plant configuration should maximize land utilization. That useful life should be 25 years and levelized tariff to be recalculated and that interest on working capital has not been considered. That the surveillance system cost is very high. Also, petitioner to confirm 70:30 debt equity ratio.

(3) Sh.G.L.Somani,Ex CE,RVUN On the capital costs Sh.Somani stated that there is in general drastic fall in the price of silicon worldwide due to recession, fall in demand and increase in production capacities. In support of his statement, he submitted various documents, extracts i.e. PV supply chain pricing, Spain’s Solar market crash, Solar buzz-retail price environment, photon international module pricing rationality, solar technology-cost trend global market review and general analysis on solar technology and cost estimates.

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(4) Sh.P.N.Mandola (i) That the Principal Secretary (Energy) be made a respondent and an affidavit

taken from the Principal Secretary that the state government will provide the subsidy support to the distribution licensee for the feed-in tariffs decided for the solar power projects.

(ii) That plantations will be provided at the project site by the petitioners and an undertaking to that effect be taken from the petitioners.

The respondents Jaipur Discom have raised objections on the petitions as per the details given below :

(i) That the tariff proposed in the tariff petitions is much higher than those indicated by the petitioners in their DPRs submitted to RREC which should not be allowed.

(ii) That the cost of silicon has drastically fallen down from the time, the petitions were filed and this cost may further fall down. Alternatively, the Commission may at its own discreation consider a reasonable cost of silicon.

(iii) That rate of interest has also fallen down, which does not appear to rise in future or the Commission may at its own consider a reasonable rate of interest.

(iv) That the benefit of Accelerated Depreciation should be accounted for as has been done while determining the tariff for wind power and biomass power plants so that the petitioners are not doubly benefited.

(v) That the contingency charges considered in the range of Rs 0.6 crores to Rs 2.0 crores in the petitions are not provided in tariff regulations and accordingly, the capital cost be adjusted.

(vi) That cost under the head ‘Balance of Plant’ is exorbitantly high as steel support structures, their fabrication and civil works can be easily arranged indigenously at very reasonable rates. Also electrical and other miscellaneous parts can also be arranged indigenously at very reasonable rate.

(vii) That CERC Regulations dated 16.09.09 have benchmarked the O&M cost at Rs 9.0 lakh/MW whereas the petitioners have considered O&M cost ranging from Rs 19.5 lakh to Rs 31.7 lakh/MW. O&M cast as per CERC norms be considered. However, insurance cost may be allowed separately ranging from 0.2 to 0.3% of the project cost.

(viii) That the petitioners should rely on Ministry of New and Renewable Energy (MNRE)/Indian Metrological Department (IMD) as NASA data are approximate data not appropriate for working out the capacity of MW –solar projects. In fact they should conduct their own site-specific studies so as to arrive at the results more nearer to the actual.

(ix) That except M/s Refex ,no petitioner has analyzed the installation of sun tracking system .All the petitioners have reacted differently about arrangement for tilt angle.Discoms expressed that use of proper technology will definitely reduce the per unit cost of generation.

(x) Discoms submitted that above factors may reduce the cost of generation by 15 to 20% and increase the estimated generation by 5 to 10% which may overall reduce the per unit cost of solar power by more than 25%.

(xi) Discoms submitted that it is obligatory for them to purchase the solar power as per the requirement of RERC regulations and requested the Commission to allow the recovery of extra burden on this account from the consumers, as pass through, as

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‘Solar Charge’. Alternatively the State Govt be directed to bear extra burden and pay equivalent subsidy to the Discoms.”

The Ajmer Discom and the Jodhpur Discom endorsed the views of Jaipur Discom.

Annexure -III(A)

Summary of comments/objections received from stakeholders in respect of Solar PV Plants

(The name of objectors are given in brackets)

S.No. Particulars Comments/objections

1. Capital cost of PV Plant

Considering that there is an insignificant development of Solar PV, the project cost may be considered as Rs.19.00 crores per MW (BMD Pvt.Ltd.), Risk in solar power plant may be accounted by considering increase in 5%-10% in capex for initial 2-3 years. Further, average capex will benefit thin film technology and disadvantageous to crystalline solar, therefore, different generic tariff be considered for different technologies (Sh.Shanti Prasad), Benchmark cost be considered as Rs.16.9 crores as per CERC (Torrent Power), Cost be revised to Rs.17 crores per MW (AES Solar)

2. Capacity Utilization Factor (CUF)

CUF be taken on average as 19.36% or have two CUF values of 19.63% for CSI based plants and 21.23% for TF plants (Acciona Energy), max. expected CUF is 17% (BMD, AES), 10% increase with single axis tracking (BMD Pvt. Ltd), CUF be kept 19% in line with CERC (Torrent Power). Consider CUF (JVVNL), consider 19% due to nascent stage of PV (Sh.Yogesh Gupta), CUF may be taken on average at 22.7% (Sh.G.L.Sharma)

3. Deration Factor

International average is 0.62% to 0.8% (Acciona Energy), Consider 1% p.a. from end of year 1 and makes upto 20% in 25 years. Inverter efficiency be taken 84% (BMD Pvt. Ltd), Consider 0.61% to 1% for first 4 years (Torrent Power). Suggested duration of 1% p.a. (Sh.Yogesh Gupta), Consider 0.5% to 0.8% (AES Solar). Average deration 0.8% (Sh.Vaibhav Gupta).

4. Depreciation On account of higher risk involved in solar power project, rate of depreciation should be 7% i.e. higher than conventional power plant (Sh.Shanti Prasad), Depreciation is linked to loan repayment period. Solar technologies are new with high risk and banks are reluctant to finance therefore achieving financial closure for projects under RERC tariff would be difficult. Rate be changed to 7% (Green Infra Ltd.), Tariff be determined with AD benefit to avoid differential tariff irrespective of the fact whether developer takes the benefit or not (JVVNL), Tariff be determined with AD benefit (Sh.G.L.Sharma)

5. Auxiliary Consumption

Against proposed rate of 0.25%, atleast a median value be adopted (Acciona Energy). Only Videocon has considered Aux. consumption in their tariff calculations other petitioner indicated to take separate connection from utility to meet Aux. consumption. Discoms should not release connections to SPPs to avoid foul play (Sh.G.L.Sharma). It should be 0.5% (Sh.Yogesh Gupta).

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6. CDM Benefits CDM registration is very lengthy and involves lot of time and cost to developer and Discom does not share any risk of developer, therefore, CDM benefit should not be shared by Discoms (Green Infra Ltd.)

7. Interest on Term Loans

Consider interests rate of SBI PLR +150 bps as there is high risk associated with solar power plant (Torrent Power, Green Infra), Consider interests rate at SBI PLR + 200 bps as per their experience (Acciona Energy). JNNSM promises a loan @5.5% for ten years whereas RERC model assumes it 12.75% for 12 years (Sh.Vaibhav Gupta).

8. Interest on Working and Capital Receivables

It should be @SBI PLR+100 basis point in line with CERC and receivables of 2 months be considered for working capital (Torrent Power). Receivables 1 month against 1.5 months (Sh.G.L.Sharma).

9. O&M Expenses

Be considered as Rs.9.51 lacs for 2010-11 considering an escalation @5.72% on 2009-10, rate of Rs.9.00 lacs per MW as per draft order (Torrent Power), O&M expenses be consider as Rs.15.00 lacs per MW (AES Solar). Rs.10.00 lacs to be escalated @3 - 5% (Sh.Vaibhav Gupta)

10. Tenure of PPA

Should be 25 years instead of 20 years as practised internationally (Acciona Energy), Should be 25 years instead of 20 years in line with provisions made in National Solar Mission for incentive (JVVNL & Sh. Vaibhav Gupta).

11. Applicability of Tariff

Tariff control period be extended upto 31.3.2012 (Torrent Power, Sh.Yogesh Gupta, Sh.D.S.Agarwal). In view of time taken for financial closure post PPA, CERC made their tariff valid upto 31.3.2012 (AES Solar).

12. Grid Interface Metering

The responsibility for development of evacuation system from pooling station should be clearly specified. RVPN may provide infrastructure from pooling station. CERC and GERC have specified capital cost inclusive of evacuation infrastructure up to interconnection point (RREC). As per NVVN transmission charges, losses, SLDC charges etc., beyond delivery point to be borne by utility. Interconnection point for supply is HV side of generator transformer. Applicability of development fee of Rs.2.00 lacs per MW needs to be clarified. Charges if any to developer for network augmentation be clarified. (Acciona Energy).

13. Use of Solar Power for Agriculture Pump Sets

Solar power should be used for energizing agriculture pump sets to ameliorate the grave situation of limited and erratic power supply moreover this power is available during the day which will be helpful to farmers to avoid work at night hours can also be used in areas where electricity is yet to reach (Sh.Arjun Singh).

14. Solar Radiation

There is a wide variation in solar insolation data; therefore, tariff calculation made at average value will have risk of revenue return during initial years of operation (Sh.Shanti Prasad). Lowest value of DNI should be taken for estimating available solar irradiation (Acira Solar).

15. Foreign Exchange Rate (Forex)

Forex variation would reflect on capital cost, thus, any rise will be to developer account (Sh.Shanti Prasad).

16. Income Tax Rates

Variations in Income Tax rates be allowed as pass through in tariff (Torrent Power). MAT rates considered as 19.93% for first year and 18.54% from second to tenth year, whereas MAT would be applicable @19.93% throughout the initial 10 years as profit of 100 MW plant will be above 1.00 Crore (ACME Power). MAT considered @19.93% for 1st year only (Sh.Shanti Prasad).

17. Roof Top applications

The upper limit of individual roof top mounted SPV be kept as 2 MW, in view of large campus available in urban/other areas for MW scale

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generation (Green Oil Energy). It would be appropriate to have flexibility in tariff order subject to guidelines as may be specified by RREC based on general guidelines of Commission and MNRE (Sh.Shanti Prasad). Purchase from roof top not covered under RPO, purchase from roof top be included in RPO of 50 MW (JVVNL). Tariff for project upto 3 MW getting GBI under NSM be kept as per CERC (P&EC)

18. Insurance Consider fixed for 20 years in the order but it should be reducing every year as per depreciated capital cost (Sh.Yogesh Gupta).

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Statement Indicating Capital Cost of Thin Film Solar Plants in petitions of

project developers and its Benchmarking

SOLAR POWER

PROJECT COST

Benchmarks for Thin

Film Technology

Cost indicated by project developers

(Rs. Cr.)

S.No

Cost component Cost

Rs/Wp

Cost

for

5MW in

Rs

Crores

% of

cost

AES

Solar

Energy

Cd Te

Ashtonfiel

d Solar

Cd Te

Mose

r

Baer

a-Si

OPG

Energ

y a-Si

Swiss

Park

a-Si

1 Land (30 to

35acres)

0.5 0.4 1.74 0.5 2.38 2.38

2 Modules 81 40.66 53.09 53.3 40.66 43.5 51.7 51.7

3 Inverters 18 9 11.75 8.2 16 13.78 9.75 9.75

4 Structure 15 7.5 9.79 7.5 8.16 8.48 9.5 9.5

5 Cables, JBs etc 7.38 3.69 4.82 7.6 1.98 3.69 3.25 3.25

6 Transformers and

switchgear

1.25 1.63 1.3 0 2.41 1 1

7 Civil contruction

incl land dev

3.77 8.4 1.1 3.77 9.7 9.7

8 Initial Spares

(approx 0.5% of

project cost)

0.375 0 1.04 0 0 0

9 Installation &

Project

management

costs

4.7 4.7 8.77 7.19 6.87 6.87

10 Interest during

construction

2.33 2.11

11 Finance Charges 1.125

4.75 5.42

0.43

9.6 9.6

12 Taxes and Duties 0 0 2.78 0 0 0

13 Insurance (0.25%),

FE risk variation

1.6875 1.35 0.78 0 2 2

Annexure- IVOrder – Solar Tariff

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185

(1%),

Miscellaneous and

contingencies (1%)

14 Sub total of Other

costs (excl items 2

to6)

14.49 18.92 19.60 21.63 14.00 30.55 30.55

15 Total Project cost

for 5MW

76.59 100.0

0

97.50 88.43 85.86 105.7

5

105.7

5

16 Project Cost per

MW

15.32 19.50 17.69 17.17 21.15 21.15

Statement Indicating Capital Cost of Crystalline Silicon Power Plants in petitions of

project developers and Its Benchmarking

SOLAR POWER

PROJECT COST

Benchmarks for Crystalline

Silicon Technology

Cost indicated by

project developers (Rs.

Cr.)

S.No Cost component Cost

Rs/Wp

Cost for

5MW in

Rs

Crores

% of

cost

VideoCon Refex

1 Land (30 to 35acres) 0.2 0.18 0.2

2 Modules 112 56 66.07 65 65.01

3 Inverters 18 9 10.62 8.85 9.22

4 Structure 7 3.5 4.13 9.45 3.54

5 Cables, JBs etc 5.18 2.59 3.06 3.9 2.59

6 Transformers and

switchgear

1.25 1.47 2 2.5

7 EPC margins 4.9 5

8 Civil contruction incl

land dev

2 1.47 1

9 Initial Spares

(approx 0.5% of

project cost)

0.375 1 1.1

10 Installation & Project

management costs

4.7 2.4 5.14

Order – Solar Tariff Annexure- V

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186

11 Interest during

construction

2.33

12 Finance Charges 1.125

5.4

13 Taxes and Duties 0 5.6

14 Insurance (0.25%),

FE risk variation (1%),

Miscellaneous and

contingencies (1%)

1.6875 1.17 0.9

15 Sub total of Other

costs (excl items 2

to6)

12.42 14.65

16 Total Project cost for

5MW

84.76 100.00 100.32 107.10

17 Project Cost per MW 16.95 20.06 21.42

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187

1

Roof top solar power plant

TO UTILITY NETWORK

SW-1

S1

Main Consumer bus

GI SE(N) GE

SW - 3 SW - 2

MAIN CONSUM

CI

S2

Consumer Import = C I

INVERTER ±

SOLAR PANEL CONSUMER NON

EMERGENCY LOAD

INVERTER CUM CHARGER

BATTERY

SM CM

GM

DG

CONSUMER EMERGENCY LOAD

Annexure-VIII

Consumer AC LT Bus Solar LT

DG LT Bus

SE(N)+GI=GE+CI GM=G rid Meter CM=Consumer Meter SM=Solar Meter SE(N)=Net Solar Export Meter reading SW = Switch

Consumer installation

Note 1.Normally solar panel is connected with the grid. When grid fails, inverter controlled normally close d (ON) Switches S1 and normally open (OFF) Switch S2 will open & close respectively. On restoration of supply, reverse action will take place.

Grid Import = GI

Solar PV Installation and Metering Scheme

Grid Export = GE

S1

Transformer

(HT or LT as applicable)

Transformer

2. In case a solar PV power producer is not a consumer then the consumer installation shown dotted above shall not be there.

3. For LT injection the transformers shall not be there.

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188

Annexure-IX

List of abbreviations AC : Alternating Current AD : Accelerated Depreciation A&G Expenses : Administrative & General Expenses a-Si : Amorphous Silicon CAPEX : Capital Expenditure CDM : Clean Development Mechanism CdTe : Cadmium Telluride CEA : Central Electricity Authority CERC : Central Electricity Regulatory Commission CoD : Commercial operation Date CPV : Concentrated Photo Voltaic c-Si : Crystalline silicon CSP : Concentrated Solar Power CUF : Capacity Utilisation Factor DC : Direct Current Di : Distribution Company DPR : Detailed Project Report DNI : Direct Normal Irradiance EA 2003 : Electricity Act, 2003 FRP : Feeder Renovation Programme FY : Financial Year GBI : Generation Based Incentive GoI : Government of India GoR : Government of Rajasthan Govt. : Government GSM : Global System for Mobile Communication IDC : Interest During Construction IMD : Indian Meteorology Department ISCC : Integrated Solar Combined Cycle IWC : Interest on Working Capital JNNSM : Jawaharlal Nehru National Solar Mission JVVNL : Jaipur Vidyut Vitran Nigam Limited LT : Low Tension MAT : Minimum Alternate Tax MNRE : Ministry of New and Renewable Energy MU : Million Units MW : Mega Watts MYT : Multi Year Tariff NASA : National Aeronautics and Space Administration NREL : National Renewable Energy Laboratory NVVNL : NTPC Vidyut Vyapar Nigam Ltd O&M : Operation & Maintenance PLF : Plant Load Factor PLR : Prime Lending Rate PPA : Power Purchase Agreement REC : Renewable Energy Certificate RERC : Rajasthan Electricity Regulatory Commission RREC : Rajasthan Renewable Energy Corporation Ltd., RoE : Return on Equity RVPN : Rajasthan Rajya Vidyut Prasaran Nigam Limited SBI : State Bank of India

Order – Solar Tariff

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SCADA : Supervisory Control and Data Acquisition SERC : State Electricity Regulatory Commission SPV : Solar Photo Voltaic STU : State Transmission Utility ToD : Time of Day

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Annexure- 10(a)

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Annexure- 10(b)

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Annexure- 10(c)

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Annexure- 11

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